GE Multilin W650 Instruction Manual

GE Consumer & Industrial

g

Multilin

W650

Wind Generator Protection System

Instruction manual

GEK-113032A

Firmware version: 3.02

GE Multilin

215 Anderson Avenue
L6E 1B3 Markham, ON -CANADA
T [phone] F [phone]

E [e-mail]

EnerVista 650 Setup version: 3.0

Copyright © 2006 GE Multilin

GE Multilin

Avda. Pinoa, 10
48170 Zamudio SPAIN
T [phone] F [phone]

E [e-mail]

2

Internet: www.GEMultilin.com

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 WITHW650....................................1-16

1.4 W650 HARDWARE

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

1.4.2 W650 COMMUNICATIONS.............................................................................1-17

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

1.4.4 MAINTENANCE...............................................................................................1-19

2. PRODUCT DESCRIPTION 2.1 OVERVIEW

2.1.1 W650 OVERVIEW.............................................. ...............................................2-1

2.2 SUMMARY

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

2.3 ORDERING CODE

2.4 TECHNICAL SPECIFICATIONS

2.4.1 PROTECTION ELEMENTS...............................................................................2-6

2.4.2 CONTROL.......................................................................................................2-14

2.4.3 MONITORING .................................................................................................2-15

2.4.4 USER –PROGRAMABLE ELEMENTS............................................................2-17

2.4.5 METERING......................................................................................................2-18

2.4.6 INPUTS............................................................................................................2-19

2.4.7 REAL TIME CLOCK ......................................................... ...............................2-21

2.4.8 OUTPUTS........................................................................................................2-21

2.4.9 CONTROL POWER SUPPLY .........................................................................2-22

2.4.10 COMMUNICATIONS.......................................................................................2-22

2.4.11 OPTIC FEATURES..........................................................................................2-24

2.4.12 ENVIRONMENTAL CHARACTERISTICS.......................................................2-25

2.4.13 PACKAGING AND WEIGHT ...........................................................................2-25

2.4.14 TYPE TESTS........................................................................ ...........................2-25

2.4.15 APPROVALS...................................................................................................2-25

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.......................................................................................3-5

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.................................................................3-9

GEK-113032A W650 Wind Generator Protection System I

TABLE OF CONTENTS

3.5 TRANSCEIVER OPTICAL POWER BUDGET VERSUS LINK LENGTH

4. HUMAN INTERFACES. 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE

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

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 MENUS STRUCTURE............................................4-12

4.1.7 FILE MENU OVERVIEW..................................................................................4-13

4.1.8 SETPOINT MENU OVERVIEW........................................................................4-17

4.1.9 ACTUAL VALUES MENU OVERVIEW............................................................4-26

4.1.10 OPERATIONS MENU OVERVIEW..................................................................4-30

4.1.11 COMMUNICATION MENU OVERVIEW..........................................................4-30

4.1.12 SECURITY MENU OVERVIEW.......................................................................4-33

4.1.13 VIEW MENU OVERVIEW........................................ ... .....................................4-33

4.1.14 HELP MENU OVERVIEW................................................................................4-33

4.2 HUMAN MACHINE INTERFACE (HMI)

4.2.1 DISPLAY..........................................................................................................4-34

4.2.2 FRONT LED INDICATORS......................................... .... ... ..............................4-35

4.2.3 PUSHBUTTONS.............................................................................................4-35

4.2.4 FRONT PORT AND COVER SEALING SYSTEM...........................................4-36

4.2.5 TEXT MENUS ............................................ ... .... ...............................................4-37

4.2.6 GRAPHIC DISPLAY.........................................................................................4-55

4.3 WEB SERVER

4.3.1 HOME...............................................................................................................4-64

4.3.2 SNAPSHOT EVENTS......................................................................................4-65

4.3.3 CONTROL EVENTS.........................................................................................4-66

4.3.4 ALARMS...........................................................................................................4-67

4.3.5 OSCILLOGRAPHY...........................................................................................4-68

4.3.6 FAULT REPORT..............................................................................................4-69

4.3.7 DATA LOGGER................................................................................................4-70

4.3.8 METERING.......................................................................................................4-71

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........................................................................................................5-22

5.3.4 SWITCHGEAR.................................................................................................5-24

5.4 PROTECTION ELEMENTS

5.4.1 CHANGE OF SETTING TABLES IN W650 ELEMENTS .................................5-25

5.4.2 INVERSE TIME CURVES CHARACTERISTICS.............................................5-29

5.4.3 PHASE CURRENT........................................................................ ...................5-39

5.4.4 NEUTRAL CURRENT......................................................................................5-49

5.4.5 GROUND CURRENT.......................................................................................5-56

5.4.6 SENSITIVE GROUND CURRENT...................................................................5-59

5.4.7 NEGATIVE SEQUENCE CURRENT................................................................5-62

5.4.8 VOLTAGE ELEMENTS....................................................................................5-63

5.4.9 POWER............................................................................................................5-68

II W650 Wind Generator Protection System GEK-113032A

TABLE OF CONTENTS

5.5 CONTROL ELEMENTS

5.5.1 SETTING GROUP..................................................... .... ... ...............................5-74

5.5.2 UNDERFREQUENCY ELEMENT (81U)..........................................................5-75

5.5.3 OVERFREQUENCY ELEMENT (81O)............................................................5-75

5.5.4 AUTORECLOSE (79)......................................................................................5-76

5.5.5 BREAKER FAILURE ELEMENT (50BF)..........................................................5-83

5.5.6 VT FUSE FAILURE ELEMENT (VTFF)...........................................................5-86

5.6 INPUTS/OUTPUTS

5.6.1 INPUT/OUTPUT PLACEMENT.......................................................................5-88

5.6.2 CONTROL SETTINGS FOR INPUTS/OUTPUTS ...........................................5-89

5.6.3 INPUTS............................................................................................................5-91

5.6.4 OUTPUTS........................................................................................................5-93

5.6.5 CIRCUIT SUPERVISION AND CONTACT SEAL-IN CIRCUITS.....................5-95

5.6.6 ANALOG BOARDS SPECIFIC SETTINGS ...................................................5-105

5.6.7 VIRTUAL INPUTS .........................................................................................5-106

5.6.8 VIRTUAL OUTPUTS .....................................................................................5-106

5.7 TESTINGS

5.7.1 FORCE IO –INPUT TESTING.......................................................................5-107

5.7.2 FORCE IO –OUTPUT TESTING...................................................................5-107

5.8 RELAY CONFIGURATION

5.8.1 OUTPUTS......................................................................................................5-108

5.8.2 LEDS ............................................................................................................. 5-109

5.8.3 OPERATIONS...............................................................................................5-110

5.8.4 PROTECTION ELEMENTS........................................................................... 5-114

5.8.5 OSCILLOGRAPHY........................................................................................5-115

5.8.6 CONTROL EVENTS ......................................................................................5-116

5.8.7 SWITCHGEAR ............................................................................................. 5-118

5.8.8 HMI (HUMAN-MACHINE INTERFACE).........................................................5-119

5.9 LOGIC CONFIGURATION (PLC EDITOR)

5.9.1 INTRODUCTION ...........................................................................................5-122

5.9.2 THEORY OF OPERATION............................................................................5-123

5.9.3 MAIN MENU..................................................................................................5-126

5.9.4 CONFIGURATION GENERATION................................................................5-127

5.9.5 GENERATION OF LIBRARIES ....................................................................5-128

5.9.6 EXAMPLE OF APPLICATION.......................................................................5-130

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...................................................................................................6-2

6.2.4 CONTROL ELEMENTS.....................................................................................6-8

6.2.5 PROTECTION SUMMARY..............................................................................6-13

6.2.6 SNAPSHOT EVENTS SUMMARY..................................................................6-15

6.2.7 MODBUS USER MAP.................................................................................. ...6-17

6.2.8 SWITCHGEAR STATUS.................................................................................6-17

6.2.9 CALIBRATION.................................................................................................6-19

6.2.10 FLEX CURVES........................................................................ ........................6-20

6.2.11 SYSTEM INFO ................................................................................................6-20

6.2.12 RECORD STATUS.................................................... .... ..................................6-20

6.3 METERING

6.3.1 PRIMARY VALUES.........................................................................................6-25

6.3.2 SECONDARY VALUES...................................................................................6-28

6.3.3 PHASOR DIAGRAM........................................................................................6-30

6.3.4 FREQUENCY..................................................................................................6-30

6.3.5 INPUTS / OUTPUTS .......................................................................................6-31

6.4 RECORDS

6.4.1 EVENT RECORDER.......................................................................................6-37

6.4.2 WAVEFORM CAPTURE .................................................................................6-39

6.4.3 FAULT REPORT .............................................................................................6-40

GEK-113032A W650 Wind Generator Protection System III

TABLE OF CONTENTS

6.4.4 DATA LOGGER................................................................................................6-42

7. IEC 61850 PROTOCOL 7.1 IEC61850 GENERIC SUBSTATION STATE EVENT (GSSE)

7.1.1 REMOTE DEVICES...................................... .... ... ..............................................7-1

7.1.2 REMOTE INPUTS......................................... ................................................. ....7-3

7.1.3 REMOTE OUTPUTS..................................... .... .................................................7-4

7.2 IEC 61850 PROFILE FOR W650

7.2.1 INTRODUCTION................................................................................................7-6

7.2.2 ACSI CONFORMANCE STATEMENT...............................................................7-6

7.2.3 LOGICAL NODES.............................................................. .... ... .......................7-11

7.2.4 COMMON DATA CLASS.................................................................................7-29

7.2.5 DATASETS.......................................................................................................7-44

7.2.6 MAPPINGS BETWEEN TOC CURVES IN IEC 61850 AND W650 RELAY

IMPLEMENTATION..........................................................................................7-46

7.2.7 ANALOG DATA UNITS AND SCALES............................................................7-47

8. W650 CANOPEN PROFILE 8.1 INTRODUCTION

8.1.1 DEFINITIONS.....................................................................................................8-1

8.2 CANOPEN INTERFACE SPECIFICATION

8.3 SERVICES

8.4 OBJECT DICTIONARY

8.4.1 STANDARD OBJECTS......................................................................................8-4

8.4.2 MANUFACTURER SPECIFIC OBJECTS..........................................................8-7

9. SECURITY 9.1 ADDING USERS

9.1.1 USER RIGHTS...................................................................................................9-1

9.2 CHANGING PASSWORDS

9.3 ENABLING SECURITY

9.4 LOGING INTO ENERVISTA 650 SETUP

10. BOOTCODE AND
FIRMWARE UPGRADE

10.1 INTRODUCTION

10.1.1 COMMUNICATION PARAMETERS.................................................................10-2

10.2 BOOT CODE UPGRADE

10.3 FIRMWARE VERSION UPGRADE

10.3.1 FIRMWARE UPGRADE...................................................................................10-9

10.3.2 BOOT CODE UPGRADE (*)..........................................................................10-11

10.3.3 FIRMWARE UPGRADE (*)............................................................................10-12

IV W650 Wind Generator Protection System GEK-113032A

TABLE OF CONTENTS

11. COMMISSIONING 11.1 VISUAL INSPECTION

11.2 GENERAL CONSIDERATIONS ON THE POWER SUPPLY NETWORK

11.3 ISOLATION TESTS

11.4 INDICATORS

11.5 POWER SUPPLY TESTING

11.6 COMMUNICATIONS

11.7 VERIFICATION OF MEASUREMENT

11.7.1 VOLTAGES .....................................................................................................11-7

11.7.2 PHASE CURRENTS............................................................. ... ........................11-7

11.7.3 ACTIVE, REACTIVE POWER, AND COSJ METERING.................................11-8

11.7.4 FREQUENCY..................................................................................................11-8

11.8 INPUTS AND OUTPUTS

11.8.1 DIGITAL INPUTS.............................................................................................11-9

11.8.2 CONTACT OUTPUTS ...................................................................................11-10

11.8.3 CIRCUIT CONTINUITY SUPERVISION INPUTS .........................................11-10

11.8.4 LATCHING CIRCUITS...................................................................................11-10

11.9 CONNECTIONS FOR TESTING PROTECTION ELEMENTS

11.10 INSTANTANEOUS OVERCURRENT (50PH, 50PL, 50N, 50G Y 50SG)

11.11 TIME OVERCURRENT (51PH, 51PL, 51N AND 51G)

11.12 DIRECTIONAL ELEMENTS (67P, 67N, 67G, 67SG)

11.12.1 67P ELEMENT ..............................................................................................11-14

11.12.2 67N ELEMENT ..............................................................................................11-14

11.12.3 67G ELEMENT..............................................................................................11-15

11.12.4 67SG ELEMENT............................................................................................11-16

11.13 UNDERVOLTAGE ELEMENTS (27P, 27X)

11.13.1 27P ELEMENT ..............................................................................................11-17

11.13.2 27X ELEMENT ..............................................................................................11-17

11.14 OVERVOLTAGE ELEMENTS (59P, 59X, 59NH, 59NL)

11.14.1 59P ELEMENT ..............................................................................................11-18

11.14.2 59X ELEMENT ..............................................................................................11-18

11.14.3 59NH AND 59NL ELEMENTS.......................................................................11-19

11.15 RECLOSER (79)

11.15.1 RECLOSING CYCLE.....................................................................................11-20

11.15.2 RECLOSER STATUS....................................................................................11-21

11.15.3 EXTERNAL RECLOSE INITIATION............................................ ..................11-21

12. APPLICATION EXAMPLES 12.1 EXAMPLE 1: COMMUNICATION & PROTECTION SETTINGS

PROCEDURE

12.1.1 DESCRIPTION OF THE EXERCISE...............................................................12-1

12.1.2 PROCEDURE TO COMMUNICATE WITH THE RELAY.................................12-1

12.1.3 PROCEDURE TO SET THE PROTECTION FUNCTION................................12-3

12.1.4 TEST................................................................................................................12-4

12.2 EXAMPLE 2: TOC PROTECTION + RECLOSING SETTINGS
PROCEDURE

12.2.1 DESCRIPTION OF THE EXERCISE...............................................................12-5

12.2.2 PROCEDURE TO COMMUNICATE THE RELAY...........................................12-5

12.2.3 PROCEDURE TO SET THE PROTECTION FUNCTION................................12-5

12.2.4 PROCEDURE TO SET THE RECLOSER.......................................................12-6

12.2.5 PROCEDURE TO SET THE SYNCHRO CHECK...........................................12-6

12.3 EXAMPLE 3: PROCEDURE TO SET AN OPERATION

12.3.1 DESCRIPTION OF THE EXERCISE...............................................................12-8

12.3.2 PROCEDURE .................................................................................................12-8

12.3.3 TEST..............................................................................................................12-10

GEK-113032A W650 Wind Generator Protection System V

TABLE OF CONTENTS

13. FREQUENTLY ASKED
QUESTIONS

13.1 COMMUNICATIONS

13.2 PROTECTION

13.3 CONTROL AND HMI

13.4 RELAY CONFIGURATION

14. TROUBLESHOOTING

14.1 SYMPTOMS AND RECOMMENDED ACTIONS

GUIDE

A. LOGIC OPERANDS A.1 LOGIC OPERANDS

B. MODBUS PROTOCOL B.1 ACCESS TO W650 DATA

B.2 MODBUS W650

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

B.2.2 PHYSICAL LAYER............................................................................................B-3

B.2.3 DATA LINK LAYER ...........................................................................................B-4

B.2.4 GENERIC READING.........................................................................................B-5

B.2.5 GENERIC WRITING..........................................................................................B-6

B.2.6 FUNCTION CODES .........................................................................................B-7

B.2.7 EXCEPTIONS AND ERROR RESPONDS........................................................B-8

B.3 DATA TYPE
B.4 MODBUS APPENDIX

B.4.1 DATA MANAGEMENT ....................................................................................B-10

B.4.2 WRITING SETTINGS......................................................................................B-11

B.4.3 SNAP-SHOT EVENTS ....................................................................................B-12

B.4.4 OPERATIONS.................................................................................................B-15

B.5 OUTPUT WRITING

B.5.1 CONTROL EVENTS........................................................................................B-17

B.5.2 EVENT STRUCTURE......................................................................................B-18

B.6 EVENTS STATUS REQUEST (ALARMS)

B.6.1 CONTROL EVENTS RETRIEVAL FROM THE COMMAND LINE .................B-21

B.6.2 SERIAL COMMUNICATION............................................................................B-22

B.6.3 ETHERNET COMMUNICATION.....................................................................B-23

B.6.4 ACKNOWLEDGEMENT OF EVENTS (ALARMS)...........................................B-24

B.6.5 VIRTUAL INPUTS WRITING...........................................................................B-25

B.6.6 USER MAP......................................................................................................B-26

B.6.7 RETRIEVING OSCILOGRAPHY.....................................................................B-27

B.6.8 TIME SYNCHRONIZATION ............................................................................B-28

B.6.9 ENQUEUEING MESSAGES ..........................................................................B-29

B.6.10 TRACES AND TROUBLESHOOTING.............................................................B-30

B.6.11 MODBUS CHECK FUNCTION........................................................................B-31

B.7 MEMORY MAP

C. DNP 3.0 PROTOCOL FOR

W650

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

VI W650 Wind Generator Protection System GEK-113032A

TABLE OF CONTENTS

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

C.5.3 MULTIPLE DNP 3.0 MASTERS COMMUNICATION WITH W650..................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

CONFIGURATION

E.1 FACTORY DEFAULT SETTINGS
E.2 FACTORY DEFAULT CONFIGURATION

F. MISCELLANEOUS F.1 GE MULTILIN WARRANTY

GEK-113032A W650 Wind Generator Protection System VII

TABLE OF CONTENTS

VIII W650 Wind Generator Protection System GEK-113032A

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.

1

Figure 1–1: FRONT VIEW OF W650 UNITS

GEK-113032A W650 Wind Generator Protection System 1-1

1.1 IMPORTANT PROCEDURES 1 GETTING STARTED

1.1.1.1 COMMUNICATION BOARDS WITHDRAWAL / INSERTION

1

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 withdra wal and insertion of the communication module.
Figure 1–2: shows the location of communication module s 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 anti static wristband must be u sed when manipul ating the mo dule in or der 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 facep late

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 re la y, connected equipment or personnel whenever

these safety rules are not followed.

1-2 W650 Wind Generator Protection System GEK-113032A

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

1

GE Multilin

Figure 1–3: REAR VIEW OF W650 UNIT

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

whenever these safety rules are not followed.

GEK-113032A W650 Wind Generator Protection System 1-3

1.1 IMPORTANT PROCEDURES 1 GETTING STARTED

1

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.

1.1.2 INSPECTION CHECKLIST

Figure 1–4: IDENTIFICATION LABEL (A4454P20)

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 W650 Wind Generator Protection System GEK-113032A

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. Pinoa, 10

48170 Zamudio, Vizcaya (SPAIN)

Tel.: [phone], Fax: [phone]

E-mail: [e-mail]

AMERICA, ASIA AND AUSTRALIA:

GE MULTILIN

215, Anderson Avenue

L6E 1B3 Markham, ON (CANADA)

Tel.: [phone], Fax: [phone]

E-mail: [e-mail]

1

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-113032A W650 Wind Generator Protection System 1-5

1.1 IMPORTANT PROCEDURES 1 GETTING STARTED

1.1.3 SAFETY INSTRUCTIONS

1

The W650 ground screw shown in Figure 1–5: must be correctly grounded.

Figure 1–5: LOCATION OF GROUNDING SCREW

Before communicating with a W650 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.

1-6 W650 Wind Generator Protection System GEK-113032A

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 pe rformed by these produ cts 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 r eductions. This requires placi ng even more
functions within the IEDs.

Users of power equipment are also interested in reducing cost by improving power quality and perso nnel 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.
This has been established by the IEC 61850 standard.

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 adaptative system configuration for protection and co ntrol
systems. This new generation of equipment must also be easily incorporated into automation systems, at both the station
and enterprise levels.

1

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 netwo rk (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 contro l features. It incorporates two internal processors, one for ge neric
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.

GEK-113032A W650 Wind Generator Protection System 1-7

1

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.
CAN Bus Inputs/Outputs: are signals associated to physical input/output contacts from independent modules connected

to the 650 unit via a CAN Bus.
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.
Remote inputs and outputs provide a means of sharing digital point state information between remote devices using IEC

61850 GSSE messages.
Analog Inputs are signals associated with transducers.

1-8 W650 Wind Generator Protection System GEK-113032A

1 GETTING STARTED 1.2 OVERVIEW

1.2.3 SOFTWARE ARCHITECTURE

The firmware (software embedded in the relay) has been designed usin g object oriented progra mming 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 W650 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 id entical po rts, COM1 and COM2. The C OM2
port is multiplexed with the front port.

Available options are:

Table 1–1: REAR SERIAL COMMUNICATIONS BOARD 1

BOARD CODE FUNCTIONALITY

F None
A Redundant RS 485
p Redundant plastic fiber optic
G Redundant glass fiber optic
X Redundant RS485 + Can port (CANopen)
Y Redundant plastic fiber optic + Can port (CANopen)
Z Redundant glass fiber optic + Can port (CANopen)
C CAN port (CANopen)
M RS485 + CAN port (CANopen)

1

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

Available Options are:

Table 1–2: REAR ETHERNET COMMUNICATIONS BOARD 2

BOARD
CODE

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

FUNCTIONALITY

For options C and D it is required to select the active physical media, by means of an intern al 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. This fa ct provides
increased communication speed, as well as the possibility of acknowledgement of modules, abnormalitie s, etc. As this is a
serial port supporting a communications protocol, it provides extraordinary immunity against external or internal
disturbances.

GEK-113032A W650 Wind Generator Protection System 1-9

1

1.2 OVERVIEW 1 GETTING STARTED

Figure 1–7: COMMUNICATIONS ARCHITECTURE (B6816F1)

1-10 W650 Wind Generator Protection System GEK-113032A

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.

1

Figure 1–8: LAUNCHPAD WINDOW

GEK-113032A W650 Wind Generator Protection System 1-11

1.3 ENERVISTA 650 SETUP SOFTWARE 1 GETTING STARTED

5. In the EnerVista Launch Pad window, click the Add Product button and select the “W650 Wind Generator Protection

1

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 W650.

Figure 1–9: ADD PRODUCT WINDOW

6. If “Web” option is selected, chose the W650 software program and release notes (if desired) from the list and cl ick the

Download Now button to obtain the installation program.

Figure 1–10: WEB UPGRADE WINDOW

1-12 W650 Wind Generator Protection System GEK-113032A

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 in stallation 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.

1

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 comple te path name including the new directory name and click Next to
continue with the installation procedure.

Figure 1–12: ENERVISTA 650 SETUP INSTALLATION CONT.

GEK-113032A W650 Wind Generator Protection System 1-13

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 Sele cted Program F older window.
Click Next to begin the installation process, and all the necessary program files will be copied into the chosen directory.

1

Figure 1–13: SELECT PROGRAM FOLDER

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

Figure 1–14: LANGUAGE WINDOW

1-14 W650 Wind Generator Protection System GEK-113032A

1 GETTING STARTED 1.3 ENERVISTA 650 SETUP SOFTWARE

14. Click Finish to end the installation. The W650 device will be added to the list of installed IEDs in the EnerVista

Launchpad window, as shown below.

1

Figure 1–15: ENERVISTA LAUNCHPAD

GEK-113032A W650 Wind Generator Protection System 1-15

1.3 ENERVISTA 650 SETUP SOFTWARE 1 GETTING STARTED

1.3.3 CONNECTING ENERVISTA 650 SETUP WITHW650

1

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 fo r installation instructions).

2. Go to “Communication>Computer” and enter the following data refering 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 (Sl ave Address) fi eld.

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.

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 fo r 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 Pro tocol” menu) in the

Slave Address field.

5. Enter the physical communications parameters (Baudrate and parity settings) from “Setpoint>Product Setup

>Communication Settings>Serial Ports” menu, in their respective fields.

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

communicating.

1-16 W650 Wind Generator Protection System GEK-113032A

1 GETTING STARTED 1.4 W650 HARDWARE

1.4W650 HARDWARE 1.4.1 MOUNTING & WIRING

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

1.4.2 W650 COMMUNICATIONS

The Enervista 650 Setup software communicates to the relay via the fa ceplate 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 en d is connected to the PC COM1 or COM2 po rt as described in
Figure 1–16:.

To communicate through the W650 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 shi elded
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 W650 rear communication port.

In order to minimize communication errors that could be caus ed by external noise, it is recommended to use a shi elded
twist pair. In order to avoid loops where external currents could flow, the cabl e 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(*).

1

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

To minimize errors from noise, th e use of shielded twisted pair wire is recommended. For correct operation, po larity 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 provi ded. 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 thi s manner
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 th an 32. Do not use other
connection configurations different to the recommended.

GEK-113032A W650 Wind Generator Protection System 1-17

1.4 W650 HARDWARE 1 GETTING STARTED

Lightning strikes and ground surge currents can cause large mo mentary voltage differences between remote ends of the
communication link. For this reason, surge protection devices are internally provided. To ensure maximum reliability, all

1

equipment should have similar transient protection devices installed.

Figure 1–17: RS485 CONNECTION FOR 650 UNITS

To comunícate through theW650 rear Ethernet port from a PC a crossover cable is required. If the connection is
performedthrough 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.

1-18 W650 Wind Generator Protection System GEK-113032A

1 GETTING STARTED 1.4 W650 HARDWARE

1.4.4 MAINTENANCE

W650 requires a minimum amount of maintenance when it is commissioned into service.W650 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 theW650 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.

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 visua l 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.

1

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.

GEK-113032A W650 Wind Generator Protection System 1-19

1

1.4 W650 HARDWARE 1 GETTING STARTED

1-20 W650 Wind Generator Protection System GEK-113032A

2 PRODUCT DESCRIPTION 2.1 OVERVIEW

2 PRODUCT DESCRIPTION 2.1OVERVIEW 2.1.1 W650 OVERVIEW

The modular W650 unit has been designed as a comprehensive generator controller specially adapted to wind turbine
generators. Based on the state of the art 650 family, it utilizes modern 32 bit processor platform to provide a complete
solution not only for the needs of present systems but also ready for the future. W650 simplifies the design of systems in
wind turbine generation due to the complete set of protection, measurement, control and recording functions. Maintenance
is eased thanks to the modular design wherea s cost is scalabl e de pending on th e options to allow a cost effective solution
from medium to large size generators.

The main features of W650 devices include:

• Directional overcurrent protection for phases, neutral, ground and sensitive ground

• High Speed Under and overvoltage protection

• Neutral Overvoltage

• Voltage Unbalance

• Under and overfrequency protection

• Autorecloser

• Metering

• Oscillography registers, fault reports, data logger

• Bay control (open/close commands, etc.)

• Bay mimic.

• Communications (RS232/RS485/CAN/Ethernet)

2

GEK-113032A W650 Wind Generator Protection System 2-1

2.1 OVERVIEW 2 PRODUCT DESCRIPTION

• Fully programmable front buttons, 15 LED’s and input/output contacts

Figure 2–1: FUNCTIONAL BLOCK DIAGRAM

2

2-2 W650 Wind Generator Protection Syst em GEK-113032A

2 PRODUCT DESCRIPTION 2.2 SUMMARY

2.2SUMMARY

2.2.1 ANSI DEVICE NUMBERS AND FUNCTIONS

DEVICE NUMBER FUNCTION

27P (4) Phase Undervoltage
27X (3) Auxiliary Undervoltage
32 (4) Directional Power
46 (3) Negative Sequence Time Overcurrent
50G (3)

50N (3) Neutral Instantaneous Overcurrent (calculated from the phase currents)
50P (6) Phase Instantaneous Overcurrent (two elements, High and Low)
50SG (3)

51G (3)
51N (3) Neutral Time Overcurrent (calculated from the phase currents)

51P (6) Phase Time Overcurrent with Voltage Restraint (two elements, High and Low)
51SG (3)

59N (6) Neutral Overvoltage (two elements, High and Low)
59P (4) Phase Overvoltage
59X (3) Auxiliary Overvoltage
60V (3) Voltage Unbalance
67P (3) Phase Directional
67N (3) Neutral directional
67G (3) Ground Directional
67SG (3) Sensitive Ground Directional
79 (1) Autoreclose (Four shot recloser)
810 (4) Overfrequency
81U (4) Underfrequency
50BF (1) Breaker Failure
VTFF (1) VT Fuse Failure

Ground Instantaneous Overcurrent (measured from 4

Ground Instantaneous Overcurrent for sensitive ground systems (measured from 5
transformer)

Ground Time Overcurrent (measured from 4

Ground Time Overcurrent for sensitive ground systems (measured from 5

th

th

current transformer)

current transformer)

th

current

th

current transformer)

2

GEK-113032A W650 Wind Generator Protection System 2-3

2.2 SUMMARY 2 PRODUCT DESCRIPTION

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 auxiliary voltage)

Digital Programmable Contact Inputs (up to

64)
Digital Programmable Contact Outputs (up to

2

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

Remote Inputs/Outputs (GSSE messages) CANopen protocol

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 4)
Configurable One-Line Diagram (Graphic

model only)
Phasor Diagram (available in EnerVista 650

Setup)

Metering Current for phases, ground and
sensitive ground inputs

Voltages phase to phase and phase to
ground

Real, Reactive and Apparent Power and
Power Factor

Three Phase Energy IEC 870-5-104

voltages

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)

IEC 61850

Breaking Arcing Current (I

IRIG-B synchronization/SNTP

Logic Equations (PLC Editor)

Web Server Application

2

t)

2-4 W650 Wind Generator Protection Syst em GEK-113032A

2 PRODUCT DESCRIPTION 2.3 ORDERING CODE

2.3ORDERING CODE

W650 units are supplied as ½ 19” rack, 6 units high, containing the followi ng modules: power supply, CPU, I/O modules,
communication modules. The required information to completely define an W650 model is shown on Table 2–1:

Table 2–1: ORDERING CODE

W650 - - - F - G - - - - - DESCRIPTION

B Basic display (4x20 characters)
M Graphic display (240x128 pixels)

REAR SERIAL COMMUNICATIONS BOARD 1

F None
A Redundant RS485
P Redundant plastic fiber optic
G Redundant glass fiber optic
X Redundant RS485 + fiber Can port (CANopen)
Y Redundant plastic fiber optic + fiber Can port (CANopen)
Z Redundant glass fiber optic + fiber Can port (CANopen)
C CableCan port (CANopen)

M Cable can port (CANopen)+RS485

REAR ETHERNET COMMUNICATIONS BOARD 2

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

I/O BOARD IN SLOT F

1 16 Digital Inputs + 8 Outputs
2 8 Digital Inputs + 8 Outputs + 2 trip/close circuit supervision

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)

HI 110-250 Vdc (range 88 – 300)

LOR Redundant LO

HIR Redundant HI

- Without IEC 61850 protocol

6 IEC 61850

circuits

I/O BOARD IN SLOT G

AUXILIARY VOLTAGE

120-230 Vac (range 96 – 250)

COMMUNICATION PROTOCOL

ENVIRONMENTAL PROTECTION

- Without Harsh (Chemical) Environment Conformal Coating

H Harsh (Chemical) Environment Conformal Coating

2

Notes:

(1) The digit selected for option G must be equal or higher than the digit selected for option F:
W650***F1G5*****: is a valid selection W650***F5G1*****: is an invalid selection

As exceptions to this rule, 0 is always available for option G, and F2G1 is also a valid selection.

GEK-113032A W650 Wind Generator Protection System 2-5

2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION

2.4TECHNICAL SPECIFICATIONS

NOTE: TECHNICAL SPECIFICA TIONS ARE SUBJECT T O 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 fro m the three ph ase currents.

2

The isolated ground unit will be used only fo r those applications where the neutral is comp letely 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 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

±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 / normally / moderately inverse
ANSI extremely / very / normally / moderately inverse

2

t

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

30 ms. (whichever is greater)

2.4.1.2 GROUND TIME OVERCURRENT (51G)

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

2-6 W650 Wind Generator Protection Syst em GEK-113032A

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

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 / normally / moderately inverse
ANSI extremely / very / normally / moderately inverse

2

I

t
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

30 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 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

±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 / normally / moderately inverse
ANSI extremely / very / normally / moderately inverse

2

I

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

or 30 ms. (whichever is greater)

2

GEK-113032A W650 Wind Generator Protection System 2-7

2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION

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 98% of the pickup level
Level Accuracy

2

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

±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 / normally / moderately inverse
ANSI extremely / very / normally / moderately inverse

2

I

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

or 30 ms. (whichever is greater)

2.4.1.5 PHASE AND GROUND INSTANTANEOUS OVERCURRENT (50PH/50PL/50G)

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% of the pickup level
Level Accuracy

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 20 ms at 3 x Pickup at 50 Hz, typically
Timing accuracy ±3% of operate time or 30 ms. (whichever is greater)
Snapshot Events Selectable by setting

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

2-8 W650 Wind Generator Protection Syst em GEK-113032A

2 PRODUCT DESCRIPTION 2.4 TECHNICAL SPECIFICATIONS

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% of the pickup level
Level Accuracy

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 20 ms at 3 x Pickup at 50 Hz, typically
Timing accuracy ±3% of operate time or 30 ms. (whichever is greater)
Snapshot Events Selectable by setting

2.4.1.7 SENSITIVE GROUND INSTANTANEOUS OVERCURRENT (50SG)

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% of the pickup level
Level Accuracy
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 20 ms at 3 x Pickup at 50 Hz
Timing accuracy ±3% of operate time or 30 ms. (whichever is greater)
Snapshot Events Selectable by setting

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

±1.5% of the reading ± 1 mA from 0.005 to 16 A

2

GEK-113032A W650 Wind Generator Protection System 2-9

2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION

2.4.1.8 NEGATIVE SEQUENCE CURRENT (46)

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

2

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

±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 / normally / moderately inverse
ANSI extremely / very / normally / moderately inverse

2

I

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

or 30 ms. (whichever is greater)

2.4.1.9 PHASE DIRECTIONAL (67P)

Directionality Forward and reverse selectable by setting
Polarizing Quadrature Voltage:

ABC seq: Phase A (VBC), Phase B (VCA), Phase C
(VAB)
ACB seq: Phase A (VCB), Phase B (VAC), Phase C
(VBA)

Polarizing voltage threshold 0 to 850 V ac in steps of 1 V
Characteristic angle -90º to +90º in steps of 1º
Block Logic Permission or Block selectable by setting
Angle accuracy
Operate time <30ms, typically

2.4.1.10 GROUND DIRECTIONAL (67G)

Directionality Forward and reverse selectable by setting
Polarizing Voltage, current, dual
Polarizing V o ltage VN (measured or calculated, selected by setting)

Polarizing Current
Operating Current
Polarizing Voltage threshold 0 to 500 Vac in steps of 1 V

Polarizing Current threshold 0.005 A

±2º for I>0.1 A and V>5 Vac

Isg (measured from 5
Ig (measured from 4

th

current transformer)

th

current transformer)

2-10 W650 Wind Generator Protection System GEK-113032A

2 PRODUCT DESCRIPTION 2.4 TECHNICAL SPECIFICATIONS

Characteristic angle -90º to +90º in steps of 1º
Block Logic Permission or Block selectable by setting
Angle accuracy
Operate time <30ms, typically

±2º for I>0.1 A and V>5 Vac

2.4.1.11 NEUTRAL DIRECTIONAL (67N)

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

Polarizing Current
Operating Current I
Polarizing Voltage threshold 0 to 500 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
Operate time <30ms, typically

2.4.1.12 SENSITIVE GROUND DIRECTIONAL (67SG)

Directionality Forward and reverse selectable by setting
Polarizing Voltage
Polarizing V o ltage V

Operating Current
Polarizing Voltage threshold 0 to 500 Vac in steps of 1 V

Characteristic angle -90º to +90º in steps of 1º
Block Logic Permission or Block selectable by setting
Angle accuracy
Operate time <30ms, typically

(measured or calculated, selected by setting)

N

th

Isg (measured from 5

N

±2º for I>0.1 A and V>5 Vac

(measured or calculated, selected by setting)

N

Isg (measured from 5

±2º for I>0.1 A and V>5 Vac

current transformer)

th

current transformer)

2

2.4.1.13 PHASE OVERVOLTAGE (59P)

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

phase voltages
Pickup level 3 to 850 in steps of 1 V
Dropout level 97% 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 op erate time or 30 ms. (whichever is greater)
Logic Any/Two/All phases logic selectable by setting

GEK-113032A W650 Wind Generator Protection System 2-11

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

2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION

Snapshot Events Selectable by setting

2.4.1.14 PHASE UNDERVOLTAGE (27P)

Voltage Input Fundamental Phasor of phase-to-ground or phase-to-

2

Pickup level 3 to 850 in steps of 1 V
Dropout level 103% of the pickup leve l
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 30 ms. (whichever is greater)
Minimum Voltage Threshold 0 to 850 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

phase voltages (selectable by setting)

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

2.4.1.15 NEUTRAL OVERVOLTAGE (59NH/59NL)

Voltage Input Fundamental Phasor of the neutral voltage
Pickup level 3 to 500 in steps of 1 V
Dropout level 97% 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 30 ms. (whichever is greater)
Snapshot Events Selectable by setting

2.4.1.16 AUXILIARY OVERVOLTAGE (59X)

Voltage Input Fundamental Phasor
Pickup level 3 to 500 in steps of 1 V
Dropout level 97% 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 30 ms. (whichever is greater)
Snapshot Events Selectable by setting

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

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

2-12 W650 Wind Generator Protection System GEK-113032A

2 PRODUCT DESCRIPTION 2.4 TECHNICAL SPECIFICATIONS

2.4.1.17 AUXILIARY UNDERVOLTAGE (27X)

Voltage Input Fundamental Phasor
Pickup level 3 to 500 V in steps of 1 V
Dropout level 97% 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 30 ms. (whichever is greater)
Snapshot Events Selectable by setting

2.4.1.18 UNDERFREQUENCY (81U)

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 500V in steps of 1 V
Timing accuracy ±3.5% of operate time or 100 ms. (whichever is greater)
Snapshot Events Selectable by setting

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

±0.01 Hz of the reading

2

2.4.1.19 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 500V in steps of 1 V
Timing accuracy ±3.5% of operate time or 100 ms. (whichever is greater)
Snapshot Events Selectable by setting

2.4.1.20 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
Dropout level 97% of the pickup level
Accuracy for primary magnitudes ±3% complete range
Trip delay (two stages) 0.00 to 900.00 s in steps of 0.01 s

±0.01 Hz of the reading

0.01 MW

GEK-113032A W650 Wind Generator Protection System 2-13

2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION

Timing accuracy ±3.5% of operate time or 30 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

2.4.1.21 VOLTAGE UNBALANCE (60V)

2

Pickup level 0.00-500.00% (V2/V1 ratio) in steps of 0.01%
Reset delay 0.00 to 900.00 s in steps of 0.01 s
Trip delay 0.00 to 900.00 s in steps of 0.01 s
Timing accuracy ±3.5% of operate time or 30 ms. (whichever is greater)
Snapshot Events Selectable by setting

2.4.2.1 AUTORECLOSE (79)

Schemes Three-pole tripping schemes
Number of shots Up to 4 reclose attempts before lockout
Dead time Independent dead time setting before each shot

adjustable between 0 and 900 s in steps of 0.01 s
Reclaim time 0.0 0 to 900.00 s in steps of 0.01 s
Condition permission Selectable by setting
Hold time 0.00 to 900.00 s in steps of 0.01 s
Reset time 0.00 to 900.00 s in steps of 0.01 s
Snapshot Events Selectable by setting
Possibility to modify protection settings after each shot programmable through PLC (block signals available after each

shot)

2.4.2 CONTROL

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
Reset level 97% of the pickup level

2-14 W650 Wind Generator Protection System GEK-113032A

2/V1

ratio

2 PRODUCT DESCRIPTION 2.4 TECHNICAL SPECIFICATIONS

Level Accuracy

Timing accuracy ±3.5% of operate time or 30 ms. (whichever is greater)
Snapshot Events Selectable by setting

2.4.2.4 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

2.4.2.5 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

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

0.03 to 0.25 s in steps of 0.01 s

2

2.4.2.6 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: Programmable to 4, 8, 16, 32 or 64 samples per power cycle

Capacity per record:

No of Oscillos * No of samples/cycle

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

27592 samples

GEK-113032A W650 Wind Generator Protection System 2-15

2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION

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

2

Zero Sequence Module: 0.01 to 750.00 Ohms in steps of 0.01 Ohm
Zero Sequence Angle: 25 a 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)

Format: Text in ASCII format

2.4.3.3 SNAPSHOT EVENTS

Capacity: 479 scrolling events
Time-tag
Timing Accuracy: 1 ms (using the IRIG-B synchronization input)
Triggers:

Data Storage
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 using an internal clock of 100 μs

Any element pickup, dropout

Digital input /output change of state
By virtual inputs and control events

In non volatile memory (flash) without battery

1 ms using an internal clock of 100 μs

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

2-16 W650 Wind Generator Protection System GEK-113032A

2 PRODUCT DESCRIPTION 2.4 TECHNICAL SPECIFICATIONS

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 sho ws the present and maximum measu red 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

±1%

method)

2

Number of Channels:
Parameters Any available analog actual value

Samples 1 sec., 1, 5, 10, 15, 20, 30, 60 min.
Storage Capacity Fixed, 32768 measures

2.4.4.1 PLC LOGIC

Programming language: The logical configuration is performed using graphical functions based on the

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

Libraries: Logical gates fully programmable by user. To create user-programmable logic to

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

1 to 16

2.4.4 USER –PROGRAMABLE ELEMENTS

IEC 61131-3 standard.

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

2 inputs default gates, from 3 to 8 inputs provided in library format.

be distributed as a single object.

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

GEK-113032A W650 Wind Generator Protection System 2-17

2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION

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.

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

2

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

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

Number of selectable displays: Logotype, metering or both in scrolling mode, can be selectable as default

trip signals.
The following 10 ones (yellow and green) are self-reset but can be latched
through PLC configuration.

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

and outputs screen with test functionality for inputs and outputs. In graphical
displays only

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

2.4.5.1 CURRENT

Accuracy:

2.4.5.2 VOLTAGE

Accuracy:

2.4.5.3 REAL POWER (WATTS)

Accuracy:

±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 and 0.8 <PF=1

2.4.5 METERING

2.4.5.4 REACTIVE POWER (VARS)

Accuracy:

2-18 W650 Wind Generator Protection System GEK-113032A

±1% of the reading at-0.2 = PF = 0.2

2 PRODUCT DESCRIPTION 2.4 TECHNICAL SPECIFICATIONS

2.4.5.5 APPARENT POWER (VA)

Accuracy:

2.4.5.6 WATT-HOURS (POSITIVE AND NEGATIVE)

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

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

±1% of the reading

±1% of the reading

±0 to 2147 MWh

±1% of the reading

±0 to 2147 MVArh

2

Accuracy:

2.4.5.10 ANGLE

Accuracy: 2º

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. W650 has universal range for CT (valid for 1 or 5 A to

Relay Burden: < 0.04 Ohm
Current Withstand Co ntinuo us at 20 A

±10 mHz at 50 Hz

±12 mHz at 60 Hz

2.4.6 INPUTS

only one terminal).

1 second at 500 A for phases and ground

1 second at 50 A for sensitive ground

GEK-113032A W650 Wind Generator Protection System 2-19

2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION

2.4.6.2 AC VOLTAGE INPUTS

VT Ratio 1.0 to 1500.0 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

2

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: 1 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

1 min/hr at 800 to neutral

±10% setting ± 2.5 V

< 10 V (fixed)

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)

2.4.6.4 REMOTE INPUTS

Number of input points: 32, configured from 64 incoming bit points

Number of remote devices:

Default states on loss of comms: On, Off, Latest/on, Latest/off

2.4.6.5 ANALOG INPUTS

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:

Accuracy: +/- 0.2% of full scale
Type: Passive

2-20 W650 Wind Generator Protection System GEK-113032A

16

-1 to +20mA

2 PRODUCT DESCRIPTION 2.4 TECHNICAL SPECIFICATIONS

2.4.6.6 IRIG-B INPUT

Amplitude modulation: DC SHIFT = Demodulated input (no carrier)

Input Voltage:

Input Burden: 1.5 mA
Input Impedance: 3.3 kOhm
Minimum Input Voltage: 2.4 V
Maximum Input Voltage: +/- 24 V
Formats: B000 (*) B001, B002 and B003 (*)

Isolation: 2 kV

TTL

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

2.4.7 REAL TIME CLOCK

2

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 Ou tput 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, F34­F36) for board type 2 (supervision)
in slot F:

GEK-113032A W650 Wind Generator Protection System 2-21

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 100 mA, the function is sealed independently of
the status of the function that caused the trip.

2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION

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

2

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 port (CANopen)
Model P Redundant 1mm-plastic F.O.
Model Y Redundant 1mm-plastic F.O. + fiber CAN port (CANopen)
Model G Redundant multimode glass F.O.
Model Z Redundant multimode glass F.O. + fiber CAN port (CANopen)
Model C Cable CAN port (CANopen)
Model M Ca ble CAN port (CANopen) + RS485 (ModBus RTU)
Optic Features for ST connectors

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

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

2-22 W650 Wind Generator Protection System GEK-113032A

2 PRODUCT DESCRIPTION 2.4 TECHNICAL SPECIFICATIONS

Default Baud Rate 19200
Protocols available:

Typical distance: 1 200 m
Isolation: dc kV1
CAN PORT:
Rear port:

ModBus® RTU / DNP 3.0

Fiber CAN port in models X, Y, Z and cable CAN port in models C and M for

rear board 1

Physical Layer: ISO11898, High speed
Baud rate: 125 / 500 kbaud

Fiber Type: Multimode glass F.O. port with ST connectors
Fiber Wave length: 1300 nm
Fiber type:

Maximum recommended length 1km (fiber); 500m (cable)
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 10/100BaseT X self-ne gotiable 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

multimode 62.5/125 μm or 50/125 μm

multimode 62.5/125 μm or 50/125 μm

DNP over TCP/IP and UDP/IP

IEC 61850

Http, ftp, tftp (allow the use of a standard Internet browser)

2

GEK-113032A W650 Wind Generator Protection System 2-23

2.4 TECHNICAL SPECIFICATIONS 2 PRODUCT DESCRIPTION

2.4.11 OPTIC FEATURES

Wave length: 1300nm
Connector types: ST package style
Fiber type: multimode 62.5/125 μm or 50/125 μm

2

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

-33.9 -31 dBm avg. Note 3

-35.2 -31.8 dBm avg. Note 4

-14 dBm avg. Note 1

-14 dBm avg. Note 1

-45 dBm avg. Note 2

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 degration 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.

2-24 W650 Wind Generator Protection System GEK-113032A

2 PRODUCT DESCRIPTION 2.4 TECHNICAL SPECIFICATIONS

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

2

Type test report available upon request.
W650 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.

GEK-113032A W650 Wind Generator Protection System 2-25

2.5 EXTERNAL CONNECTIONS 2 PRODUCT DESCRIPTION

2.5EXTERNAL CONNECTIONS

2

Figure 2–2: W650 WIRING DIAGRAM (189C4216H12R1)

Figure 2–3:

2-26 W650 Wind Generator Protection System GEK-113032A

3 HARDWARE 3.1 MODULE DESCRIPTION

e

3 HARDWARE 3.1MODULE DESCRIPTION

AAnnaalloog

s

iinnppuutts

s

VVTTs

d

aannd

s

CCTTs

HHiigghhSSppeeeeddsseerriiaallCCAANNBBuus

g

CPU

Module

SCREEN

Digital

I/O

Optional

Digital

I/O

s

Power

Supply

3

KKeeyyppaad

s

s

D

D

E

E

L

L

W650 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 as ynchronous communication
accessories.

• Input/Output module included in basic unit

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

SShhuuttttlleekkeey

S

RRS

2

22332

d

y

LLooccaall/

RReemmoot

/

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e

Figure 3–1: BLOCK DIAGRAM

GEK-113032A W650 Wind Generator Protection System 3-1

3.2 POWER SUPPLY 3 HARDWARE

3.2POWER SUPPLY

W650 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 te rminals. This rel ay 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

3

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

3-2 W650 Wind Generator Protection Syst em GEK-113032A

3 HARDWARE 3.3 MECHANICAL DESCRIPTION

3.3MECHANICAL DESCRIPTION

The model number and electrical characteristics of the unit are indica ted on the label loca ted on the right side of the re lay
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 conductor 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 personne l, 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 un it. The dr illing
dimensions are shown on Figure 3–4:.

3

Figure 3–3: PANEL MOUNTING

The relay width allows the mounting of two units on a standard 19’’ panel, 6 units high.

GEK-113032A W650 Wind Generator Protection System 3-3

3

3.3 MECHANICAL DESCRIPTION 3 HARDWARE

Figure 3–4: DRILLING DIMENSIONS DIAGRAM

3-4 W650 Wind Generator Protection Syst em GEK-113032A

3 HARDWARE 3.3 MECHANICAL DESCRIPTION

3

Figure 3–5: DIMENSIONS OF THE 19” RACKS 6U HIGH FOR TWO RELAYS

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

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 mm

12).

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

2

(AWG 10).

2

(AWG

GEK-113032A W650 Wind Generator Protection System 3-5

3

3.3 MECHANICAL DESCRIPTION 3 HARDWARE

Figure 3–6: CONNECTORS LOCATION

3-6 W650 Wind Generator Protection Syst em GEK-113032A

3 HARDWARE 3.3 MECHANICAL DESCRIPTION

TYPE OF COMMUNICATION CONNECTOR

RS485 / CAN cable
IRIG B Plug-in, 2 poles.

Plastic fiber optic Versatile Link

Plug-in, 3 poles.

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.

3

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

The transformers module with the VTs and CTs is already con nected 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.

GEK-113032A W650 Wind Generator Protection System 3-7

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.

3

Figure 3–9: REAR TERMINALS LOCATION

3-8 W650 Wind Generator Protection Syst em GEK-113032A

3 HARDWARE 3.4 WIRING

3.4WIRING 3.4.1 EXTERNAL CONNECTIONS

W650 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 includ ing bo ards
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 an d 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 outpu t co ntact.

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.

3

3.4.3 CABLE/FIBER ETHERNET BOARD

The Ethernet board is the communication board 2 (COM3) sh own in Fig ure 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: F IBER/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.

GEK-113032A W650 Wind Generator Protection System 3-9

3.4 WIRING 3 HARDWARE

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.

3

Figure 3–10: FIBER/CABLE SELECTION

3-10 W650 Wind Generator Protection System GEK-113032A

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 op tic 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

LENGTH (KM)

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

3

GEK-113032A W650 Wind Generator Protection System 3-11

3

3.5 TRANSCEIVER OPTICAL POWER BUDGET VERSUS LINK LENGTH 3 HARDWARE

3-12 W650 Wind Generator Protection System GEK-113032A

4 HUMAN INTERFACES. 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE

4 HUMAN INTERFACES. 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 UR
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 commu nication 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 W650 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 W650 features.

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.

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

4.1.2 ENERVISTA 650 SETUP SOFTWARE OVERVIEW

4

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 rel ay settings via relay data view windows, and th en
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

• P rotection 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.

GEK-113032A W650 Wind Generator Protection System 4-1

4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES.

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 W650 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

4.1.2.6 ONE LINE DIAGRAMS

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

4-2 W650 Wind Generator Protection Syst em GEK-113032A

4 HUMAN INTERFACES. 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

Main Menu bar

Main Icon bar

4

Working Area

Status bar

Figure 4–1: ENERVISTA 650 SETUP MAIN SCREEN

GEK-113032A W650 Wind Generator Protection System 4-3

4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES.

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.

4

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.

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 p ort 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.

4-4 W650 Wind Generator Protection Syst em GEK-113032A

4 HUMAN INTERFACES. 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE

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 communica tion 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 . W ith rel ay no t co mmunica tin g,
a message “650 Setup is not talking to a W650” will be shown and ON button wi ll be enable. Pressing this button, 650
Setup start communicating with the relay.

With relay communicating a message “650 Setup is now talking to a W650” will be shown and OFF will be enable. Pressing
this button, communications between relay and PC will be closed.

4

4.1.4.3 COMMUNICATION OPTIMIZATION:

The parameters shown on the bottom right window (Communica tion optimization) can improve co mmunication , 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.

GEK-113032A W650 Wind Generator Protection System 4-5

4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES.

File management with EnerVista 650 Setup software:

4

4.1.5 FILE MANAGEMENT

4-6 W650 Wind Generator Protection Syst em GEK-113032A

4 HUMAN INTERFACES. 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE

(

)

y

p(

)

(

)

gn(

pp

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

Is the relay
completely

configured?

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

4

YES

Save *.650 settings & configuration file

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

well as the *.650 for further logic changes.

Figure 4–3: OFF-LINE MODE FILE MANAGEMENT

GEK-113032A W650 Wind Generator Protection System 4-7

4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES.

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
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.

4

Contents

How to save

How to open

How to
transfer to
relay

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”)
LaunchLogic 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”

4-8 W650 Wind Generator Protection Syst em GEK-113032A

4 HUMAN INTERFACES. 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE

In case of using element libraries (either existing (“File Library>Open Library”) or created by the user (“File Library>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 modification s; 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

4

GEK-113032A W650 Wind Generator Protection System 4-9

4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES.

(

)

y

p(

)

(

)

y

r

4.1.5.2 ON LINE MODE

4

NO

Run EnerVista 650 Setup

Connect to the relay

“Communication>Computer>ON”

Modify and send to the

relay protection Settings

and rela

configuration

Is it necessary to

program

additional logic?

YES

Launch the Logic Configuration tool in EnerVista

650 Setu

“Setpoint>Logic Configuration”

Create new or modify the existing logic

“File>Open Project”

NO

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

4-10 W650 Wind Generator Protection System GEK-113032A

4 HUMAN INTERFACES. 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

ontents

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.

4

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.

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”)

GEK-113032A W650 Wind Generator Protection System 4-11

4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES.

4.1.6 ENERVISTA 650 SETUP MENUS 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 > Language ” 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

OPERATIONS
(*)

NA

NA

NA

NA

COMMUNICATION SECURITY VIEW HELP

ModBus
Memory
Map

Languages
(**)

Upgrade firmware
version (*)

Upgrade operating
system (*)

Upgrade 650 Web
Server

Upload info files to
relay

Download info files
from relay

Change
Password

User
Management

4

FILE SETPOINT ACTUAL

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

Save As
(**)

Close (**)
Config File

Converter
Properties

(**)
Get info

from relay
(*)

Send info
to relay (*)

Print Setup
(**)

Print
Preview
(**)

Print (**) NA
Print to file

(**)
Exit NA

System Setup Status NA Modem (*)

Protection
Elements

Control
Elements

Inputs/Outputs Records (*) NA

Relay
Configuration

Logic
Configuration

Clock (*) NA

Metering NA Troubleshooting (*)

Inputs/Outputs NA Calibration (*)

Instruction
Manual

About
EnerVista
650 Setup

4-12 W650 Wind Generator Protection System GEK-113032A

4 HUMAN INTERFACES. 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE

4.1.7 FILE MENU OVERVIEW

Table 4–4: GENERAL OVERVIEW OF FILE MENU:

FILE

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

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

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

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

4

GEK-113032A W650 Wind Generator Protection System 4-13

4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES.

4.1.7.1 OPEN, SAVE AS AND CLOSE

In these options, the program opens a dialog box (with default path to Files> Config program fold er) 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.

4

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, Communica tion, 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 th e ”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 “Language”, ”Upgrade firmware version” and “Upgrade Operating system” options.

4-14 W650 Wind Generator Protection System GEK-113032A

4 HUMAN INTERFACES. 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:

4

Figure 4–7: FILE PROPERTIES MENU

GEK-113032A W650 Wind Generator Protection System 4-15

4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES.

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:.

4

Figure 4–8: PRINT PREVIEW OF SETTINGS FILE

c) PRINT

In this option, the program will print the relay configuratio n using the PC default (active) printer on port COMx or LPT. This
option is active only in off-line mode, in file edition, an d 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.

4-16 W650 Wind Generator Protection System GEK-113032A

4 HUMAN INTERFACES. 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

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 and 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).

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

4

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, CAN Open 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”

GEK-113032A W650 Wind Generator Protection System 4-17

4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES.

e) COMMUNICATION SETTINGS

This section details the settings related to communication parameters for the different protocols available in the W650.

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

COMMUNICATION
SETTINGS

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

Ethernet communication parameters for COM3 (IP Address, Netmask,
Gateway IP)
NOTE: The ModBus Slave address used by Ethernet ports is the one set
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.

TCP Port, Common Addr of ASDU, Cyclic Meter Period and,
Synchronization Event settings.

4

Network (Ethernet)

ModBus Protocol

DNP3 Slave

IEC 870-5-104,
SNTP (*) Sinchronization over Ethernet settings

CAN Open Node ID and Baud for CANopen protocol

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

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 W650. 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.

2

t, KI2t Integ. Time, Maximum

2

t counters, and the

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

4-18 W650 Wind Generator Protection System GEK-113032A

4 HUMAN INTERFACES. 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE

4.1.8.3 PROTECTION ELEMENTS

This option shows all the protection-grouped elements available in the rel ay 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).

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 Directional 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

Negative sequence time overcurrent function
All under and overvoltage grouped functions for phases, neutral,

auxiliary voltage and voltage unbalance.

th

current input)

th

4

GEK-113032A W650 Wind Generator Protection System 4-19

4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES.

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)
Phase IOC Low Phase instantaneous overcurrent, low level (50PL)
Phase Directional Phase directional unit (67P). Quadrature Voltage for polarization

NEUTRAL
CURRENT

Neutral TOC Neutral time overcurrent (51N)
Neutral IOC Neutral instantaneous overcurrent (50N)
Neutral Directional Neutral directional unit (67N). Voltage, current and dual polarization.

GROUND
CURRENT

Ground TOC Ground time overcurrent (51G)

4

SENSITIVE
GROUND
CURRENT

NEGATIVE
SEQUENCE
CURRENT

VOLTAGE
ELEMENTS

POWER

Ground IOC Ground instantaneous overcurrent (50G)
Ground Directional Ground directional unit (67G). Voltage, current and dual polarization.

Sensitive Ground TOC Sensitive ground time overcurrent (51SG)
Sensitive Ground IOC Sensitive ground instantaneous overcurrent (50SG)

Sensitive Ground
Directional

Negative Sequence
TOC

Phase UV Phase undervoltage (27P)
Phase OV Phase overvoltage (59P)
Neutral OV High Neutral overvoltage, high level (59NH)
Neutral OV Low Neutral overvoltage, low level (59NL)
Auxiliary OV Auxiliary overvoltage (59X)
Auxiliary UV Auxiliary undervoltage (27X)
Voltage Unbalance Voltage unbalance (60V)

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

Sensitive ground directional unit (67SG)

Negative sequence time overcurrent (46P)

4-20 W650 Wind Generator Protection System GEK-113032A

4 HUMAN INTERFACES. 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

W650 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 four setting
groups (in this mode, protection units are grouped in four independent

Setting Group

Underfrequency Underfrequency unit (81U). Grouped element
Overfrequency Overfrequency unit (81O). Grouped element
Autoreclose Recloser (79). Not grouped, a single unit provided
Breaker Failure Breaker failure (50BF). Not grouped, a single unit provided
VT Fuse Failure Fuse Failure (VTFF). Not grouped, a single unit provided

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 recloser, fuse failure, breaker failure, synchronism, and breaker
settings are not involved in the tabled groups concept.

4

GEK-113032A W650 Wind Generator Protection System 4-21

4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES.

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 (*)

Remote Comms.

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 W650. 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 menu allows configuring remote inputs coming from other devices
through GSSE messages.

This section shows the settings related to inputs and outputs for the different boards available in W650 (F , G).

4

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

CONTACT I/O

Board F Board locate d in first slot, always connected.
Board G

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

4-22 W650 Wind Generator Protection System GEK-113032A

4 HUMAN INTERFACES. 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE

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

Remote outputs

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.

Up to 32 DNA bits and 64 userSt bits to be transmitted to remote devices
over CAN using GSSE messages

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 Figure 4–10:

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

4

GEK-113032A W650 Wind Generator Protection System 4-23

4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES.

The following figures show an example of the default factory configuration for W650.

4

Figure 4–9: RELAY CONFIGURATION

Figure 4–10: HMI CONFIGURATION

4-24 W650 Wind Generator Protection System GEK-113032A

4 HUMAN INTERFACES. 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE

4.1.8.7 LOGIC CONFIGURATION

This logic configuration allows creating more complex con figurations, 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:

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

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

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.

block diagram (FDB).

into libraries and be distributed in different PLC projects.

4

GEK-113032A W650 Wind Generator Protection System 4-25

4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES.

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.

4

Figure 4–11: CLOCK

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 fron t 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.

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4 HUMAN INTERFACES. 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE

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
CAN Open Information related to OPENcan protocol

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.

4

Table 4–17: DIFFERENT CONTROL ACTUAL VALUES INCLUDED IN THE CONTROL ELEMENTS MENU

CONTROL
ELEMENTS

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

Autoreclose S tatus signals for autoreclose function (79). Close signal, recloser status

Breaker Failure Status signals for breaker failure function (50BF).
VT Fuse Failure Fuse failure detection signal.
Setting Groups Status signals (activations and blocks) for the relay setting group change.

units.

(ready, lockout, etc), block signals after each shot.

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

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4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES.

T able 4–18: ACTUAL VALUES INCLUDED IN THE PROTECTION MENU

PROTECTION

4

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 directional power

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, and auxiliary
under and over voltage.

units.

th

current input).

th

current input).

T able 4–19: ACTUAL VALUES RELATED TO RECORDING FUNCTIONS IN THE RECORDS STATUS MENU:

RECORD
STATUS

Fault Reports This menu shows the fault repor t 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.

2

closings, (KI)

t counters, alarm signal for (KI)2t, etc.

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4 HUMAN INTERFACES. 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE

4.1.9.3 METERING

The Metering menu includes all the measurements available in the device. Primary and secon dary 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.
Remote Outputs States of remote outputs
Remote Inputs Status of remote device and remote inputs
Analog Inputs (*) Measurements coming from analog inputs (DCMA)

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.
T o 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).

4

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

4.1.9.5 RECORDS

The Records menu is only available in on line mode and includes the possibili ty to retrieve all the records availabl e in the
device. By serial or Ethernet.

Table 4–22: GENERAL OVERVIEW OF RECORDS MENU:

RECORDS (*)

Event recorder (*) Retrieval and visualization of snapshot event (all and new), control

Waveform capture (*) Retrieval of oscillography files, by serial or Ethernet.
Fault Report (*) Retrieval and visualization of fault report files, by serial or Ethernet.
Data logger (*) Retrieval and visualization of data logger files. Only by Ethernet.

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

events and alarm panel. By serial or Ethernet (ModBus RTU or TCP/IP)

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4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES.

4.1.10 OPERATIONS MENU OVERVIEW

Option only available in on line mode, showing all the operations previously configured in the relay with their corresponding
texts.

Table 4–23: GENERAL OVERVIEW OF OPERATIONS MENU:

OPERATIONS

Operation 1 (*) Entry to first operation (with its corresponding text)

... ...

Operation 24 (*)

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

Entry to 24

th

operation (with its corresponding text)

4.1.11 COMMUNICATION MENU OVERVIEW

The communication menu includes the computer screen to start communicating with the relay, the different update
procedures available in device: firmware, operative system, web server and other file storing capabilities (upload and

4

download info files to/from relay).
For more detail information go to section 4.1.4 for co mmunication menus description and to section 5 for flash memory

update procedures.

Table 4–24: GENERAL OVERVIEW OF COMMUNICATION MENU:

COMMUNICATION

Computer Menu to start communication with the relay.
Modem (**) Menu to set modem communication parameters (only available if control

Troubleshooting (*) Menu that Lets the user to perform reading or writing in ModBus

Calibration (*) Retrieval and store calibration settings from/to relay.
Upgrade firmware

version (**)
Upgrade operating

system (**)
Upgrade 650 web

server
Upload info files to

relay
Download info files

from relay

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

type is set to modem in computer menu).

addresses, for verifying communications and access to different
positions in the ModBus memory map.

Menu to update the relay firmware version through Ethernet

Menu to update the relay boot code (front RS323 and Ethernet
connection)

Menu to update the web server application (if available)

Hard disk storage of settings and configuration files on the relay.

Retrieval of settings and configuration files that had been previously
stored in the relay hard disk.

The rest of options available in the Communication menu in EnerVista 650 Setup are:

• Modem: Allows configuring the unit for remote communications via modem, using telephonic l ine. It i s o nly avail able if
the relay is not communicating and if modem has been select on Communication>compu te r control type selection. Go
to “Communication>Modem”

• Troubleshooting (Serial or Ethernet connection): Lets the user to perform reading or writing in ModBus a ddresses, for
verifying communications and access to different positions in the ModBus memory map. Only available if the
communication has already been established. Go to “Communication>Troubleshooting”. An example is provided in
Figure 4–12:

Figure 4–12: COMMUNICATION TROUBLESHOOTING SCREEN

• Calibration (Serial or Ethernet connection): Allows retrieving the unit calibration settings and storing them in a file (with
extension *.cal). For reading or storing the calibration settings in the relay go to “Communications>Calibration>Get

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4 HUMAN INTERFACES. 4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE

or Set calibration settings” and select the intended calibration file. The calibration retrieval process is necessary to
be performed before updating the unit operative system, when the operating system is updated all the data in the relay
is deleted, including the factory calibration settings. When only the firmware is updated (for versions higher than 1.50),
the calibration settings are automatically saved in the relay.

• Upgrade firmware version (Ethernet connection): Go to “Communications>Upgrade firmwa re version”, this menu

allows the user to update the firmware version of the relay through Ethernet communication. Firmware is related to the
relay internal program, designed by GE Multilin, which performs the protection and control functions, and which is run
by the relay main microprocessor.

• Upgrade operating system (Serial and Ethernet connection): Go to “Communications>Upgrade operating system”.

This option allows the user to update the relay operative system. The operative system or OS is the program that
supports the firmware and provides auxiliary services for access to electronic devices included in the relay.

IMPORTANT NOTE:

READ CAREFULLY THE FLASH MEMORY UPDATE PROCED URE DESCRIBED IN
SECTION 9 AND CLOSE ALL THE RUNNING APPLICATIONS BEFORE
PERFORMING FIRMWARE AND OPERATIVE SYSTEM UPDATING PROCCESS

Before updating firmware check that the firmware version that is going to be updated
match the operative system version of the relay. Otherwise it is necessary to update the
operative system before proceeding to update the firmware. Other combinations of
firmware and operative system different from the listed below will not be operative

The operative system version is available in the logotype main screen in HMI; it is the
number between brackets in the first line, e.g. W6501.70 (2.35). The operative system
version is 2.35

4

Firmware version up to 1.5X must be used with Boot Code 2.30 (or 2.20 and 2.35)
Firmware version from 1.6X up to 1.8X must be used with Boot Code 2.35
Firmware version 2.00 must be used with Boot Code 3.00

Thanks to the use of a double flash memory, one with the Bootcode startup program and the operative system, and a
second one with the application program (firmware), a high reliability is guaranteed when updating the unit firmware, as
even if the case of a communication breakdown during the firmware upg rade process, we can retry the process for an
unlimited number of times.

• Upgrade 650 web server (Ethernet connection): Go to “Communications> Upgrade 650 web server”. The relay web

server application can be updated to further versions (if available) using this menu without modifying the relay
operative system.

• Upload info files to relay (Ethernet connection): Go to “Communications>Upload info files to relay”. This

functionality is used to store setting files (*.650) inside the relay, as well as auxiliary files used by the programmable
logic graphical editor (*.pep, *.aut, *.lib).

• Download info files from relay (Ethernet connection): Go to “Communications>Download info files from relay”.

This functionality is used for retrieving the files (*.650 and *.pep, *.aut, *.lib) th at have been previously stored in the
relay flash memory.

Important Note:

*.650 files contain protection, control settings, relay configuration and compiled logic
equations. This file can be retrieved from the relay, using the “File>Get info from

relay” option in EnerVista 650 Setup (through serial or Ethernet communication).
“File>Send info to relay” option stores this *.650 file in the relay.

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4.1 ENERVISTA 650 SETUP SOFTWARE INTERFACE 4 HUMAN INTERFACES.

*.pep, *.aut and *.lib files contain the logic configuration projects necessary to modify the
logic (virtual outputs) in the relay. These files can be stored in the relay, using the
“Communication>Upload info files to relay” option in EnerVista 650 Setup (through
Ethernet communication). They can be retrieved using “Communication>Download
info files to relay” option in EnerVista 650 Setup program (Ethernet communication).
Take into account tha t the *.pep, *.aut and lib rary files are necessary to modify the PLC
logic (virtual outputs). Without these files setting and configuration can be modified but
not logic equations (virtual outputs). It is advisable to use the
“Communication>Upload info files to relay” option to store these logic configuration
files into the relay.

It is important to distinguish between “Send / Get info to relay” and “Upload /
Download info files to/from relay”. “File>Send/Get info to relay” sends/gets
settings and configuration and compiled logic equation to/from the relay (*.65 0 format),
and the relay automatically starts working with the new settings once they a re stored.
“Communications>Upload/Download info files to relay“, stores/retrieves in the
relay hard disk: settings, configuration and compiled logic equations (*.650) besid es the
PLC files (*.pep, *.aut, *.lib). This is only a physical storage (file backup).

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