GE 350-A9, 350-AD, 350-AA, 350-AE, 350-AF Instruction Manual

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Page 1

LISTED

52TL

IND.CONT. EQ.

E83849

Grid Solutions

350

Feeder Protection System

Feeder protection and control

Instruction manual

350 revision: 2.3x

Manual P/N: 1601-9086-AN

GE publication code: GEK-113507W

*1601-9086-AN*

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© 2017 GE Multilin Inc. All rights reserved. GE Multilin Inc. 350 Feeder Protection System instruction manual for revision 2.3x. 350 Feeder Protection System, EnerVista, EnerVista Launchpad, and EnerVista 3 Series

Setup are trademarks or registered trademarks of GE Multilin Inc. The contents of this manual are the property of GE Multilin Inc. This documentation is

furnished on license and may not be reproduced in whole or in part without the permission of GE Multilin Inc. The content of this manual is for informational use only and is subject to change without notice.

Part number: 1601-9086-AN (June 2017)

Storage

Store the unit indoors in a cool, dry place. If possible, store in the original packaging. Follow the storage temperature range outlined in the Specifications.

To avoid deterioration of electrolytic capacitors, power up units that are stored in a deenergized state once per year, for one hour continuously.

This product cannot be disposed of as unsorted municipal waste in the European Union. For proper recycling return this product to your supplier or a designated collection point. For more information go to www.recyclethis.info.

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Note

GENERAL SAFETY PRECAUTIONS - 350

• Failure to observe and follow the instructions provided in the equipment manual(s) could cause irreversible damage to the equipment and could lead to property damage, personal injury and/or death.

• Before attempting to use the equipment, it is important that all danger and caution indicators are reviewed.

• If the equipment is used in a manner not specified by the manufacturer or functions abnormally, proceed with caution. Otherwise, the protection provided by the equipment may be impaired and can result in Impaired operation and injury.

• Caution: Hazardous voltages can cause shock, burns or death.

• Installation/service personnel must be familiar with general device test practices, electrical awareness and safety precautions must be followed.

• Before performing visual inspections, tests, or periodic maintenance on this device or associated circuits, isolate or disconnect all hazardous live circuits and sources of electric power.

• Failure to shut equipment off prior to removing the power connections could expose you to dangerous voltages causing injury or death.

• All recommended equipment that should be grounded and must have a reliable and un-compromised grounding path for safety purposes, protection against electromagnetic interference and proper device operation.

• Equipment grounds should be bonded together and connected to the facility’s main ground system for primary power.

• Keep all ground leads as short as possible.

• At all times, equipment ground terminal must be grounded during device operation and service.

• In addition to the safety precautions mentioned all electrical connections made must respect the applicable local jurisdiction electrical code.

• Before working on CTs, they must be short-circuited.

• LED transmitters are classified as IEC 60825-1 Accessible Emission Limit (AEL) Class 1M. Class 1M devices are considered safe to the unaided eye. Do not view directly with optical instruments.

• This product uses optical electronic devices (line or point sensors) to sense arc flash fault conditions. It is recommended to follow proper housekeeping measures and establish a regularly scheduled preventive maintenance routine to ensure proper device operation.

• This product itself is not Personal Protective Equipment (PPE). However, it can be used in the computation of site-specific arc flash analysis when the arc flash option is ordered. If a new appropriate Hazard Reduction Category code for the installation is determined, the user should follow the cautions mentioned in the arc flash installation section.

• This guide is intended to provide protective relay application guidance to mitigate arc flash incident energy. This guide does not endorse energized work. This guide does not claim that protective relaying can totally protect personnel from the dangers of an arc flash. The only way to completely prevent injury from arc flash events is to de-energize the equipment and properly follow safe lockout/tagout procedures to ensure the equipment remains de-energized.

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Safety words and definitions

The following symbols used in this document indicate the following conditions

Note

Indicates a hazardous situation which, if not avoided, will result in death or serious injury.

Note

Indicates a hazardous situation which, if not avoided, could result in death or serious injury.

Note

Indicates a hazardous situation which, if not avoided, could result in minor or moderate injury.

Note

Indicates practices not related to personal injury.

For further assistance

For product support, contact the information and call center as follows:

GE Grid Solutions 650 Markland Street Markham, Ontario Canada L6C 0M1 Worldwide telephone: +1 905 927 7070 Europe/Middle East/Africa telephone: +34 94 485 88 54 North America toll-free: 1 800 547 8629 Fax: +1 905 927 5098 Worldwide e-mail: multilin.tech@ge.com Europe e-mail: multilin.tech.euro@ge.com Website: http://www.gegridsolutions.com/multilin

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1. INTRODUCTION Overview ................................................................................................................................1 - 1

Description of the 350 Feeder Protection System..............................................1 - 2

350 order codes..................................................................................................................1 - 5

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

Password security....................................................................................................................1 - 9

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

Metering........................................................................................................................................1 - 14

Data capture ..............................................................................................................................1 - 14

Control...........................................................................................................................................1 - 15

Monitoring....................................................................................................................................1 - 17

Inputs .............................................................................................................................................1 - 17

Outputs..........................................................................................................................................1 - 18

Power supply..............................................................................................................................1 - 20

Communications ......................................................................................................................1 - 21

Testing and certification .......................................................................................................1 - 22

Physical.........................................................................................................................................1 - 23

Environmental............................................................................................................................1 - 24

2. INSTALLATION Mechanical installation ...................................................................................................2 - 1

Dimensions..................................................................................................................................2 - 2

Product identification .............................................................................................................2 - 4

Mounting ......................................................................................................................................2 - 4

Standard panel mount.........................................................................................................2 - 4

Mounting using the S1/S2/MDP/IAC or SR735 adapter plate............................2 - 8

Drawout unit withdrawal and insertion.........................................................................2 - 11

IP20 Cover (optional) ...............................................................................................................2 - 12

Arc flash sensors.......................................................................................................................2 - 13

Sensor fiber handling & storage......................................................................................2 - 14

Point sensor installation......................................................................................................2 - 15

Loop sensor installation.......................................................................................................2 - 19

Electrical installation ........................................................................................................2 - 22

Typical wiring diagrams........................................................................................................2 - 23

350 Terminal identification..................................................................................................2 - 25

Wire range...................................................................................................................................2 - 28

Phase sequence and transformer polarity ..................................................................2 - 28

Current inputs ............................................................................................................................2 - 29

Ground and sensitive ground CT inputs ........................................................................2 - 29

Zero sequence CT installation ............................................................................................2 - 30

Voltage inputs............................................................................................................................2 - 31

Control power ............................................................................................................................2 - 31

Contact inputs ...........................................................................................................................2 - 32

Trip and Close output relays...............................................................................................2 - 33

Serial communications ..........................................................................................................2 - 35

IRIG-B .............................................................................................................................................2 - 36

3. INTERFACES Front control panel interface........................................................................................3 - 2

Description ..................................................................................................................................3 - 3

Display...........................................................................................................................................3 - 4

Working with the Keypad...................................................................................................3 - 4

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL i

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LED status indicators - Front panel with non-programmable LEDs................3 - 6

LED status indicators - Front panel with programmable LEDs .......................... 3 - 7

Relay messages........................................................................................................................ 3 - 8

Target messages.....................................................................................................................3 - 8

Self-test errors..........................................................................................................................3 - 8

Flash messages.......................................................................................................................3 - 10

Software setup....................................................................................................................3 - 11

Quick setup - Software interface...................................................................................... 3 - 11

EnerVista 3 Series Setup Software................................................................................... 3 - 12

Hardware and software requirements.........................................................................3 - 12

Installing the EnerVista 3 Series Setup software......................................................3 - 12

Upgrading the software.......................................................................................................3 - 15

Connecting EnerVista 3 Series Setup to the relay ...................................................3 - 15

Configuring serial communications...............................................................................3 - 15

Using the Quick Connect feature....................................................................................3 - 16

Configuring Ethernet communications........................................................................3 - 17

Connecting to the relay.......................................................................................................3 - 18

Working with setpoints and setpoint files .................................................................... 3 - 19

Engaging a device..................................................................................................................3 - 19

Entering setpoints...................................................................................................................3 - 19

Setting programmable LEDs..............................................................................................3 - 21

File support ................................................................................................................................3 - 22

Using setpoint files.................................................................................................................3 - 22

Downloading and saving setpoint files ........................................................................3 - 23

Adding setpoint files to the environment....................................................................3 - 23

Creating a new setpoint file...............................................................................................3 - 24

Upgrading setpoint files to a new revision .................................................................3 - 25

Printing setpoints and actual values.............................................................................3 - 26

Printing actual values from a connected device.....................................................3 - 26

Loading setpoints from a file.............................................................................................3 - 27

Uninstalling files and clearing data................................................................................3 - 27

Upgrading relay firmware ...................................................................................................3 - 28

Loading new relay firmware.............................................................................................3 - 28

Advanced EnerVista 3 Series Setup features.............................................................. 3 - 30

Flexcurve editor.......................................................................................................................3 - 30

Transient recorder (Waveform capture).......................................................................3 - 31

Protection summary .............................................................................................................3 - 34

Password security..................................................................................................................3 - 36

4. ACTUAL VALUES Actual values overview ...................................................................................................4 - 1

A1 Status................................................................................................................................4 - 2

Clock............................................................................................................................................... 4 - 2

Contact inputs ...........................................................................................................................4 - 2

Output relays .............................................................................................................................4 - 2

Logic elements ..........................................................................................................................4 - 3

Virtual inputs ..............................................................................................................................4 - 3

Remote inputs ........................................................................................................................... 4 - 3

Remote outputs ........................................................................................................................4 - 3

Contact inputs summary ..................................................................................................... 4 - 3

Output relays summary ....................................................................................................... 4 - 4

Logic elements summary .................................................................................................... 4 - 4

GOOSE status............................................................................................................................. 4 - 4

GOOSE HDR status ..................................................................................................................4 - 5

61850 status ..............................................................................................................................4 - 5

RTC Sync Source ...................................................................................................................... 4 - 5

Redundancy ...............................................................................................................................4 - 5

ii 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

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IEEE 1588 PTP (Precision Time Protocol) ........................................................................4 - 6

A2 Metering...........................................................................................................................4 - 7

Current...........................................................................................................................................4 - 7

Voltage ..........................................................................................................................................4 - 8

Power .............................................................................................................................................4 - 9

Energy ...........................................................................................................................................4 - 9

Current Demand.......................................................................................................................4 - 10

Power Demand..........................................................................................................................4 - 10

Thermal capacity .....................................................................................................................4 - 11

Clear energy ...............................................................................................................................4 - 11

Clear current demand ...........................................................................................................4 - 11

Clear power demand..............................................................................................................4 - 11

A3 Records ............................................................................................................................4 - 12

Event records .............................................................................................................................4 - 12

Transient records .....................................................................................................................4 - 14

Fault report..................................................................................................................................4 - 14

Clear event record ...................................................................................................................4 - 15

Clear transient record ............................................................................................................4 - 15

Clear thermal capacity record...........................................................................................4 - 15

Clear fault report ......................................................................................................................4 - 16

A4 Target messages.........................................................................................................4 - 17

5. QUICK SETUP -

Quick Setup settings.........................................................................................................5 - 2

FRONT CONTROL PANEL

6. SETPOINTS Setpoints Main Menu........................................................................................................6 - 1

Setpoint entry methods ........................................................................................................6 - 3

Common setpoints .................................................................................................................6 - 3

Logic diagrams..........................................................................................................................6 - 4

Setting text abbreviations ....................................................................................................6 - 5

S1 Relay setup.....................................................................................................................6 - 6

Clock...............................................................................................................................................6 - 6

350 Real Time Clock...............................................................................................................6 - 8

Password security....................................................................................................................6 - 9

Access passwords..................................................................................................................6 - 10

Communications ......................................................................................................................6 - 12

RS485 interface .......................................................................................................................6 - 12

Ethernet.......................................................................................................................................6 - 12

Redundancy mode 13

Modbus........................................................................................................................................6 - 14

IEC 60870-5-103 serial communication......................................................................6 - 15

IEC60870-5-104 protocol....................................................................................................6 - 15

DNP communication.............................................................................................................6 - 16

3 Series IEC 61850 GOOSE details...................................................................................6 - 16

OPC-UA Settings......................................................................................................................6 - 17

Event recorder ...........................................................................................................................6 - 18

Transient recorder ...................................................................................................................6 - 19

Fault report..................................................................................................................................6 - 21

Front panel with non-programmable LEDs .................................................................6 - 22

Front panel with programmable LEDs ...........................................................................6 - 22

Installation...................................................................................................................................6 - 24

S2 System Setup ................................................................................................................6 - 25

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL iii

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Current sensing......................................................................................................................... 6 - 25

Voltage sensing ........................................................................................................................ 6 - 26

Power system............................................................................................................................6 - 28

Breaker.......................................................................................................................................... 6 - 28

User curve ................................................................................................................................... 6 - 29

FlexCurves................................................................................................................................... 6 - 30

S3 Protection........................................................................................................................6 - 31

Time overcurrent curves....................................................................................................... 6 - 31

Phase timed overcurrent (51P) ..........................................................................................6 - 40

Phase instantaneous overcurrent protection (50P)................................................. 6 - 43

Phase directional (67P) ..........................................................................................................6 - 45

Ground/Sensitive Ground timed overcurrent protection (51G/SG) .................. 6 - 48

Ground/Sensitive Ground instantaneous overcurrent protection (50G/SG) 6 - 51

Ground directional (67G/SG)...............................................................................................6 - 53

Neutral timed overcurrent (51N).......................................................................................6 - 58

Negative sequence timed overcurrent protection (51_2)..................................... 6 - 61

Neutral instantaneous overcurrent protection (50N) ............................................. 6 - 64

Neutral directional (67N).......................................................................................................6 - 66

Negative sequence instantaneous overcurrent (50_2)..........................................6 - 71

Phase undervoltage (27P) .................................................................................................... 6 - 73

Phase overvoltage (59P) .......................................................................................................6 - 76

Neutral overvoltage (59N).................................................................................................... 6 - 78

Negative sequence overvoltage (59_2) ......................................................................... 6 - 80

Auxiliary undervoltage (27X)............................................................................................... 6 - 82

Auxiliary overvoltage (59X)..................................................................................................6 - 85

Underfrequency (81U) ........................................................................................................... 6 - 87

Overfrequency (81O) .............................................................................................................. 6 - 89

Thermal Overload (49)............................................................................................................6 - 91

Wattmetric ground fault (32N)........................................................................................... 6 - 95

Directional power (32)............................................................................................................6 - 99

Broken conductor (I1/I2 or 46BC) .....................................................................................6 - 103

Positive sequence undervoltage (27_1)......................................................................... 6 - 106

Volts per Hertz (24) .................................................................................................................. 6 - 109

S4 Controls............................................................................................................................6 - 115

Change setpoint group .........................................................................................................6 - 115

Virtual inputs ..............................................................................................................................6 - 118

Logic elements ..........................................................................................................................6 - 118

Breaker control .........................................................................................................................6 - 131

Cold load pickup (CLP)............................................................................................................ 6 - 132

Breaker failure (50BF) ............................................................................................................. 6 - 135

CT failure (60CTS)...................................................................................................................... 6 - 137

Autorecloser (79)....................................................................................................................... 6 - 139

Synchrocheck (25) ...................................................................................................................6 - 145

Second harmonic inhibit.......................................................................................................6 - 150

Lockout (86)................................................................................................................................. 6 - 152

VT fuse fail (VTFF or 60VTS).................................................................................................. 6 - 154

Arc flash protection................................................................................................................. 6 - 155

S5 Inputs/Outputs .............................................................................................................6 - 158

Contact inputs ...........................................................................................................................6 - 158

Output relays .............................................................................................................................6 - 159

Output Relay 1 "Trip".............................................................................................................6 - 159

Output Relay 2 "Close"..........................................................................................................6 - 161

Auxiliary Output Relays 3 to 6..........................................................................................6 - 163

Critical Failure Relay #7.......................................................................................................6 - 163

Virtual inputs ..............................................................................................................................6 - 166

Remote inputs ........................................................................................................................... 6 - 167

iv 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

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S6 Monitoring.......................................................................................................................6 - 168

Demand ........................................................................................................................................6 - 168

Current demand......................................................................................................................6 - 169

Real Power .................................................................................................................................6 - 171

Reactive Power ........................................................................................................................6 - 173

Apparent Power.......................................................................................................................6 - 175

7. MAINTENANCE M1 Relay information.......................................................................................................7 - 1

M3 Breaker maintenance...............................................................................................7 - 3

Trip coil ..........................................................................................................................................7 - 3

Close coil.......................................................................................................................................7 - 6

Breaker trip counter ................................................................................................................7 - 9

Breaker health ...........................................................................................................................7 - 11

Reset counters...........................................................................................................................7 - 14

M4 Breaker monitor..........................................................................................................7 - 15

M5 Relay maintenance ...................................................................................................7 - 16

Ambient temperature.............................................................................................................7 - 16

M7 Testing .............................................................................................................................7 - 18

Force LEDs ...................................................................................................................................7 - 18

Force output relays .................................................................................................................7 - 19

General maintenance ......................................................................................................7 - 20

In-service maintenance ........................................................................................................7 - 20

Out-of-service maintenance...............................................................................................7 - 20

Unscheduled maintenance (system interruption) ....................................................7 - 20

A. APPENDIX Warranty................................................................................................................................A - 1

Repairs ....................................................................................................................................A - 2

Change notes.......................................................................................................................A - 3

Manual Revision history........................................................................................................A - 3

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL v

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vi 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

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Grid Solutions

350 Feeder Protection System

Chapter 1: Introduction

Overview

Introduction

The 350 is a microprocessor-based relay for primary and backup over-current protection of medium and low voltage distribution feeders. The relay is also suitable for providing over-current and backup protection for small and medium size motors, transformers, generators, and distribution bus-bars. The small footprint and the withdrawable option make the 350 combination of proven hardware, a variety of protection and control features, and communications, makes the relay ideal for total feeder protection and control. Equipped with serial (RS485), USB, and Ethernet ports with the possibility of adding redundancy (IEC62439, PRP and HSR), and a wide selection of protocols such as Modbus, DNP3.0, IEC 60870-5-103, 60870-5-104, IEC61850 GOOSE, OPC-UA, the 350 for MCCs and PCCs, SCADA and inter-relay communications. The 350 excellent transparency with respect to power system conditions and events, through its four-line 20-character display, as well as the EnerVista 3 Conveniently located LEDs provide indication of relay operation, alarm, and pickup, as well as breaker, and relay status.

The 350 relay provides the following key benefits:

• Withdrawable small footprint – saves on rewiring and space. (non-draw out version is also available)

• Multiple protection groups with the added flexibility of switching through a wide selection of overcurrent protection and control features.

• Fast setup (Quick Setup) menu for power-system setup and a simple overcurrent protection configuration.

• Large four-line LCD display, LEDs, and an easy-to-navigate keypad.

• Multiple communication protocols for simultaneous access when integrated into monitoring and control systems.

relay ideal for panel mounting on either new or retrofit installations. The

relay is the best-in-class

relay provides

Series Setup program.

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 1–1

Page 12

DESCRIPTION OF THE 350 FEEDER PROTECTION SYSTEM CHAPTER 1: INTRODUCTION

Description of the 350 Feeder Protection System

CPU

Relay functions are controlled by two processors: a Freescale MPC5554 32-bit microprocessor measures all analog signals and digital inputs and controls all output relays; a Freescale MPC520B 32-bit microprocessor controls all the Ethernet communication protocols.

Analog Input and Waveform Capture

Magnetic transformers are used to scale-down the incoming analog signals from the source instrument transformers. The analog signals are then passed through a 960 Hz low pass anti-aliasing filter. All signals are then simultaneously captured by sample and hold buffers to ensure there are no phase shifts. The signals are converted to digital values by a 12-bit A/D converter before finally being passed on to the CPU for analysis.

Both current and voltage are sampled thirty-two times per power frequency cycle. These ‘raw’ samples are scaled in software, then placed into the waveform capture buffer, thus emulating a fault recorder. The waveforms can be retrieved from the relay via the EnerVista 3

Frequency

Frequency measurement is accomplished by measuring the time between zero crossings of the Bus VT phase A voltage. The signals are passed through a low pass filter to prevent false zero crossings. Sampling is synchronized to the Va-x voltage zero crossing which results in better co-ordination for multiple 350

Phasors, Transients, and Harmonics

Current waveforms are processed four times every cycle with a DC Offset Filter and a Discrete Fourier Transform (DFT). The resulting phasors have fault current transients and all harmonics removed. This results in an overcurrent relay that is extremely secure and reliable; one that will not overreach.

Processing of AC Current Inputs

The DC Offset Filter is an infinite impulse response (IIR) digital filter, which removes the DC component from the asymmetrical current present at the moment a fault occurs. This is done for all current signals used for overcurrent protection; voltage signals bypass the DC Offset Filter. This filter ensures no overreach of the overcurrent protection.

The Discrete Fourier Transform (DFT) uses exactly one sample cycle to calculate a phasor quantity which represents the signal at the fundamental frequency; all harmonic components are removed. All subsequent calculations (e.g. RMS, power, etc.) are based upon the current and voltage phasors, such that the resulting values have no harmonic components.

Protection Elements

Protection elements are processed up to four times every cycle to determine if a pickup has occurred or a timer has expired. The protection elements use RMS current/voltage, based on the magnitude of the phasor. Hence, protection is impervious to both harmonics and DC transients.

NOTE:

Arc Flash protection elements are processed up to 8 times every cycle.

Series Setup software for display and diagnostics.

relays on the same bus.

1–2 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 13

CHAPTER 1: INTRODUCTION DESCRIPTION OF THE 350 FEEDER PROTECTION SYSTEM

898742A7.CDR

A350 RELAYY

TRIP

BUS

LOAD

50G/

51G

50P 50N

METERING

TRANSIENT RECORDER

EVENT RECORDER FAULT REPORT

51N51P

50_2

111

27X

59P27P

59X

59_2 59N 81U 81O

CLP

50BF

1122

MONITORING

BUS VT

67P

51_2

67N

CTS

51G/SG 67G/SG50G/SG

I/I

27_1

VTFF

32N

50P HS

50G/SG

SENSORS

Figure 1-1: Functional block diagram

Table 1-1: ANSI device numbers and functions

ANSI Code 61850 Logical Node Description

24 PVPH Volts per Hertz 25 RSYN1 Synchrocheck 27_1 psseqPTUV1 Positive Sequence Undervoltage 27P phsPTUV1, phsPTUV2,

27X auxPTUV1 Auxiliary Undervoltage 32 PDOP1, PDOP2 Directional Power 32N ndPDOP Wattmetric Ground Fault I1/I2 (46BC) - Broken Conductor 49 PTTR1 Thermal Overload 50_2 ngseqPIOC1 Negative Sequence Overcurrent

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 1–3

50BF RBRF1 Breaker Failure 50G/SG gndPIOC1, gndPIOC2/

50N ndPIOC1, ndPIOC2 Neutral Instantaneous Overcurrent 50P phsPIOC1, phsPIOC2 Phase Instantaneous Overcurrent 51_2 ngseqPTOC1 Negative Sequence Time Overcurrent 51G/SG gndPTOC1/hsePTOC1 Ground/Sensitive Ground Time Overcurrent 51N ndPTOC1 Neutral Time Overcurrent 51P phsPTOC1 Phase Time Overcurrent 59_2 ngseqPTOV1,

phsPTUV3, phsPTUV4

hsePIOC1, hsePIOC2

ngseqPTOV2

Phase Undervoltage

Ground/Sensitive Ground Instantaneous Overcurrent

Negative Sequence Overvoltage

Page 14

DESCRIPTION OF THE 350 FEEDER PROTECTION SYSTEM CHAPTER 1: INTRODUCTION

ANSI Code 61850 Logical Node Description

59N ndPTOV1, nfPTOV2,

ndPTOV3, ndPTOV4

59P phsPTOV1, phsPTOV2,

phsPTOV3, phsPTOV4 59X auxPTOV1 Auxiliary Overvoltage 60CTS - CT Supervision 67G/SG gndRDIR1/hseRDIR1 Ground/Sensitive Ground Directional Element 67N ndRDIR1 Neutral Directional Element 67P phsRDIR1 Phase Directional Element 79 RREC1 Autoreclose 81O PTOF1, PTOF2, PTOF3,

PTOF4 81U PTUF2, PTUF2, PTUF3,

PTUF4 86 - Lockout CLP - Cold Load Pickup VTFF (60VTS) - Voltage Fuse Failure

- MMXU1 Voltage, Energy, Power Metering

Neutral Overvoltage

Phase Overvoltage

Overfrequency

Underfrequency

Table 1-2: Other device functions

Description

2nd Harmonic Blocking Arc Flash Detector Ambient Temperature Breaker Control Breaker Health Breaker Maintenance CT Failure Detection Data Logger Demand (in metering) Digital Counters DNP 3.0 Communications Event Recorder Fault Report Flexcurves HSR Communications IEC 60870-5-103 Communications IEC 60870-5-104 Communications IEC 61850 Communications IEC 61850 GOOSE Communications Lockout (86) Logic Elements Metering: current, voltage, power, PF, energy, frequency, 2nd harmonics Modbus User Map Modbus RTU Communications Modbus TCP Communications Non-volatile Latches OPC-UA Communications

1–4 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

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CHAPTER 1: INTRODUCTION 350 ORDER CODES

ACTUAL VALUES

COMMANDS

SETPOINTS

MAINTENANCE

ACTUAL VALUES

A1 STATUS

A2 METERING

A3 RECORDS

A4 TARGET MESSAGES

QUICK SETUP

RELAY STATUS

NOMINAL FREQUENCY

PH CT PRIMARY

PH CT SECONDARY

VT SEC. VOLTAGE

VT RATIO

AUX VT SECONDARY

AUX VT RATIO

PH TOC FUNCTION

NTRL TOC FNCTN

PH IOC1 FUNCTION

NTRL IOC1 FNCTN

▼

SETPOINTS

S1 RELAY SETUP

S2 SYSTEM SETUP

S3 PROTECTION

S4 CONTROLS

S5 INPUTS/OUTPUTS

▼

MAINTENANCE

M1 RELAY INFO

M3 BKR MAINTENANCE

M5 RELAY MAINT

M6 FACTORY SERVICE

M4 BKR MONITOR

▼

898756A3.cdr

[S]GND CT SECONDARY

S6 MONITORING

M7 TESTING

QUICK SETUP

[S]GND CT PRIMARY

VT CONNECTION

[S]GND TOC FUNCTION

[S]GND IOC1 FNCTN

Description

Output Relays PRP Communications Relay Maintenance Remote Inputs (32) Setpoint Groups (2) Test Mode Transient Recorder (Oscillography) Trip and Close Coil Monitoring User Curves User-programmable LEDs Virtual Inputs (32) Virtual Outputs (32)

Figure 1-2: Main Menu structure

350 order codes

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 1–5

The information to specify a 350 relay is provided in the following order code figure.

Page 16

350 ORDER CODES CHAPTER 1: INTRODUCTION

350  * * * * * * * * * * * *

Interface 350 ||||||||||| | 350 Feeder Protection System User Interface E | | | | | | | | | | | English without programmable LEDs

L | | | | | | | | | | | English with programmable LEDs

Phase Currents

a. Phase Current options PX/P0 and Ground Current options GX/G0 are only available with the non-drawout Case Design N.

PX|||||||||| No CT P0||||||||| | 1 A or 5 A configurable phase current inputs P1||||||||| | 1 A 3-phase current inputs P5||||||||| | 5 A 3-phase current inputs

Ground Currents

b. Ground Currents G1/G5 and S1/S5 must match the corresponding P1/P5 Phase Currents (i.e. 5A and 1A must not be mixed).

Ground Current GX requires PX Phase Current, and is only available with Case N, Current Protection N, Other Options V, and Input/Output E. Ground Current G0/S0 must match the P0 Phase Current, and is only available with the non-drawout Case Design N.

H|||||||| 125 to 250 V DC/120 to 230 V AC

Input/Output

c. Input/Output option A is only available with the non-drawout Case Design N

Current Protection

d. Current Protection option S has been discontinued.

N|||||| None (voltage and frequency relay, requires a PX/GX configuration)

||||||||||||Extended configuration: User selectable 49, 50P(2), 50G/SG(2), 50N(2), 51P(1), 51G/SG(1),

51N(1)

||||||||||||Advanced configuration: Extended + 51_2 or 46(1), 50_2 (1) or 46(1),

I1/I2(46BC)

C | | | | | CLP, 50BF, Lockout (86), Autoreclose (79)

Other Options

e. CLP, 79, and 50BF are not supported when V is selected under Other Options.

N| | | | No selection

||||||||27P(4), 27X(1), 27P_1(1), 59P(4), 59N(4), 59X(1), 59_2(2), 81O(4), 81U(4), 25(1), VTFF(1), 24(1),

Voltage Metering (requires a PX/GX configuration)

D| | | | Neutral and Ground Directional Overcurrent Protection: 67N(1), 67G/SG(1), 60CTS M| | | | Voltage, Power, and Energy Metering, 60CTS

||||||||Phase, Neutral, and Ground Directional Overcurrent Protection: 67P(1), 67N(1), 67G/

SG(1), 32N(2), VTFF + Voltage, Power, and Energy Metering, 60CTS

P||

| | |

Extended Protection: 27P(2), 27X(1), 27P_1 (1), 59P(2), 59N(1), 59X(1), 59_2(1), 81O(2), 81U(2), 67P(1), 67N(1), 67G/SG(1), VTFF(1), 25(1), 60CTS, Voltage, Power, and Energy Metering

W| | | | Advanced Protection: Extended + 32(2)

Communications

f. Communications option 4E allows the selection of either IEC 61850 or OPC-UA; both cannot be used at the same time.

Communications option 5E is only available with Case Design D or X. 898800AA.PDF

S N | | Standard: Front USB, Rear RS485: Modbus RTU, DNP3.0, IEC60870-5-103

1 E

||||Standard + Ethernet (Copper & Fiber - MTRJ),

Modbus TCP/IP, DNP3.0, IEC 60870-5-104

2 E

||||Standard + Ethernet (Copper & Fiber - MTRJ),

Modbus TCP/IP, DNP3.0, IEC 60870-5-104, IEC 61850 GOOSE

3 E

||||Standard + Ethernet (Copper & Fiber - MTRJ),

Modbus TCP/IP, DNP3.0, IEC 60870-5-104, IEC 61850

4 E

||||Standard + Ethernet (Copper & Fiber - MTRJ),Modbus TCP/IP, DNP3.0, IEC 60870-5-104,

IEC 61850, OPC-UA

5 E

||||Standard + Ethernet (Dual Fiber - MTRJ),Modbus TCP/IP, DNP3.0, IEC 60870-5-104, IEC

61850, OPC-UA, PRP, HSR, 1588, PTP

Case Design D | Protection Relay with drawout design

N| Protection Relay with non-drawout design X| Protection Relay (drawout design) with no chassis

Harsh Environment N None

H Harsh Environment Conformal Coating

Figure 1-3: Order Codes

1–6 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 17

CHAPTER 1: INTRODUCTION 350 ORDER CODES

NOTE

897800AF-A1.fm

AFC  * *

AF System Component E | Sensor Fiber Extension (black sensor fiber with two single

bulkhead connectors, used with loop sensors)

L | Loop Sensor with transparent sensor fiber P | Point Sensor with black sensor fiber

Sensor Fiber Length XX Sensor fiber length:

01 to 35 meters for Point Sensors and Extensions 01 to 70 meters for Loop Sensors

NOTE:

FASTPATH:

Features related to each order number are subject to change without notice.

Arc Flash System

The 350 protection relay with Input/Output option “A” supports up to 4 Arc Flash sensors, which are ordered separately so that the connected sensor fiber lengths can be customized.

The total sensor fiber length connected to each loop sensor must not exceed 70 meters of single sensor fiber. Black sensor fiber is duplex, and must be doubled in calculations.

For example, a loop sensor with a 25 meter transparent sensor fiber plus a sensor fiber extension of 10 meters would have a total of 2 x 10m + 25m = 45m of single sensor fiber.

The total sensor fiber length connected to each point sensor must not exceed 35 meters of black (duplex) cable.

NOTE:

FASTPATH:

Generally each loop sensor is used with a sensor fiber extension, in order to minimize exposure to ambient light when running the sensor fiber between cabinets. A duplex sensor fiber extension connects the relay to the loop sensor, and can be gently pulled apart to connect to the loop sensor connectors if they are not adjacent. Consider your installation needs carefully when ordering sensor and extension lengths.

Empty chassis

The 350 protection relay chassis used with a drawout relay is available separately, for use as a partial replacement or in test environments. Many features are supported by the cards and ports within the chassis, as is reflected in the chassis order code.

The chassis order code and drawout relay order code must match exactly.

A drawout relay cannot be used in a chassis with different order code options.

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 1–7

Page 18

350 ORDER CODES CHAPTER 1: INTRODUCTION

NOTE

350  CH  * * * * * *

P5 | | | | | 5 A 3-phase current inputs

Ground Currents

a. Ground current options G1/G5 must match the corresponding P1/P5 Phase currents

Other Options N | | | No selection

D| | | Neutral and Ground Directional Overcurrent Protection: 67N(1), 67G/SG(1), 60CTS M| | | Voltage, Power, and Energy Metering, 60CTS

||||||Phase, Neutral, and Ground Directional Overcurrent Protection: 67P(1), 67N(1),

67G/SG(1), 32N(2), VTFF + Voltage, Power, and Energy Metering, 60CTS

|||||

Extended Protection: 27P(2), 27X(1), 27P_1 (1), 59P(2), 59N(1), 59X(1), 59_2(1), 81O(2), 81U(2), 67P(1), 67N(1), 67G/SG(1), VTFF(1), 25(1), 60CTS, Voltage, Power, and Energy Metering

W| | | Advanced Protection: Extended + 32(2)

Communications

b. Communications option 4E allows the selection of either IEC 61850 or OPC-UA; both cannot be used at the same time.

898800CH-A2.PDF

S N | Standard: Front USB, Rear RS485: Modbus RTU, DNP3.0, IEC60870-5-103

1 E

||Standard + Ethernet (Copper & Fiber - MTRJ),

Modbus TCP/IP, DNP3.0, IEC 60870-5-104

2 E

||Standard + Ethernet (Copper & Fiber - MTRJ),

Modbus TCP/IP, DNP3.0, IEC 60870-5-104, IEC 61850 GOOSE

3 E

||Standard + Ethernet (Copper & Fiber - MTRJ),

Modbus TCP/IP, DNP3.0, IEC 60870-5-104, IEC 61850

4 E

||Standard + Ethernet (Copper & Fiber - MTRJ),Modbus TCP/IP, DNP3.0, IEC 60870-5-

104, IEC 61850, OPC-UA

5 E

||Standard + Ethernet (Dual Fiber - MTRJ),Modbus TCP/IP, DNP3.0, IEC 60870-5-104,

IEC 61850, OPC-UA, PRP, HSR, 1588, PTP

Harsh Environment N None

H Harsh Environment Conformal Coating

Figure 1-4: 350 chassis order codes

NOTE:

1–8 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Other accessories

• 1819-0103 350 Retrofit Kit for 735

• 1819-0102 350 Retrofit Kit for IAC Relay

• 1819-0101 350 Retrofit Kit for MDP Relay

• 1819-0100 350 Retrofit Kit for S1/S2 Cut-Out

• 18L0-0075 3 Series Depth reducing collar - 1.375”

• 18L0-0076 3 Series Depth reducing collar - 3.00”

• 18L0-0080 3 Series IP20 Kit

• 3S-NDO-STCONKIT 3 Series NDO straight terminal block kit

• 0804-0458 USB A-B configuration cable - 6’

Refer to the 3 Series Retrofit Instruction Manual for the retrofit of Multilin MI, MII, MLJ, and TOV relays.

Page 19

CHAPTER 1: INTRODUCTION SPECIFICATIONS

NOTE

Specifications

NOTE:

Specifications are subject to change without notice.

To obtain the total element operating time, i.e. from the presence of a trip condition to initiation of a trip, add 8 ms output relay time to the operate times listed below, with the exception of Arc Flash SSR loads.

Password security

PASSWORD SECURITY

Master Password: ...............................................8 to 10 alpha-numeric characters

Settings Password:.............................................3 to 10 alpha-numeric characters for local and remote

access

Control Password:...............................................3 to 10 alpha-numeric characters for local and remote

access

Protection

BROKEN CONDUCTOR (I1/I2 OR 46BC)

Minimum operating positive current:........ 0.05 to 1.00 x CT in steps of 0.01 x CT

Maximum operating positive current:....... 0.05 to 5.00 x CT in steps of 0.01 x CT

Pickup level:........................................................... 20.0% to 100.0% in steps of 0.1%

Dropout level:........................................................ 97% to 98% of the pickup level

Pickup time delay: .............................................. 0.000 to 65.535 s in steps of 0.001 s

Timer accuracy: .................................................. ± 3% of delay setting or ± ¾ cycle (whichever is greater)

from pickup to operate

Operate time:........................................................ <30 ms at 60 Hz

WATTMETRIC GROUND FAULT (32N)

Measured power:................................................ zero sequence

Number of elements: ........................................ 1

Characteristic angle: ......................................... 0º to 359º in steps of 1°

Pickup threshold:................................................. 0.001 to 1.200 pu in steps of 0.001 pu

Pickup level accuracy:...................................... ± 2% or ± 0.03 pu, whichever is greater

Hysteresis:.............................................................. 3% or 0.001 pu, whichever is greater

Pickup delay:......................................................... Definite T ime (0.00 to 600 .0 s in steps of 0.1 s), Inverse T ime,

or Flexcurve

Inverse time multiplier:..................................... 0.01 to 2.00 in steps of 0.01

Curve timing accuracy:.................................... ± 3.5% of operate time or ± ¼ cycle (whichever is greater)

from pickup to operate

Operate time:........................................................ <30 ms at 60 Hz

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 1–9

Page 20

SPECIFICATIONS CHAPTER 1: INTRODUCTION

DIRECTIONAL POWER (32)

Measured power:................................................ 3-phase

Characteristic angle:......................................... 0º to 359º in steps of 1°

Power pickup range: ......................................... -1.200 to 1.200 x Rated Power in steps of 0.001

Pickup level accuracy:...................................... 2.5% or 0.01 pu, whichever is greater

Hysteresis: ............................................................. 2% or 0.001 x Rated Power, whichever is greater

Pickup time delay:.............................................. 0.0 to 600.0 s in steps of 0.1 s

Operate time:........................................................ < 55 ms at 1.1 x pickup at 60 Hz

< 65 ms at 1.1 x pickup at 50 Hz

Timer accuracy:.................................................. ± 3% of delay setting or ± ¼ cycle (whichever is greater)

from pickup to operate

VOLTS PER HERTZ (24)

Inputs: ...................................................................... Van (Wye VTs), Vab (Delta VTs)

Pickup Level: ......................................................... 0.80 to 4.00 x V/Hz in steps of 0.01 x V/Hz

Dropout Level:...................................................... 97% to 98% of pickup

Level Accuracy: ................................................... ± 0.02 x V/Hz or 2% of set value, whichever is greater

Time Curves:......................................................... Definite Time, Inverse A/B/C, FlexCurves A/B

TD Multiplier: ......................................................... 0.00 to 600.00 s in steps of 0.01 s

Reset Delay: .......................................................... 0.00 to 600.00 s in steps of 0.01 s

Time Accuracy:.................................................... ± 3% of operate time of ±15 cycles (whichever is greater) for

values greater than 1.1 x pickup

PHASE/NEUTRAL/GROUND/NEGATIVE SEQUENCE TIME OVERCURRENT (51P/51N/51G/ 51_2)

Pickup Level: ......................................................... 0.05 to 20.00 x CT in steps of 0.01 x CT

Dropout Level:...................................................... 97% of Pickup @ I > 1 x CT

Pickup - 0.02 x CT @ I < 1 x CT

Curve Shape:......................................................... ANSI Extremely/Very/Moderately/Normally Inverse

Definite T ime (0.1 s base curve) IEC Curve A/B/C and Short Inverse IAC Extreme/Very/-/Short Inverse

User Curve, FlexCurve™ A/B (programmable curves)

Curve Multiplier: .................................................. 0.05 to 50.00 in steps of 0.01

Reset Time: ............................................................ Instantaneous, Linear

Curve Timing Accuracy:.................................. ±3% of expected inverse time or 1.5 cycle, whichever is

greater, from pickup to operate

Level Accuracy: ................................................... per CT input

SENSITIVE GROUND TIME OVERCURRENT (51SG)

Pickup Level: ......................................................... 0.005 to 3.000 x CT in steps of 0.001 x CT

Dropout Level:...................................................... 97% of Pickup @ I > 0.1 x CT

Pickup - 0.002 x CT @ I < 0.1 x CT

Curve Shape:......................................................... ANSI Extremely/Very/Moderately/Normally Inverse

Definite T ime (0.1 s base curve)

IEC Curve A/B/C/Short Inverse

IAC Extreme/Very/-/Short Inverse

User Curve, FlexCurve™ A/B

Curve Multiplier: .................................................. 0.05 to 50.00 in steps of 0.01

Reset Time: ............................................................ Instantaneous, Linear

Curve Timing Accuracy:.................................. ±3% of expected inverse time or 1 cycle, whichever is

greater, from pickup to operate

Level Accuracy: ................................................... per CT input

1–10 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 21

CHAPTER 1: INTRODUCTION SPECIFICATIONS

PHASE/NEUTRAL/GROUND/NEGATIVE SEQUENCE INSTANTANEOUS OVERCURRENT (50P/50N/50G/50_2)

Pickup Level:.......................................................... 0.05 to 20.00 x CT in steps of 0.01 x CT

Dropout Level: ...................................................... 97% of Pickup @ I > 1 x CT

Pickup - 0.02 x CT @ I <1 x CT

Time Delay:............................................................ 0.00 to 300.00 sec in steps of 0.01

Operate Time:....................................................... <30 ms @ 60Hz (I > 2.0 x PKP, No time delay)

<35 ms @ 50Hz (I > 2.0 x PKP, No time delay)

Time Delay Accuracy: ...................................... 1% or 1 cycle, whichever is greater (Time Delay selected)

Level Accuracy:.................................................... per CT input

SENSITIVE GROUND INSTANTANEOUS OVERCURRENT (50SG)

Pickup Level (Gnd IOC):..................................... 0.005 to 3.000 x CT in steps of 0.001 x CT

Dropout Level: ...................................................... 97% of Pickup @ I > 0.1 x CT

Pickup - 0.002 x CT @ I < 0.1 x CT

Time Delay:............................................................ 0.00 to 300.00 sec in steps of 0.01

Operate Time:....................................................... <30 ms @ 60Hz (I > 2.0 x PKP, No time delay)

<35 ms @ 50Hz (I > 2.0 x PKP, No time delay)

Time Delay Accuracy: ...................................... 1% or 1 cycle, whichever is greater (Time Delay selected)

Level Accuracy:.................................................... per CT input

PHASE DIRECTIONAL (67P)

Directionality: ....................................................... Co-existing forward and reverse

Operating:............................................................... Phase Current (Ia, Ib, Ic)

Polarizing Voltage:.............................................. Quadrature Voltage

(ABC phase sequence: Vbc, Vca, Vab)

(CBA phase sequence: Vcb, Vac, Vba)

Polarizing voltage threshold:......................... 0.05 to 1.25 x VT in steps of 0.01

MTA (Maximum Torque Angle): ..................... From 0º to 359º in steps of 1°

Angle Accuracy: .................................................. ±4º

Operational Delay: ............................................. 20 to 30 ms

NOTE:

The selection of the “P” or “R” option from “350 OTHER OPTIONS” in the order code table, will enable the Phase directional element. The polarizing voltage used for this element is the line voltage.

GROUND DIRECTIONAL (67G)

Directionality: ....................................................... Co-existing forward and reverse

Operating:............................................................... Ground Current (Ig)

Polarizing Voltage:.............................................. -V

calculated using phase voltages (VTs must be connected

in “Wye”)

-3V

measured from Vaux input. (3V0 provided by an

external open delta connection).

MTA (Maximum Torque Angle): ..................... From 0º to 359º in steps of 1°

Angle Accuracy: .................................................. ±4º

Operational Delay: ............................................. 20 to 30 ms

NOTE:

The selection of the “D” option from “350 OTHER OPTIONS” in the Order Code table, will enable the Ground Directional element with voltage polarizing 3V

measured from the

Vaux voltage input.

NOTE:

The selection of the “P”, “R”, or “W” option from “350 OTHER OPTIONS” in the order code table, will enable the Ground directional element. The polarizing voltage used for this element is the computed V0 from the measured phase voltage inputs.

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 1–11

Page 22

SPECIFICATIONS CHAPTER 1: INTRODUCTION

NOTE

NEUTRAL DIRECTIONAL (67N)

Directionality: ....................................................... Forward and reverse

Polarizing:............................................................... Voltage, Current, Dual

Polarizing Voltage:.............................................. - V

Polarizing Current:.............................................. I

MTA:........................................................................... From 0º to 359º in steps of 1°

Angle Accuracy: .................................................. ±4º

Operational Delay:............................................. 20 to 30 ms

NOTE:

The selection of the “D” option from “350 OTHER OPTIONS” in the Order Code table, will enable the Neutral Directional element with voltage polarizing 3V

calculated using phase voltages (VTs must be

connected in “Wye”)

-3V

measured from Vaux input (3V0 provided by an

external broken delta connection).

measured from the

Vaux voltage input. The selection of “P”, “R”, or “W” option from “350 OTHER OPTIONS” in the Order Code table,

will enable the Neutral Directional elements with voltage polarizing V

computed from the

measured phase voltage inputs.

The ground polarizing current, IG, is available for selection in both cases.

THERMAL OVERLOAD (49)

Current:.................................................................... RMS current - max (Ia, Ib, Ic)

Pickup Accuracy: ................................................ per current inputs

Timing Accuracy:................................................ See graph below

Figure 1-5:

The graph shows the trip time error with respect to the ratio of cable load and thermal model pickup setting. With a smaller I/Ipkp ratio, the time error tends to be higher, as accumulated through the logarithmic formula, the measurement error, and the time of measurement. For higher I/Ipkp ratios, the time to trip is substantially more accurate. Each point on the graph represents a trip time error, with the I/Ipkp ratio kept constant during the test.

PHASE/AUXILIARY/POSITIVE SEQUENCE UNDERVOLTAGE (27P, 27X, 27_1)

Minimum Voltage: .............................................. Programmable from 0.00 to 1.25 x VT in steps of 0.01

Pickup Level: ......................................................... 0.00 to 1.25 x VT in steps of 0.01

Dropout Level:...................................................... 102% of pickup (pickup > 0.1 x VT)

Pickup + 0.02 x VT (pickup < 0.1 x VT)

Curve: ....................................................................... Definite Time, Inverse Time

Time Delay: ........................................................... 0.00 to 600.00 s in steps of 0.01

Operate Time: ...................................................... T ime delay ±30 ms @ 60 Hz (V < 0.85 x PKP)

Time delay ±40 ms @ 50 Hz (V < 0.85 x PKP)

Time Delay Accuracy:...................................... ±3% of expected time, or 1 cycle, whichever is greater

Level Accuracy: ................................................... Per voltage input

1–12 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 23

CHAPTER 1: INTRODUCTION SPECIFICATIONS

NOTE

PHASE/AUXILIARY/NEUTRAL/NEGATIVE SEQUENCE OVERVOLTAGE (59P, 59X, 59N, 59_2)

Pickup Level:.......................................................... 0.00 to 1.25 x VT in steps of 0.01

Dropout Level: ...................................................... 98% of pickup (pickup > 0.1 x VT)

Pickup - 0.02 x VT (pickup < 0.1 x VT)

Time Delay:............................................................ 0.00 to 600.00 s in steps of 0.01

Operate Time:....................................................... Time delay ±35 ms @ 60Hz (V > 1.1 x PKP)

Time delay ±40 ms @ 50Hz (V > 1.1 x PKP)

Time Delay Accuracy: ...................................... ±3% of expected time, or 1 cycle, whichever is greater

Level Accuracy:.................................................... Per voltage input

UNDERFREQUENCY (81U)

Minimum Voltage:............................................... 0.00 to 1.25 x VT in steps of 0.01

Pickup Level:.......................................................... 40.00 to 70.00 Hz in steps of 0.01

Dropout Level: ...................................................... Pickup + 0.05 Hz

Time Delay:............................................................ 0.10 to 600.0 s in steps of 0.01

Time Delay Accuracy: ...................................... 0 to 6 cycles (Time Delay selected)

Operate Time:....................................................... Typically 10 cycles @ 0.1Hz/s change

Level Accuracy:.................................................... ±0.03 Hz

OVERFREQUENCY (81O)

Minimum Voltage:............................................... 0.3 x VT

Pickup Level:.......................................................... 40.00 to 70.00 Hz in steps of 0.01

Dropout Level: ...................................................... Pickup - 0.05 Hz

Time Delay:............................................................ 0.1 to 600.0 s in steps of 0.01

Time Delay Accuracy: ...................................... 0 to 6 cycles (Time Delay selected)

Operate Time:....................................................... Typically 10 cycles @ 0.1Hz/s change

Level Accuracy:.................................................... ±0.03 Hz

ARC FLASH HS PHASE/GROUND INSTANTANEOUS OVERCURRENT HS 50P/50G

Current:.................................................................... RMS Magnitude (special high speed algorithm)

Pickup Level:.......................................................... 0.050 to 30.000 x CT in steps of 0.001 x CT

Dropout Level: ...................................................... 97 to 98% of Pickup

Level Accuracy:.................................................... For 0.1 to 0.2 x CT: ± 0.2% of reading or 1.5% of rated

current, whichever is greater

For > 0.2 x CT: ± 5% of reading

Operate Time:....................................................... 4 ms at >6 x Pickup at 60 Hz

5 ms at >6 x Pickup at 50 Hz

4-8 ms at > (3-6) x Pickup at 60 Hz

4-10 ms at > (3-6) x Pickup at 50 Hz

NOTE:

The operate times listed require that SSR output relays (Aux 5 and 6) be used for Arc Flash detection.

ARC FLASH SENSOR/FIBER

Number of Sensors: ........................................... 4

Detection Radius:................................................ 180 degree

Maximum Duplex Fiber Length (Point

Sensor):............................................................... 35 m

Maximum Single Fiber Length (Loop

Sensor):............................................................... 70 m

Fiber Size:................................................................ 1.0 mm core diameter

2.2 mm total diameter (single)

4.4 mm total diameter (duplex)

Mode:........................................................................ Multi-mode

Connector:.............................................................. Small Media Interface (SMI)

Fiber Type:.............................................................. Plastic Optical Fiber

Bend Radius: ......................................................... 35 mm minimum

Product Type:........................................................ Class 1 Laser product

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 1–13

Page 24

SPECIFICATIONS CHAPTER 1: INTRODUCTION

NOTE

Metering

PARA METER ACCURACY

3-Phase Real Power (MW or kW) ±1% of full scale 0.1 MW ± 100000.0 kW 3-Phase Reactive Power (Mvar or kvar) ±1% of full scale 0.1 Mvar ± 100000.0 kvar 3-Phase Apparent Power (MVA or kVA) ±1% of full scale 0.1 MVA ± 100000.0 kVA 3-Phase Positive Watthour (MWh) ±1% of full scale ±0.001 MWh 50000.0 MWh 3-Phase Negative Watthour (MWh) ±1% of full scale ±0.001 MWh 50000.0 MWh 3-Phase Positive Varhour (Mvarh) ±1% of full scale ±0.001 Mvarh 50000.0 Mvarh 3-Phase Negative Varhour (Mvarh) ±1% of full scale ±0.001 Mvarh 50000.0 Mvarh Power Factor ±0.05 0.01 -0.99 to 1.00 Frequency ±0.05 Hz 0.01 Hz 40.00 to 70.00 Hz

NOTE:

Negative values (-) represent lead and positive values (+) represent lag.

(full scale for CT Input is 3 x CT)

RESOLUTION RANGE

CURRENTS

Parameters:...........................................................Phase A, Phase B, Phase C, Neutral, Ground, Sensitive

Ground, Positive Sequence, Negative Sequence, Zero Sequence, and 2nd Harmonic

Accuracy: ...............................................................See the Inputs section in Chapter 1: Specifications

VOLTAGES

Parameters:...........................................................Wye VTs: AN, BN, CN, Negative Sequence, Zero Sequence

and Auxiliary Delta VTs: AB, BC, CA, Negative Sequence, Zero Sequence and Auxiliary

Accuracy: ...............................................................See the Inputs section in Chapter 1: Specifications

Data capture

TRANSIENT RECORDER

Buffer size: .............................................................3 s

No. of buffers:.......................................................1, 3, 6

No. of channels:................................................... 14

Sampling rate:......................................................4, 8, 16, or 32 samples per cycle

Triggers: ..................................................................Manual Command

Data: .........................................................................AC input channels

Data storage:........................................................ RAM - battery backed-up

FAULT RECORDER

Number of records:............................................ 1

Content:................................................................... Date and Time, first cause of fault, phases,

Contact Input Virtual Input Logic Element Element Pickup/Trip/Dropout/Alarm

Contact input state Contact output state Virtual input state Logic element state

Currents: Ia, Ib, Ib, Ig/Isg, In - magnitudes and angles Voltages: Van, Vbn, Vcn, Vab, Vbc, Vca, Vaux - magnitudes and angles System frequency

1–14 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 25

CHAPTER 1: INTRODUCTION SPECIFICATIONS

EVENT RECORDER

Number of events:..............................................256

Header: ....................................................................relay name, order code, firmware revision

Content:...................................................................event number, date of event, cause of event,per-phase

current, ground current, sensitive ground current, neutral current, per-phase voltage (VTs connected in “Wye”), or phase-phase voltages (VTs connected in “Delta”), system frequency, power, power factor, thermal capacity

Data Storage:........................................................Retained for 3 days

CLOCK

Setup:........................................................................Date and time

Daylight Saving Time

IRIG-B:.......................................................................Auto-detect (DC shift or Amplitude Modulated)

Amplitude modulated: 1 to 10 V pk-pk DC shift: 1 to 10 V DC

Input impedance: 40 kOhm ± 10%

Accuracy with IRIG-B:....................................... ± 1 ms

Accuracy without IRIG-B:................................± 1 min / month

Control

LOGIC ELEMENTS

Number of logic elements: .............................16

Trigger source inputs per element: ............2 to 8

Block inputs per element: ...............................2 to 4

Supported operations: .....................................AND, OR, NOR, NAND, XOR, XNOR, Pickup / Dropout timers

Pickup timer:..........................................................0 to 60000 ms in steps of 1 ms

Dropout timer:......................................................0 to 60000 ms in steps of 1 ms

BREAKER CONTROL

Operation:...............................................................Asserted Contact Input, Logic Element, Virtual Input, Manual

Command

Function: .................................................................Opens / closes the feeder breaker

AUTORECLOSE (79)

Reclose attempts:...............................................Up to 4 shots

Time Delay Accuracy: ......................................0 to 3 cycles (AR Dead Time selected)

Elements: ................................................................Inputs, Outputs, Breaker Status (52 status)

SYNCHROCHECK (25)

Maximum frequency difference:.................0.05 to 5.00 Hz in steps of 0.01 Hz

Maximum Angle difference:...........................2° to 80° in steps of 1°

Maximum Voltage difference:.......................10 to 10000 V in steps of 1 V

Dead Bus and Dead Line level:.....................0.00 to 1.25 x VT in steps of 0.01 x VT

Live Bus and Live Line level:...........................0.03 to 1.25 x VT in steps of 0.01 x VT

SECOND HARMONIC INHIBIT

Operating Parameter:.......................................Current 2nd harmonic per phase or average

Pickup Level:..........................................................0.1% to 40.0% in steps of 0.1

Minimum Current:...............................................0.03 to 3.00 x CT in steps of 0.01 x CT

Time Delay:............................................................0.00 to 600.00 s in steps of 0.01 s

Time Delay Accuracy: ......................................±3% of expected time or 2 cycles, whichever is greater

Level Accuracy:....................................................±2% or ±10mA (whichever is greater)

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 1–15

Page 26

SPECIFICATIONS CHAPTER 1: INTRODUCTION

BREAKER FAILURE (50BF)

Pickup Level: .........................................................0.05 to 20.00 x CT in steps of 0.01 x CT

Dropout Level:......................................................97 to 98% of pickup

Timer 1 Delay: ...................................................... 0.03 to 1.00 s in steps of 0.01 s

Timer 2 Delay: ...................................................... 0.00 to 1.00 s in steps of 0.01 s

Time Delay Accuracy:...................................... 0 to 1 cycle (T imer 1, T imer 2)

Level Accuracy: ...................................................per CT input

Reset Time: ............................................................<14 ms typical at 2 x pickup at 60 Hz

<16 ms typical at 2 x pickup at 50 Hz

CT FAILURE

Inputs: ......................................................................Neutral Current IN,

Neutral Current VN (from three-phase VTs)

Ground Current Ig

Time Delay: ........................................................... 0.00 to 60.00 s in steps of 0.01 s

3IO level accuracy: ............................................per CT inputs

3VO level accuracy:........................................... per VT inputs

GND current level accuracy:.........................see the specifications for phase and ground current inputs

Operate Time: ......................................................30 ms at 60 Hz

35 ms at 50 Hz

BREAKER TRIP COUNTER

Trip Counter Limit (Pickup):............................. 1 to 10000 in steps of 1

LOCKOUT

Function:................................................................. Latch Trip command to Relay 1 TRIP

Block Close to Relay 2 CLOSE

Operation: ..............................................................Any protection element

COLD LOAD PICKUP BLOCKING

Operation: ..............................................................Automatically (current level), or by command (asserted

input)

Function:................................................................. Block IOC functions, raise TOC pickup, for selected period of

time

Time Delay Accuracy:...................................... 0 to 1 cycle (block Time)

±50 ms (outage time ≤5 min)

±1 s (outage time > 5 min)

FUSE FAIL (VTFF)

Time Delay: ........................................................... 1 s

Timing Accuracy:................................................ ±0.5 s

Elements:................................................................ Trip or Alarm

AMBIENT TEMPERATURE

High Temperature Pickup:.............................. 20°C to 80°C in steps of 1°C

Low Temperature Pickup:...............................-40°C to 20°C in steps of 1°C

Time Delay: ........................................................... 1 to 60 min in steps of 1 min

Temperature Dropout:......................................Configurable 90 to 98% of pickup

Temperature Accuracy:................................... ±10°C

Timing Accuracy:................................................ ±1 second

1–16 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 27

CHAPTER 1: INTRODUCTION SPECIFICATIONS

Monitoring

BREAKER HEALTH

Timer Accuracy: ..................................................± 3% of delay setting or ± 1 cycle (whichever is greater) from

pickup to operate

DEMAND

Measured Values:................................................Phase A/B/C present and maximum current, three-phase

present and maximum real/reactive/apparent power

Measurement Type:...........................................Thermal Exponential, 90% response time (programmed): 5,

10, 15, 20, 30 minutes Block Interval / Rolling Demand, time interval (programmed):

5, 10, 15, 20, 30 minutes

Current Pickup Level:.........................................10 to 10000 in steps of 1 A

Real Power Pickup Level:.................................0.1 to 300000.0 in steps of 0.1 kW

Reactive Power Pickup Level:........................0.1 to 300000.0 in steps of 0.1 kVar

Apparent Power Pickup Level: ......................0.1 to 300000.0 in steps of 0.1 kVA

Dropout Level: ......................................................96-98% of Pickup level

Level Accuracy:....................................................± 2% (current demand only)

Inputs

CONTACT INPUTS

Inputs:.......................................................................10

Selectable thresholds:.......................................17, 33, 84, 166 VDC

±10%

Recognition time:................................................1/2 cycle

Debounce time: ...................................................1 to 64 ms, selectable, in steps of 1 ms

Maximum input voltage & continuous

current draw:...................................................300 VDC, 2 mA, connected to Class 2 source

Type: .........................................................................opto-isolated inputs

External switch: ...................................................wet contact

PHASE & GROUND CURRENT INPUTS

CT Primary: ............................................................1 to 6000 A

Range: ......................................................................0.02 to 20 × CT

Input type:..............................................................1 A, 5 A, or 1/5 A (must be specified with order)

Nominal frequency:...........................................50/60 Hz

Burden: ....................................................................<0.1 VA at rated load

Accuracy:................................................................3%

±10 mA or ±20% of reading from 0.02 to 0.19 × CT, whichever is greater

CT withstand: ........................................................1 second at 100 A (1 A option)

1 second at 400 A (5 A or universal CT option) 2 seconds at 40 × rated current continuous at 3 × rated current

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 1–17

Page 28

SPECIFICATIONS CHAPTER 1: INTRODUCTION

SENSITIVE GROUND CURRENT INPUT

CT Primary: ............................................................ 1 to 600 A

Range:......................................................................0.002 to 3 × CT

Input type:.............................................................. 1 A, 5 A, or 1/5 A (must be specified with order)

Nominal frequency:........................................... 50/60 Hz

Burden:.................................................................... <0.1 VA at rated load

Accuracy: ...............................................................3%

±10 mA or ±20% of reading from 0.02 to 0.19 × CT, whichever is greater

CT withstand:........................................................1 second at 100 A (1 A option)

1 second at 400 A (5 A or universal CT option) 2 seconds at 40 × rated current continuous at 3 × rated current

PHASE/AUX VOLTAGE INPUTS

Source VT: ..............................................................0.15 to 550 kV / 50 to 220 V

VT secondary range:.........................................50 to 240 V

VT ratio: ...................................................................1.0 to 5000.0 in steps of 0.1

Nominal frequency:........................................... 50/60 Hz

Relay burden: ....................................................... <0.25 VA at 120 V

Accuracy: ...............................................................±1.0% throughout range

Voltage withstand: .............................................260 VAC continuous

Outputs

ARC FLASH OPTION

FORM-A RELAYS

Configuration: ...................................................... 2 (two) electromechanical

Contact material:................................................ silver-alloy

Operate time:........................................................ <8 ms

Continuous current:........................................... 10 A

Make and carry for 0.2s: ................................. 30 A per ANSI C37.90

Break (DC inductive, L/R=40 ms):................. 24 V / 1 A

48 V / 0.5 A 125 V / 0.3 A 250 V / 0.2 A

Break (DC resistive): ........................................... 24 V / 10 A

48 V / 6 A 125 V / 0.5 A

250 V / 0.3 A

Break (AC inductive):.......................................... 720 VA @ 240 VAC Pilot duty A300

Break (AC resistive):............................................ 250 VAC / 10 A

Ratings per UL Certification:

Break (AC resistive):............................................ 250 VAC / 10 A GEN USE

Continuous Current:.......................................... 10 A

FORM-A VOLTAGE MONITOR

Applicable voltage:............................................. 20 to 250 VDC

Trickle current: ..................................................... 1 to 2.5 mA

1–18 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 29

CHAPTER 1: INTRODUCTION SPECIFICATIONS

FORM-C RELAYS

Configuration:....................................................... 3 (three) electromechanical

Contact material: ................................................ silver-alloy

Operate time:........................................................ <8 ms

Continuous current:........................................... 10 A

Make and carry for 0.2s:.................................. 30 A per ANSI C37.90

Break (DC inductive, L/R=40 ms):................. 24 V / 1 A

48 V / 0.5 A 125 V / 0.3 A 250 V / 0.2 A

Break (DC resistive):............................................ 24 V / 10 A

48 V / 6 A 125 V / 0.5 A

250 V / 0.3 A

Break (AC inductive):.......................................... 720 VA @ 240 VAC Pilot duty A300

Break (AC resistive):............................................ 250 VAC / 10 A

Ratings per UL Certification:

Break (AC resistive):............................................ 250 VAC / 10 A GEN USE

Continuous Current: .......................................... 10 A

SOLID STATE CONTACT

Configuration:....................................................... 2 MOSFET

Operate time:........................................................ 60 µs

Continuous current:........................................... 6 A

Make and carry for 1 s:.................................... 10 A

Break (DC resistive):............................................ 300 V / 6 A

Break (DC inductive L/R=40ms):................... 300 V / 6 A

Ratings per UL Certification:

Break:........................................................................ 24 VDC, 1 A Pilot Duty

48 VDC, 0.5 A Pilot Duty

125 VDC, 0.3 A Pilot Duty

250 VDC, 0.2 A Pilot Duty

Continuous Current: .......................................... 6 A

TRIP / CLOSE SEAL-IN

Relay 1 trip seal-in: ............................................ 0.00 to 9.99 s in steps of 0.01

Relay 2 close seal-in:......................................... 0.00 to 9.99 s in steps of 0.01

NON-ARC FLASH OPTION

FORM-A RELAYS

Configuration:....................................................... 2 (two) electromechanical

Contact material: ................................................ silver-alloy

Operate time:........................................................ <8 ms

Continuous current:........................................... 10 A

Make and carry for 0.2s:.................................. 30 A per ANSI C37.90

Break (DC inductive, L/R=40 ms):................. 24 V / 1 A

48 V / 0.5 A

125 V / 0.3 A

250 V / 0.2 A

Break (DC resistive):............................................ 24 V / 10 A

48 V / 6 A

125 V / 0.5 A

250 V / 0.3 A

Break (AC inductive):.......................................... 720 VA @ 240 VAC Pilot duty A300

Break (AC resistive):............................................ 250 VAC / 10 A

Ratings per UL Certification:

Break (AC resistive):............................................ 250 VAC / 10 A GEN USE

Continuous Current: .......................................... 10 A

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 1–19

Page 30

SPECIFICATIONS CHAPTER 1: INTRODUCTION

FORM-A VOLTAGE MONITOR

Applicable voltage:............................................. 20 to 250 VDC

Trickle current: ..................................................... 1 to 2.5 mA

FORM-C RELAYS

Configuration: ...................................................... 5 (five) electromechanical

Contact material:................................................ silver-alloy

Operate time:........................................................ <8 ms

Continuous current:........................................... 10 A

Make and carry for 0.2s: ................................. 30 A per ANSI C37.90

Break (DC inductive, L/R=40 ms):................. 24 V / 1 A

48 V / 0.5 A 125 V / 0.3 A 250 V / 0.2 A

Break (DC resistive): ........................................... 24 V / 10 A

48 V / 6 A 125 V / 0.5 A

250 V / 0.3 A

Break (AC inductive):.......................................... 720 VA @ 240 VAC Pilot duty A300

Break (AC resistive):............................................ 250 VAC / 10 A

Ratings per UL Certification:

Break (AC resistive):............................................ 250 VAC / 10 A GEN USE

Continuous Current:.......................................... 10 A

TRIP / CLOSE SEAL-IN

Relay 1 trip seal-in:............................................ 0.00 to 9.99 s in steps of 0.01

Relay 2 close seal-in: ........................................ 0.00 to 9.99 s in steps of 0.01

Power supply

HIGH RANGE POWER SUPPLY

Nominal:.................................................................. 120 to 240 VAC

Range:......................................................................60 to 300 VAC (50 and 60 Hz)

Ride-through time:............................................. 35 ms

LOW RANGE POWER SUPPLY

Nominal:.................................................................. 24 to 48 VDC

Range:......................................................................20 to 60 VDC

ALL RANGES

Voltage withstand:............................................. 2 × highest nominal voltage for 10 ms

Power consumption: ......................................... 15 W nominal, 20 W maximum

Fuse rating:............................................................ 5A fuse; time lag, slow blow, 350V 4.5 O.D. X 14.5mm

125 to 250 VDC

84 to 250 VDC

20 VA nominal, 40 VA maximum

1–20 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 31

CHAPTER 1: INTRODUCTION SPECIFICATIONS

Communications

SERIAL

RS485 port: ............................................................Opto-coupled

Baud rates:.............................................................up to 115 kbps

Response time:.....................................................1 ms typical

Parity: .......................................................................None, Odd, Even

Protocol: ..................................................................Modbus RTU, DNP 3.0, IEC 60870-5-103

Maximum distance: ...........................................1200 m (4000 feet)

Isolation:..................................................................2 kV

ETHERNET (COPPER)

Modes:......................................................................10/100 MB (auto-detect)

Connector:..............................................................RJ-45

Protocol: ..................................................................Modbus TCP, DNP3.0, IEC 60870-5-104, IEC 61850 GOOSE,

IEC 61850, OPC-UA

ETHERNET (FIBER)

Fiber type: ..............................................................100 MB Multi-mode

Wavelength: ..........................................................1300 nm

Connector:..............................................................MTRJ

Protocol: ..................................................................Modbus TCP, DNP3.0, IEC 60870-5-104, IEC 61850 GOOSE,

IEC 61850, OPC-UA, PRP, HSR

Transmit power:...................................................-20 dBm

Receiver sensitivity: ...........................................-31 dBm

Power budget: ......................................................9 dB

Maximum input power:....................................-11.8 dBm

Typical distance:..................................................2 km (1.25 miles)

Duplex:.....................................................................half/full

Maximum number of TCP/IP sessions: .....3

Product type: ........................................................Class 1 Laser product

USB

Standard specification: ....................................Compliant with USB 2.0

Data transfer rate:..............................................115 kbps

OPC-UA (OLE FOR PROCESS CONTROL - UNIFIED ARCHITECTURE)

DA Server:...............................................................Transmission of real-time data to Clients

A&E Server: ............................................................Transmission of Event information to Clients. Acknowledge

and confirmation permitted from Client side

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 1–21

Page 32

SPECIFICATIONS CHAPTER 1: INTRODUCTION

Testing and certification

TYPE TESTS

TEST REFERENCE STANDARD TEST LEVEL

Dielectric voltage withstand (high voltage power supply*) 60255-27 2200 VAC for one second (low voltage power supply*) 60255-27 550 VAC for one second * Test level is based on basic insulation principle (Power supply I/P terminals tested to Chassis

ground). Impulse voltage withstand EN60255-27 5 kV Damped Oscillatory IEC 60255-26 / IEC61000-4-18 2.5 kV CM, 1 kV DM Electrostatic Discharge IEC 60255-26 / IEC 61000-4-2 15 kV / 8 kV RF immunity IEC 60255-26 / IEC 61000-4-3 80 MHz - 1 GHz,

Fast Transient Disturbance IEC 60255-26 / IEC 61000-4-4 2 kV / 4 kV Surge Immunity IEC 60255-26 / IEC 61000-4-5 0.5, 1 & 2 kV Conducted RF Immunity IEC 60255-26 / IEC 61000-4-6 150 kHz - 80 MHz,

Voltage interruption and Ripple DC IEC 60255-26 / IEC 60255-4-11 15% ripple, 200ms

Radiated & Conducted Emissions CISPR11 / CISPR22/

IEC 60255-26: Section 7.1.2 & 7.1.3 Sinusoidal Vibration IEC 60255-21-1 Class 1 Shock & Bump IEC 60255-21-2 Class 1 Seismic IEC 60255-21-3 Class 2 Power magnetic Immunity IEC 60255-26 / IEC 61000-4-8 1000 A/m, 100 A/m,

Voltage Dip & interruption IEC 60255-26 / IEC 61000-4-11 0, 40, 70, 80% dips, 250/

Power frequency IEC 60255-26 / IEC 61000-4-16 Level 4 Voltage Ripple IEC 60255-26 / IEC 61000-4-17 15% ripple Ingress Protection IEC 60529 IP54 front Environmental (Cold) IEC 60068-2-1 -40°C 16 hrs Environmental (Dry heat) IEC 60068-2-2 85°C 16hrs Relative Humidity Cyclic IEC 60068-2-30 6 day variant 2 EFT IEEE / ANSI C37.90.1 4KV, 2.5Khz Damped Oscillatory IEEE / ANSI C37.90.1 2.5KV, 1Mhz RF Immunity IEEE / ANSI C37.90.2 35V/m (max field),

ESD IEEE / ANSI C37.90.3 8KV CD/ 15KV AD

UL 508 e83849 NKCR Safety UL C22.2-14 e83849 NKCR7

UL 1053 e83849 NKCR

1.4 GHz - 2.7 GHz, 10 V/m

26 MHz - 68MHz, 10V/m

interrupts Class A

30A/m 300 A/m

300 cycle interrupts

(80 MHz-1 GHz with 1 KHz sine and 80% AM modulation)

1–22 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 33

CHAPTER 1: INTRODUCTION SPECIFICATIONS

APPROVALS

Applicable Council Directive According to:

Low voltage directive 2014/35/EU

CE compliance EMC Directive 2014/30/EU

UL 508

North America cULus UL 1053

C22.2. No 14 EAC Machines and Equipment TR CU 010/2011 Lloyd’s Register Rules and Regulations for the

Classifications of Ships IEC 61850 IEC 61850 Certificate Level B IEC 61850-10 ISO Manufactured under a registered

quality program

Marine Applications: ENV2, ENV3

ISO9001

EAC

The EAC Technical Regulations (TR) for Machines and Equipment apply to the Customs Union (CU) of the Russian Federation, Belarus, and Kazakhstan.

Item Description

Country of origin Spain or Canada; see label on the unit Date of manufacture See label on the side of the unit Declaration of Conformity and/or Certificate of

Conformity

Available upon request

Physical

DIMENSIONS

NOTE:

Refer to Chapter 2 for details

NON-DRAWOUT UNIT

Height:...................................................................... 7.98” (202.7 mm)

Width: ....................................................................... 6.23” (158.2 mm)

Length:..................................................................... 9.35” (237.5 mm)

DRAWOUT UNIT

Height:...................................................................... 7.93” (201.51 mm)

Width: ....................................................................... 6.62” (138.2 mm)

Length:..................................................................... 9.62” (244.2 mm)

WEIGHT

NON-DRAWOUT UNIT

Weight (net): .......................................................... 2.9 kg (6.4 lbs)

Weight (gross):...................................................... 4.0 kg (8.6 lbs)

DRAWOUT UNIT

Weight (net): .......................................................... 3.9 kg (8.6 lbs)

Weight (gross):...................................................... 5.0 kg (11.0 lbs)

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 1–23

Page 34

SPECIFICATIONS CHAPTER 1: INTRODUCTION

Environmental

OPERATING ENVIRONMENT

Ambient temperatures: Storage/Shipping: -40 Operating: -40

Humidity: Operating up to 95% (non condensing) @ 55

Altitude: 2000 m (max) Pollution Degree: II Overvoltage Category: III Ingress Protection: IP54 Front, IP20 cover (optional) Noise: 0 dB

C to 85oC

C to 60oC

per IEC60068-2-30 Variant 2, 6 days)

C (As

1–24 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 35

Grid Solutions

350 Feeder Protection System

Chapter 2: Installation

Mechanical installation

Installation

This section describes the mechanical installation of the 350 system, including dimensions for mounting and information on module withdrawal and insertion.

This equipment is Suitable for mounting on the flat surface of a Type 1 Enclosure

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 2–1

Page 36

MECHANICAL INSTALLATION CHAPTER 2: INSTALLATION

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 >PP@

+$1'/(1(('672%(527$7(' :+,/(6/,',1*7+('5$:287 81,7,172&$37,9(81,7

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Dimensions

The dimensions of the 350 are on the following pages. Additional dimensions for mounting and panel cutouts are shown in the following sections.

Figure 2-1: 350 dimensions - Drawout unit

2–2 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 37

CHAPTER 2: INSTALLATION MECHANICAL INSTALLATION

6.23"

(158.2mm)

7.98"

(202.7mm)

1.47"

(37.3mm)

7.88"

(200.2mm)

6.82"

(173.2mm)

3.96"

(100.6mm)

."

(.mm)

Figure 2-2: 350 dimensions - Non-drawout unit

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 2–3

Page 38

MECHANICAL INSTALLATION CHAPTER 2: INSTALLATION

NOTE

Technical Support: Worldwide: +1 905 927 7070 North America: 1 800 547 8629 www.gegridsolutions.com/multilin/ 650 Markland Street, Markham ON, Canada L6C 0M1 MFG. Date:Mar. 11, 2017

Feeder Protection System

Model:350-E-P1-G1-H-E-S-N-M-2E-N-N Serial Number:ML1A16000098

Power Supply: 125-250V 20W 120-240V 50/60Hz 36VA Output Ratings: Refer to Instruction manual Input Ratings: 300 VDC @ 2mA Instruction Manual: GEK-113507 Pollution Degree 2 / Degré de pollution 2

Multilin 350

ML1A160000988U

ML1A160000988

Technical Support: Worldwide: +1 905 927 7070 North America: 1 800 547 8629 www.gegridsolutions.com/multilin/ GE POWER MANAGEMENT S.L. AV Pinoa 10, 48170 Zamudio, Spain MFG. Date:Mar. 11, 2017

Feeder Protection System

Model:350-E-P1-G1-H-E-S-N-M-2E-N-N Serial Number:BL1A16000098

Power Supply: 125-250V 20W 120-240V 50/60Hz 36VA Output Ratings: Refer to instruction manual Input Ratings: 300 VDC @ 2mA Instruction Manual: GEK-113507 Pollution Degree 2 / Degré de pollution 2

Multilin 350

ML1A160000988U

ML1A160000988

Product identification

The product identification label is located on the side panel of the 350 . This label indicates the product model, serial number, and date of manufacture.

Figure 2-3: 350 Product labels

NOTE:

Standard panel mount The standard panel mount and cutout dimensions are illustrated in the following figures.

CAUTION:

The pink color text (i.e. Model, Serial Number, Instruction Manual, MFG. Date) is for reference only. The text can vary.

Mounting

To avoid the potential for personal injury due to f ire hazards, ensure the unit is mounted in a safe location and/or within an appropriate enclosure.

2–4 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 39

CHAPTER 2: INSTALLATION MECHANICAL INSTALLATION

8 - 32X3/8IN P/HD PHIL BLK GE PART # 1408-0306; (QTY:8) TIGHTENING TORQUE: 15 IN LB

8-32 x 3/8" P/HD PHIL BLK GE P/N 1408-0306 (QTY:8) Tightening Torque: 15 in-lb (1.7 Nm)

Panel with Cutout

NDO unit

Figure 2-4: Standard panel mounting - Drawout

Figure 2-5: Standard Panel mounting - Non-drawout

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 2–5

Page 40

MECHANICAL INSTALLATION CHAPTER 2: INSTALLATION

BOTTOM TAB

“V” TABS

Figure 2-6: Depth Reducing collar (optional)

Panel mounting with depth reducing collar:

1. Mount the collar of required depth (1.375” or 3”) to the unit (captive or non-drawout) using 4 screws (see above).

2. Mount the combination of unit and collar to the panel using 4 screws as shown above.

Figure 2-7: Mounting tabs (optional)

1. From the front of the panel, slide the empty case into the cutout until the bottom tab clicks into place (see above).

2. From the rear of the panel screw the case into the panel at the 8 screw positions shown above.

2–6 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 41

CHAPTER 2: INSTALLATION MECHANICAL INSTALLATION

5.350” 0.010”

(135.9 mm 0.25mm)

4.100” 0.010”

(104.1 mm 0.25 mm)

0.200”

(5.1 mm)

6.900” 0.010”

(175.3 mm 0.25 mm)

6.000” 0.010”

(152.4 mm 0.25 mm)

4.000” 0.010”

(101.6 mm 0.25 mm)

3. If added security is required, bend the retaining "V"tabs outward, to about 90°. These

tabs are located on the sides of the case and appear as shown above.

The relay can now be inserted and can be panel wired.

Figure 2-8: Panel cutout dimensions

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 2–7

Page 42

MECHANICAL INSTALLATION CHAPTER 2: INSTALLATION

350 ADAPTER PLATEFOR S1, S2, MDP, & IAC GE PART#: 1463-0011 QTY: 1

ASSEMBLYINSTRUCTIONS:

- MOUNT THE ADAPTER PLATEIN THE CORRECT ORIENTATION (FRONT SURFACE OUTSIDE) PER THE VIEW. MAKE SURE THE MOUNTING SCREWS (GE PART# 1410-0112)DO NOT PENETRATE THROUGHTHE ADAPTER PLATE FRONT SURFACE.

- MOUNT THE CAPTIVE UNIT WITH THEADAPTER PLATE.

- SLIDE AND LOCK THE DRAWOUTUNIT INTO THE CAPTIVE UNIT.

350 DRAWOUT & CAPTIVE UNIT

WASHER LOCK ZINC NO. 8 GE PART#: 1430-0003 QTY: 8

18-8 FILLISTER HEAD PHILLIPS MACHINE SCREW 8-32 THREAD, 3/8” LENGTH GE PART#: 1408-0015 QTY: 8 TIGHTENING TORQUE: 15 LB-IN

EXISTING PANELCUT-OUT FOR S1, S2, MDP,OR IAC

18-8 STAINLESS STEELFLAT WASHER NO. 10L SZ, .438” OD, .028 - .036” THK, GE PART#: 1430-0039 QTY: 4

NOTE: USE SCREW & ONE FLATWASHERFOR PANEL THICKNESS OF 0.090”. USE ADDITIONAL WASHERS OR REMOVE WASHERS FOR THINNER OR THICKER PANELS. THIS PROVIDES MOUNTING FOR ADAPTER PLATEFOR PANELTHICKNESS RANGE BETWEEN 0.06” AND 0.125”.

SCREW 10-32X1/4” PAN HD PHIL 18-8SS WITH EXTERNAL LOCK WASHER GE PART#: 1410-0112 QTY: 4 TIGHTENING TORQUE: 22 LB-IN

SURFACE WITH FLUSH NUTS IS THE FRONT SURFACE OF THE ADAPTER PLATE

FRONT SURFACE

350 ADAPTER PLATE

FOR S1, S2, MDP, & IAC

11.000”

279.4 mm

8.000”

203.2 mm

0.114”

2.9 mm

350 ADAPTER PLATE FOR SR735

11.000”

279.4 mm

8.000”

203.2 mm

6.123”

155.5 mm

9.750”

247.7 mm

#10-32 NUT QTY: 4

350 ADAPTER PLATEFOR SR735 GE PART#: 1463-0012 QTY: 1

- THIS STEP IS FOR SR735 REPLACEMENT ONLY: CREATE 4 HOLES (0.250” DIA) ON EXISTING PANELAT #10-32 NUT LOCATION SHOWN IN ADAPTER PLATE AT BOTTOM RIGHT.

Mounting using the

S1/S2/MDP/IAC or

SR735 adapter plate

Retrofit Kit Kit Part Number Adapter Plate Washer

Lock (8)

Machine Screws (8)

Flat Washers (4) Screws with ext.

Lock Washers (4)

350 Retrofit Kit for 735 1819-0103 1463-0012 1430-0003 1408-0015 1430-0039 1410-0112 350 Retrofit Kit for IAC Relay 1819-0102 1463-0011 1430-0003 1408-0015 1430-0039 1410-0112 350 Retrofit Kit for MDP Relay 1819-0101 1463-0011 1430-0003 1408-0015 1430-0039 1410-0112 350 Retrofit Kit for S1/S2 Cut-Out 1819-0100 1463-0011 1430-0003 1408-0015 1430-0039 1410-0112

CAUTION:

To avoid the potential for personal injury due to f ire hazards, ensure the unit is mounted in a safe location and/or within an appropriate enclosure.

The adaptor plate for mounting the 350 directly over the existing S1/S2/MDP/IAC or SR735 mounting plate, is shown below:

Figure 2-9: Adaptor Plate mounting - Drawout case

2–8 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 43

CHAPTER 2: INSTALLATION MECHANICAL INSTALLATION

350 ADAPTER PLATE

FOR SR735

11.000”

279.4 mm

8.000”

203.2 mm

6.123”

155.5 mm

9.750”

247.7 mm

#10-32 NUT QTY: 4

Figure 2-10: Non-drawout - Adapter plate mounting

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 2–9

Page 44

MECHANICAL INSTALLATION CHAPTER 2: INSTALLATION

5.350” 0.010”

(135.9 mm 0.25mm)

4.100” 0.010”

(104.1 mm 0.25 mm)

0.200”

(5.1 mm)

6.900” 0.010”

(175.3 mm 0.25 mm)

6.000” 0.010”

(152.4 mm 0.25 mm)

4.000” 0.010”

(101.6 mm 0.25 mm)

Figure 2-11: Panel cutout dimensions

2–10 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 45

CHAPTER 2: INSTALLATION MECHANICAL INSTALLATION

KEEP THE HANDLE IN ITS ROTATED POSITION UNTIL THE DRAW-OUT UNIT IS INSERTED COMPLETELY

PUSH THE HANDLE DOWN AND TIGHTEN THE SCREW UNTIL THE HANDLE IS PARALLEL WITH THE FRONT PANEL SURFACE

THE HANDLE MUST BE ROTATED 90 WHILE SLIDING THE

DRAW-OUT

UNIT INTO THE CAPTIVE UNIT

⁰

8 - 32X3/8IN P/HD PHIL BLK GE PART # 1408-0306; (QTY:8) TIGHTENING TORQUE: 15 IN LB

Drawout unit withdrawal and insertion

Figure 2-12: Unit withdrawal and insertion diagram

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 2–11

Page 46

MECHANICAL INSTALLATION CHAPTER 2: INSTALLATION

IP20 Cover (optional)

The IP20 cover minimizes potential dangers to users by preventing finger contact with electrical connections at the back of the 3 Series drawout units.

Attaching the cover

The steps for attaching the IP20 cover (optional) to the drawout unit are as follows:

Figure 2-13: IP20 Cover mounting - Drawout unit only

1. Place 4 custom standoffs (item#1) using the suggested tightening torque of 8lb-in in the following order:

A. Remove the 2 mounting screws near letters A and C, of label ABC (item#2), and mount 2 standoffs.

B. Remove the 2 mounting screws near the letters B and E, of label ABCDE (item#3), and mount 2 standoffs.

2. Place the IP20 cover (item#4) and secure it with 4 screws (item#5) using the suggested tightening torque of 8lb-in.

NOTE:

Make sure the device terminals are wired before placing the cover. Use the 5 slots located on each side of the cover to guide the wires outside of the cover.

Retrofit kit for IP20

Before attaching the cover, remove the old labels from the device (see item#2 and item#3) and replace them with the new labels from the retrofit kit. Attach the cover as described in the previous section.

2–12 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 47

CHAPTER 2: INSTALLATION MECHANICAL INSTALLATION

Duplex Connector

Single Connectors

Bulkhead Connectors

Sensor Fiber (length Y)

Loop Sensor (with Sensor Fiber Extension)

350 Relay

Single Connectors

Sensor Fiber (maximum length 70 m)

Loop Sensor

Duplex Connector

Point Sensor Assembly

Point Sensor

350 Relay

Duplex Sensor Fiber (maximum length 35 m)

Duplex Sensor Fiber (length X)

Sensor Fiber Extension

Total Sensor Fiber Length = 2 times(length X) + length Y (maximum 70 m)

Single Connectors

Arc flash sensors

Arc flash sensors house the fiber optics that are used to detect the arc flash. Mounting details depend on the sensor type (point or loop).

For detailed installation, testing and maintenance guidance for Arc Flash sensors, see GET20057 3 Series Arc Flash Application Note.

CAUTION:

If the relay is used in the computation for reducing the Hazard Reduction Category code, operands for sensor failures must be assigned to an auxiliary output relay which must be connected into the control logic of the breaker equipment to ensure safe operations when the output relay is asserted. In the event of this assertion, the Hazard Reduction Category code cannot be maintained unless backup protection is continuing to maintain it.

CAUTION:

This product uses optical electronic devices (line or point sensors) to sense arc flash fault conditions. It is recommended to follow proper housekeeping measures & establish a regularly scheduled preventive maintenance routine to ensure proper device operation. For maintenance recommendations, see GET-20057 3 Series Arc

Flash Application Note

Arc flash sensors are available in two different configurations, point and loop. Loop sensors can be used with a black-coated sensor fiber extension to connect the ends of the loop sensor to the 350 relay through panels up to 51 mm (2 inches) thick.

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 2–13

Page 48

MECHANICAL INSTALLATION CHAPTER 2: INSTALLATION

Arc flash sensors of either type can be connected to any of the four arc flash ports on the back of the 350 relay, as shown.

Figure 2-14: Arc flash sensors connected to a 350 relay

Sensor fiber handling

& storage

CAUTION:

2–14 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Arc Flash sensor fiber is pressure sensitive and must be handled carefully to avoid damage. Read the following guidelines fully before proceeding.

Care must be taken when handling the Arc Flash sensor fiber, which can be damaged if twisted, bent, or clamped tightly during installation.

• Do not bend sensor fiber sharply, or with a radius of less than 35 mm (1.3 inches). Sharp bends can damage the fiber. Do not pull or tug loops of sensor fiber, as sharp bends may result.

• Do not clamp sensor fiber tightly during installation. Sensor fiber should be held in place loosely for the best long-term performance. Avoid over-tightening ties which may deform or break the sensor fiber.

• Do not pull or tug sensor fiber with force, as this may cause internal damage or separate the fiber from the cable connector.

• Do not twist the sensor fiber, as twisting can damage the fiber resulting in substandard performance.

• Do not attach sensor fiber directly to the bus or other live conductors.

Page 49

CHAPTER 2: INSTALLATION MECHANICAL INSTALLATION

• Avoid surface temperatures above 70 °C or 158 °F to prolong the life of the fiber.

• Secure all sensor fibers (loosely but securely) away from any moving parts.

Point sensor

installation

Figure 2-15: Arc flash point sensor without sensor fiber connected

Figure 2-16: Point sensor and slim connector dimensions

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 2–15

Page 50

MECHANICAL INSTALLATION CHAPTER 2: INSTALLATION

Figure 2-17: Duplex connector dimensions (point sensor, and sensor fiber extension for loop sensor)

FASTPATH:

The point sensor fiber includes a duplex connector to connect to the back of the 350 relay on one end, and a compressed slim connector that connects to the sensor itself on the other end.

Before installing the AF sensor units, ensure that all other drilling and installation is complete to minimize possible damage to the sensitive unit and connected sensor fiber cable. Choose a location for the sensor clear of any obstructions that could shield the sensor from arc flash light.

Review the sensor fiber handling guidelines above.

Sensor fiber should be held in place loosely for the best long-term performance. Avoid over-tightening ties which may deform or break the sensor fiber.

General installation:

1. Choose a location for the point sensor. Arc flash point sensors should be installed clear of any obstructions that could shield

the sensor from arc flash light, and less than 2m (6ft 6") from any potential arc flash source.

The sensor head should be pointed towards the most likely source of arc flash. For further guidance selecting point sensor locations, see GET-20057 3 Series Arc

Flash Application Note.

2. Remove the slim connector from the point sensor assembly.

3. Carefully route the duplex sensor fiber from the point sensor location to the back of the relay unit, minimizing loops and curves for the strongest possible signal. Ensure all sensor fiber handling precautions are followed.

2–16 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 51

CHAPTER 2: INSTALLATION MECHANICAL INSTALLATION

The slim connecter fits through holes with a radius of 11 mm or greater, and can be threaded through holes drilled in any panels between the relay and arc flash detection location.

NOTE:

Install protective grommets when routing sensor fiber through metal walls.

4. Mount the point sensor using either a cable tie mount or through-hole mount, as

detailed below.

5. Reconnect the slim connector to the point sensor. Arc flash point sensors can be installed in one of two ways, using a cable tie mount or a

through-hole mount.

Cable tie mount:

• Requires a 2.5-mm-wide cable tie.

• Mount the sensor on a stick or similar using the cable tie, as shown in the following

figure.

Figure 2-18: AF point sensor, cable tie mount

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 2–17

Page 52

MECHANICAL INSTALLATION CHAPTER 2: INSTALLATION

Through-hole mount

• Requires a standard or self-tapping M3 screw, and optionally an M3 washer.

• Mount the sensor through a 10 mm hole made in the surface of any mechanical structure inside the switchgear or on the surface of one side of the switchgear itself, as shown in the following figure.

Figure 2-19: AF point sensor, through-hole mount

Figure 2-20: AF point sensors connected to 350 relay

Make sure there is no dirt or dust inside the point sensor or on the surface because it reduces the capturing efficiency of the device, increases its transmission loss, or both. If the point sensor is covered with dust, clean it by blowing or wiping the dust off the point sensor.

FASTPATH:

The material of the point sensor is not affected by water-based cleaning agents, dish soap, or organic solvents with an alcohol (ethanol) base. Do not use solvents or solvent mixtures that contain acids because they can attack or dissolve the optical plastic material.

2–18 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 53

CHAPTER 2: INSTALLATION MECHANICAL INSTALLATION

Loop sensor

installation

The loop sensor transparent sensor fiber has a single connector on either end. The sensor fiber extension has a duplex connector on one end, two single connectors on the other end, and comes with two single bulkhead connectors. Both come in custom lengths, which can be ordered to fit your installation.

Figure 2-21: Single connector dimensions (loop sensor, and sensor fiber extension for loop sensor)

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 2–19

Page 54

MECHANICAL INSTALLATION CHAPTER 2: INSTALLATION

Figure 2-22: Duplex connector dimensions (point sensor, and sensor fiber extension for loop sensor)

Figure 2-23: Single bulkhead connector dimensions

2–20 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 55

CHAPTER 2: INSTALLATION MECHANICAL INSTALLATION

Figure 2-24: Single bulkhead connector with single connectors and sensor f iber

Before installing the AF sensor units, ensure that all other drilling and installation is complete to minimize possible damage to the sensitive unit and connected sensor fiber cable.

FASTPATH:

Review the sensor fiber handling guidelines above.

Sensor fiber should be held in place loosely for the best long-term performance. Avoid over-tightening ties which may deform or break the sensor fiber.

1. Plan the path of the loop sensor fiber, looping through the chamber or chambers

requiring arc flash detection. See GET-20057 3 Series Arc Flash Application Note for detailed examples of loop sensor installation.

2. Ensure that both ends of the loop remain close enough together to be reached by the

sensor fiber extension. If needed, gently pull apart the duplex sensor fiber extension from the end with two single connectors, being careful not to bend the fiber with a radius of less than 35 mm (1.3 inches).

3. Ensure that the sensor fiber extension is long enough to reach the 350 relay from the

bulkhead connector location.

4. Mount the bulkhead connector on the side of the chamber, following the drill hole

dimensions provided. Note that the single bulkhead connector uses washers 11.0 mm (0.420 in) wide, so the drill holes must be spaced accordingly if the loop sensor path begins and ends in the same place.

Figure 2-25: Bulkhead connector cutout

5. Install the loop sensor carefully, following all sensor fiber handling guidelines.

6. Plug the ends of the loop sensor into the bulkhead connectors.

7. Plug the single connectors on the sensor fiber extension into the other sides of the

bulkhead connectors, and the duplex connector into the back of the 350 relay.

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 2–21

Page 56

ELECTRICAL INSTALLATION CHAPTER 2: INSTALLATION

Electrical installation

This section describes the electrical installation of the 350 system, including typical wiring diagrams and terminal identification.

2–22 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 57

898728.CDR

POWER SUPPLY

chassis

gnd

C8 C9

C10

DIGITAL INPUTS

52a (C1 #1)

52b (C1 #2)

INPUT 3

INPUT 4

INPUT 5

INPUT 6

INPUT 7

INPUT 8

INPUT 9

INPUT 10

ETHERNET

RJ45

mTRJ

10/100BASE-T

100BASE-FX

USB

TYPE B

A10

A11

A12

B10

B11

B12

4 WIRE USB

4 WIRE ETHERNET

USB

F5 F4 F3

RS485

IRIG-B

F1F2

COMMUNICATIONS

CONTROL

POWER

ABC

FEEDER

BUS Vts

IAI

FEEDER Cts

CONNECT AUX_VT AS REQUIRED

VOLTAGE INPUTS

WYE VT

CONNECTION

E10

D10

E11

D11

E12

D12

AVA

VXV

7 CRITICAL

FAILURE RELAY

3 AUXILIARY

4 AUXILIARY

5 AUXILIARY

6 AUXILIARY

2CLOSE

1TRIP

OPEN DELTA V T CONNECTION

E9 D9 E10 D10 E11 D11

OPTIONAL

DIRECTION OF POWER FLOW FOR POSITIVE WATTS POSITIVE DIRECTION OF LAGGING VARs

Front Panel

Rear Panel

350 Feeder Protection System

52a

52b

Breaker Aux Contacts

C11

C12

COMMON

CHASSIS GND

CURRENTINPUTS

PERSONAL COMPUTER

OUTPUT CONTACTS SHOWN WITH NO CONTROL POWER

TRIP CIRCUIT

CLOSE CIRCUIT

TRIP COIL

COIL

52b

52a

GROUND BUS

SEE COMMUNICATIONS WIRING IN INSTRUCTION MANUAL

1A OR 5A

COM

GE Multilin

COM

RS485

GROUND BUS

GND STUD

CHAPTER 2: INSTALLATION ELECTRICAL INSTALLATION

Typical wiring diagrams

Figure 2-26: Typical wiring diagram - Drawout

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 2–23

Page 58

898803A2.CDR

POWER SUPPLY

chassis

gnd

B10

DIGITAL INPUTS

52a (C1 #1)

52b (C1 #2)

INPUT 3

INPUT 4

INPUT 5

INPUT 6

INPUT 7

INPUT 8

INPUT 9

INPUT 10

ETHERNET

RJ45

mTRJ

10/100 BASE-T

100 BASE-FX

USB

TYPE B

A11

A13

A15

A17

A19

A21

A10

A12

A14

A16

A18

A20

4 WIRE USB

4 WIRE ETHERNET

USB

C5 C4 C3

RS485

IRIG-B

C1C2

COMMUNICATIONS

CONTROL

POWER

ABC

FEEDER

BUS Vts

IAI

FEEDER Cts

CONNECT AUX_VT AS REQUIRED

VOLTAGE INPUTS

WYE VT

CONNECTION

E10

D10

E11

D11

E12

D12

AVA

VXV

7 CRITICAL FAILURE RELAY

3 AUXILIARY

4 AUXILIARY

5 AUXILIARY

6 AUXILIARY

2 CLOSE

1 TRIP

OPEN DELTA VT CONNECTION

E9 D9 E10D10 E11D11

OPTIONAL

DIRECTION OF POWER FLOW FOR POSITIVE WATTS POSITIVE DIRECTION OF LAGGING VARs

Front Panel

Rear Panel

350 Feeder Protection System

52a

52b

Breaker Aux Contacts

B11

B12

COMMON

CHASSIS GND

CURRENT INPUTS

PERSONAL COMPUTER

OUTPUT CONTACTS SHOWN WITH NO CONTROL POWER

TRIP CIRCUIT

CLOSE CIRCUIT

TRIP COIL

COIL

52b

52a

GROUND BUS

SEE COMMUNICATIONS WIRING IN INSTRUCTION MANUAL

1A OR 5A

COM

GE Multilin

COM

RS485

GROUND BUS

GND STUD

Notes: A13 and A16 are not available for the optional Arc Flash solution. Arc Flash protection should

be connected to the SSR outputs (AUX5 and AUX6). If connected to other outputs using logic elements,

the total element operating time increases by 8 ms plus the logic element protection cycle timer.

Fibre Optic

AF1 AF2

ARC FLASH DETECTORS

AF3

AF4

TxRxTxRxTxRxTx

OPTIONAL - ARC FLASH

A15

A17

A14

A18

5 AUXILIARY

(SSR 1)

6 AUXILIARY

(SSR 2)

OPTIONAL - ARC FLASH

OUTPUT RELAYS

ELECTRICAL INSTALLATION CHAPTER 2: INSTALLATION

Figure 2-27: Typical wiring diagram - Non-drawout

2–24 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 59

CHAPTER 2: INSTALLATION ELECTRICAL INSTALLATION

NOTE

SCREW

WASHER

LOWER

TERMINAL

DIVIDER

TERMINAL

BLOCK

350 Terminal identification

NOTE:

When installing two lugs on one terminal, both lugs should be "right side up" as shown in the picture below. This is to ensure the adjacent lower terminal block does not interfere with the lug body.

Figure 2-28: Orient the Lugs correctly...

Figure 2-29: CORRECT INSTALLATION METHOD

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 2–25

Page 60

ELECTRICAL INSTALLATION CHAPTER 2: INSTALLATION

Figure 2-30: INCORRECT INSTALLATION METHOD (lower lug reversed)

2–26 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 61

CHAPTER 2: INSTALLATION ELECTRICAL INSTALLATION

INPUT 1

INPUT 2

INPUT 3

INPUT 4

INPUT 5

INPUT 6

INPUT 7

INPUT 8

INPUT 9

INPUT 10

INPUT COM

CHASSIS GND

PHASE A CT

PHASE B CT

PHASE C CT

GND CT

PHASE A VT

PHASE B VT

PHASE C VT

AUX VT

PHASE A CT

PHASE B CT

PHASE C CT

GND CT

PHASE A VT

PHASE B VT

PHASE C VT

AUX VT

■

IRIG-B + IRIG-B RS485 + RS485 RS485 COM CHASSIS GND RESERVED RESERVED

POWER SUPPLY +

CHASSIS GND

TRIP COM

CLOSE N/O

CLOSE OPTV

AUX 3 COM

AUX 4 N/C

AUX 4 N/O

AUX 5 COM

AUX 6 N/C

AUX 6 N/O

CRIT FAIL COM

POWER SUPPLY -

TRIP N/O

TRIP OPTV

CLOSE COM

AUX 3 N/C

AUX 3 N/O

AUX 4 COM

AUX 5 N/C

AUX 5 N/O

AUX 6 COM

CRIT FAIL N/C

CRIT FAIL N/O

A B C D E

1 2 3 4 5 6 7 8

Figure 2-31: 350 Terminal Identification - standard(drawout)

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 2–27

Page 62

ELECTRICAL INSTALLATION CHAPTER 2: INSTALLATION

INPUT 1 INPUT 2 INPUT 3 INPUT 4 INPUT 5 INPUT 6 INPUT 7 INPUT 8 INPUT 9 INPUT 10 INPUT COM CHASSIS GND

1 2 3 4 5 6 7 8

9 10 11 12

PHASE A CT

PHASE B CT

PHASE C CT

GND CT

PHASE A VT

PHASE B VT

PHASE C VT

AUX VT

PHASE A CT

PHASE B CT

PHASE C CT

GND CT

PHASE A VT

PHASE B VT

PHASE C VT

AUX VT

POWER SUPPLY -

POWER SUPPLY +

CHASSIS GND

TRIP COM

CLOSE N/O

CLOSE OPTV

AUX 4 N/C

AUX 4 N/O

AUX 5 COM

AUX 6 N/C

AUX 6 N/O

CRIT FAIL COM

1 2 3 4 5 6 7 8

9 10 11 12 13 14 15 16 17 18 19 20 21

IRIG-B + IRIG-B RS485 + RS485 RS485 COM CHASSIS GND RESERVED RESERVED

1 2 3 4 5 6 7 8

TRIP N/O

TRIP OPTV

CLOSE COM

AUX 3 N/C

AUX 3 N/O

AUX 4 COM

AUX 5 N/C

AUX 5 N/O

AUX 6 COM

CRIT FAIL N/C

CRIT FAIL N/O

AUX 3 COM

Figure 2-32: 350 Terminal Identification - Non-drawout

Wire range

Use the following guideline when selecting wires or lugs to connect to terminal blocks A,B,C,D,E (Drawout case design), and terminal blocks D,E (Non-drawout case design):

• 12 AWG to 22 AWG (3.3 mm2 to 0.3 mm2): Single wire termination with/without mm (0.375”) maximum diameter ring terminals.

9.53

• 14 AWG to 22 AWG (2.1 mm2 to 0.3 mm2): Multiple wire termination with matching

wire sizes and stranding. Two wires maximum per circuit.

• 14 AWG to 22 AWG (2.1 mm2 to 0.3 mm2): Multiple wire termination with 9.53 mm

(0.375”) maximum diameter ring terminals. Two ring terminals maximum per circuit.

• Suggested wiring screw tightening torque, tighten to 12 in-lb (1.35 N-m).

• The uncovered communications cable shield connected to the common terminal

should not exceed 1” (2.5 cm) for proper EMC shielding of the communications cable.

• Minimum suggested temperature rating for the conductors is 75C.

• Wire type: copper

Phase sequence and transformer polarity

For correct operation of the relay features, the user must follow the instrument transformer polarities, shown in the Typical Wiring Diagram. Note the solid square markings shown with all instrument transformer connections. When the connections

2–28 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

adhere to this drawing, the arrow shows the direction of power flow for positive watts and the positive direction of lagging vars. The phase sequence is user programmable for either ABC or ACB rotation.

Page 63

CHAPTER 2: INSTALLATION ELECTRICAL INSTALLATION

NOTE

Current inputs

The 350 relay has four (4) channels for AC current inputs, each with an isolating transformer. There are no internal ground connections on the current inputs. Current transformers with 1 to 6000 A primaries may be used.

CAUTION:

Verify that the relay’s nominal input current of 1 A or 5 A matches the secondary rating of the connected CTs. Unmatched CTs may result in equipment damage or inadequate protection.

CAUTION:

NOTE:

IMPORTANT: The phase and ground current inputs will correctly measure up to 20 times the current input’s nominal rating. Time overcurrent curves become horizontal lines for currents above the 20 × CT rating. This becomes apparent if the pickup level is set above the nominal CT rating.

Before working on CTs, they MUST be short circuited.

Ground and sensitive ground CT inputs

One dedicated ground input is referred to throughout this manual as the Ground Current or Sensitive Ground Current input. Before making ground connections, consider that the relay automatically calculates the neutral (residual) current from the sum of the three phase current phasors. The following figures show three possible ground connections (or three possible sensitive ground connections).

The ground input (Terminals D8 and E8) is used in conjunction with a Zero Sequence CT as source, or in the neutral of wye-connected source CTs. The ground current input can be used to polarize the neutral directional element. When using the residual connection set the GROUND CT PRIMARY setpoint to a value equal to the PHASE CT PRIMARY setpoint.

In cases where the relay is equipped with sensitive ground CT (terminals D8 and E8) the sensitive ground current input is intended for use either with a CT in a source neutral of a high-impedance grounded system, or on ungrounded systems. On ungrounded systems it is connected residually with the phase current inputs. In this case, the SENSTV GND CT PRIMARY setpoint should be programmed to a value equal to the PHASE CT PRIMARY setpoint. The sensitive ground current input can be connected to a Zero Sequence CT for increased sensitivity and accuracy when physically possible in the system.

The Sensitive Ground input must only be used on systems where the maximum ground current does not exceed current input specifications.

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 2–29

Page 64

ELECTRICAL INSTALLATION CHAPTER 2: INSTALLATION

SOURCE

898730A1.CDR

USED FOR POLARIZING

GROUND CURRENT INPUT

350

PHASE CURRENT

INPUTS

A B C

GROUND CURRENT INPUT WITH ZERO SEQUENCE CT

GROUND CURRENT INPUT

WITH RESIDUAL CONNECTION

E8 D8

GROUND

I N NI

GROUND

D8 E8

GROUND

D8E8

Ground connection to neutral must be on the source side

UNSHIELDED CABLE

LOAD

ABCN G

Ground outside CT

Source

LOAD

SHIELDED CABLE

898733.CDR

ABC

Source

To ground; must be on load side

Stress cone

shields

Figure 2-33: Ground/Sensitive Ground wiring

Zero sequence CT installation

The various CT connections and the exact placement of a Zero Sequence CT, for ground fault current detection, are shown in the figure below. Twisted pair cabling on the Zero Sequence CT is recommended.

Figure 2-34: Zero sequence core balance (CT) installation

2–30 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 65

CHAPTER 2: INSTALLATION ELECTRICAL INSTALLATION

NOTE

FFEEDER

TO BUS VTsTO BUS VTs

E12

AUX

D12

1 2

E12

1V2

AUX

D12

2V1

AUX

E12 D12

2V1

AUX

E12 D12

V1V

AUX

E12 D12

Van Vbn Vcn Vab Vbc

898734.CDR

V1V

AUX

E12 D12

Vca

Voltage inputs

The 350 relay has four channels for AC voltage inputs, each with an isolating transformer. Voltage transformers up to a maximum 5000:1 ratio may be used. The nominal secondary voltage must be in the 50 to 240 V range.The three phase inputs are designated as the “bus voltage”. The Bus VT connections most commonly used, wye and delta (or open delta), are shown in the typical wiring diagram.

NOTE:

If Delta VTs are used, the zero sequence voltage (V0) and neutral/sensitive ground polarizing voltage (–V0) will be zero. Also, with the Delta VT connection, the phase-neutral voltage cannot be measured and will not be displayed.

NOTE:

CAUTION:

The 350 relay can be applied to both metering and protection feeders with up to 550 kV phase-to-phase voltage. Please ensure that the selected VT ratio and VT secondary do not result in a primary voltage exceeding 550 kV.

The single phase input is designated as the “Aux VT Input”. The Aux VT input channel can be connected for either phase-neutral voltage Van, Vbn, Vcn, or for phase-phase voltage Vab, Vbc, Vca as shown below.

Figure 2-35: Auxiliary VT connections

Control power

Control power supplied to the relay must match the installed power supply range. If the applied voltage does not match, damage to the unit may occur. All grounds MUST be connected for safe, normal operation regardless of control power supply type.

The label found on the relay specifies its order code or model number. The installed power supply’s operating range will be one of the following:

LO: 24 to 48 V DC (Range: 20 to 60 V DC) HI: 125 to 250 V DC/120 to 240 V AC (Range: 84 to 250 V DC/60 to 300 V AC (50 and 60

Hz))

CAUTION:

The relay should be connected directly to the ground bus, using the shortest practical path. A tinned copper, braided, shielding and bonding cable should be used. As a minimum, 96 strands of number 34 AWG should be used. Belden catalog number 8660 is suitable.

CAUTION:

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 2–31

Isolate power prior to servicing.

Page 66

ELECTRICAL INSTALLATION CHAPTER 2: INSTALLATION

PPOWER

OR BRAIDED WIRE

HEAVY COPPER CONDUCTORHEAVY COPPER CONDUCTOR

GROUND BUSGROUND BUS

SWITCHGEAR

GROUND

CHASSIS

RELAY

CONTROL

898735.CDR898735.CDR

CONTROL

POWER

Wet Contact Connection

36(5,(6 RELA

C1Contact Input 1

Contact Input Common

C11

V DC Power

Supply

LOGICIN.CDR

NOTE:

CAUTION:

An external switch, circuit breaker, or other protective device must be connected near to the equipment.

Figure 2-36: Control power connection

Contact inputs

External contacts can be connected to the relay’s ten (10) digital inputs. These contacts are wet only.

The inputs can be programmed to different thresholds depending on the DC voltage (17, 33, 84, 166).

Ensure correct polarity on contact input connections and do not connect any contact input circuits to ground or else relay hardware may be damaged.

2–32 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

A wet contact has one side connected to the positive terminal of an external DC power supply. The other side of this contact is connected to the required contact input terminal. In addition, the negative side of the external source must be connected to the relay’s DC negative rail at Terminal C11. The maximum external source voltage for this arrangement is 300 V DC.

Figure 2-37: Wet contact connections

Page 67

CHAPTER 2: INSTALLATION ELECTRICAL INSTALLATION

NOTE

Trip and Close output relays

The 350 relay is equipped with seven electromechanical output relays: two special relays designed for Breaker trip and close (Relay 1 “Trip”, Relay 2 “Close”), four general purpose relays (Auxiliary Relays 3 to 6), and a Critical Failure relay. The special purpose relays have fixed operating characteristics and the general purpose relays can be configured by the user.

Operation of the Trip and Close output relays is designed to be controlled by the state of the circuit breaker as monitored by a 52a or 52b contact.

• The Trip and Close relays reset after the breaker is detected in a state corresponding to the command. When a relay feature sends a command to one of these special relays, it will remain operational until the requested change of breaker state is confirmed by a breaker auxiliary contact and the initiating condition has reset.

• If the initiating feature resets, but the breaker does not change state, the output relay will be reset after a default interval of 2 seconds.

• If neither of the breaker auxiliary contacts, 52a nor 52b, is programmed to a contact input, the Trip Relay is de-energized after either the delay programmed in the Breaker Failure feature, or a default interval of 100 ms after the initiating input resets. The Close Relay is de-energized after 200 ms.

• If a delay is programmed for the Trip or Close contact seal-in time, then this delay is added to the reset time. Note that the default setting for the seal-in time is 40 ms.

52a Contact Configured

Yes Yes Trip Relay remains operational until 52b indicates an

Yes No Trip Relay remains operational until 52a indicates an

No Yes Trip Relay remains operational until 52b indicates an

No No Trip Relay operates until either the Breaker Failure delay

52b Contact Configured

Relay Operation

open breaker. Close Relay remains operational until 52a indicates a closed breaker.

open breaker. Close Relay remains operational until 52b indicates a closed breaker.

expires (if the Breaker Failure element is enabled), or 100 ms after the feature causing the trip resets. Close Relay operates for 200 ms.

Breaker monitoring (Trip and Close coil monitoring) is performed by a built-in voltage monitor on Form A output relays: #1 Trip, and #2 Close. The voltage monitor is connected across each of the two Form A contacts, and the relay effectively detects healthy current through the circuit. In order to do this, an external jumper must be connected between terminals A2 and A3 for Trip coil monitoring, or/and B4, and B5 for Close coil monitoring.

As long as the current through the Voltage Monitor is above the threshold of the trickle currents (see Technical Specification for Form A output relays), the circuit integrity for the Trip (Close) coil is effectively normal. If the Trip (Close) coil circuit gets disconnected, or if in general a high resistance is detected in the circuitry, a Trip (Close) alarm will be set and the “ALARM” and “MAINTENANCE” LEDs will be on.

Example 1: The figures below show the two different connections of the breaker trip (close) coil to the relay’s trip output #1 terminals (output #2 Close coil monitoring) for both no voltage monitoring and voltage monitoring of the trip (close) circuit integrity.

NOTE:

To monitor the trip coil circuit integrity, use the relay terminals A2 and B3 to connect the Trip coil, and provide a jumper between terminals A2 (optional voltage) and A3.

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 2–33

Page 68

ELECTRICAL INSTALLATION CHAPTER 2: INSTALLATION

NOTE

Trip Coil

DC +

DC -

Output Relay 1 (TRIP)

52a

contact

Coil

DC +

DC -

Output Relay 2 (CLOSE)

52b

contact

898785.cdr

Trip Coil

DC +

DC -

Output Relay 1 (TRIP)

52a

contact

External

jumper

898786.cdr

Coil

DC +

DC -

Output Relay 2 (CLOSE)

52b

contact

External

jumper

NOTE:

To monitor the close coil circuit integrity, use the relay terminals B4 and A4 to connect the Close coil, and provide a jumper between terminals B4 (optional voltage) and B5.

Figure 2-38: Trip and Close circuits with no voltage monitoring

NOTE:

All AUX contacts are shown when the breaker is open.

Figure 2-39: Trip and close circuits with voltage monitoring

2–34 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 69

CHAPTER 2: INSTALLATION ELECTRICAL INSTALLATION

SCADA, PLC, OR PERSONAL COMPUTER

COM

OPTOCOUPLER

DATA

3 Series IED

SHIELD

898738A3.CDR

UP TO 32 350 OR OTHER IEDs, MAXIMUM CABLE LENGTH OF 1200 m (4000 ft.)

LAST DEVICE

(*) TERMINATING IMPEDANCE AT EACH END (typically 120 ohms and 1 nF)

TWISTED PAIR

Z (*)

RS485 +

RS485 -

COMMON

RS485 +

RS485 -

COMMON

IED

RS485 +

IED

RS485 -

COMMON

GROUND THE SHIELD AT THE

SCADA/PLC/COMPUTER ONLY

OR THE SR3 ONLY

DATA

OPTOCOUPLER

Z (*)

Serial communications

Figure 2-40: RS485 wiring diagram

FASTPATH:

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 2–35

One two-wire RS485 port is provided. Up to 32 350 IEDs can be daisy-chained together on a communication channel without exceeding the driver capability. For larger systems, additional serial channels must be added. Commercially available repeaters can also be used to add more than 32 relays on a single channel. Suitable cable should have a characteristic impedance of 120 ohms (for example, Belden #9841) and total wire length should not exceed 1200 meters (4000 ft.). Commercially available repeaters will allow for transmission distances greater than 1200 meters.

Voltage differences between remote ends of the communication link are not uncommon. For this reason, surge protection devices are internally installed across all RS485 terminals. Internally, an isolated power supply with an optocoupled data interface is used to prevent noise coupling.

To ensure that all devices in a daisy-chain are at the same potential, it is imperative that the common terminals of each RS485 port are tied together and grounded only once, at the master or at the 350 . Failure to do so may result in intermittent or failed communications.

The source computer/PLC/SCADA system should have similar transient protection devices installed, either internally or externally. Ground the shield at one point only, as shown in the figure above, to avoid ground loops.

Correct polarity is also essential. The 350 IEDs must be wired with all the positive (+) terminals connected together and all the negative (–) terminals connected together. Each relay must be daisy-chained to the next one. Avoid star or stub connected configurations. The last device at each end of the daisy-chain should be terminated with a 120 ohm ¼ watt resistor in series with a 1 nF capacitor across the positive and negative terminals. Observing these guidelines will ensure a reliable communication system immune to system transients.

Page 70

ELECTRICAL INSTALLATION CHAPTER 2: INSTALLATION

GE MULTILIN

3 SERIES RELAY

IRIG-B(-)

RECEIVER

TO OTHER DEVICES

RG58/59 COAXIAL CABLE

GPS SATELLITE SYSTEM

GPS CONNECTION OPTIONAL

IRIG-B(+)

–

898741A3.CDR

IRIG-B

TIME CODE

GENERATOR

(DC SHIFT OR

AMPLITUDE MODULATED

SIGNAL CAN BE USED)

The uncovered communications cable shield connected to the common terminal should not exceed 1” (2.5 cm) for proper EMC shielding of the communications cable.

IRIG-B

IRIG-B is a standard time code format that allows time stamping of events to be synchronized among connected devices within 1 millisecond. The IRIG time code formats are serial, width-modulated codes which can be either DC level shift or amplitude modulated (AM) form. The type of form is auto-detected by the 350 equipment is available for generating the IRIG-B signal; this equipment may use a GPS satellite system to obtain the time reference so that devices at different geographic locations can also be synchronized.

The uncovered communications cable shield connected to the common terminal should not exceed 1” (2.5 cm) for proper EMC shielding of the communications cable.

Figure 2-41: IRIG-B connection

relay. Third party

2–36 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 71

Grid Solutions

350 Feeder Protection System

Chapter 3: Interfaces

Interfaces

There are two methods of interfacing with the 350 Feeder Protection System.

• Interfacing via the relay keypad and display.

• Interfacing via the EnerVista 3 Series Setup software.

This section provides an overview of the interfacing methods available with the 350 using the relay control panels and EnerVista 3 interface parameters (for example, settings, actual values, etc.), refer to the individual chapters.

Series Setup software. For additional details on

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 3–1

Page 72

FRONT CONTROL PANEL INTERFACE CHAPTER 3: INTERFACES

▽

△

◁▷

▲

▼

ENTER

ESCAPE

RESET

898351A1.cdr

USB

GE Multilin 350 Feeder Protection System

IN SERVICE

TROUBLE

SETPOINT GROUP 1

SETPOINT GROUP 2

TRIP

ALARM

PICKUP

BREAKER OPEN

BREAKER CLOSED

MAINTENANCE

Front control panel interface

Figure 3-1: 350 Feeder Protection System Front Panel - Non-programmable LEDs

3–2 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 73

CHAPTER 3: INTERFACES FRONT CONTROL PANEL INTERFACE

▽

△

◁▷

▲

▼

ENTER

ESCAPE

RESET

898841.cdr

USB

GE Multilin 350 Feeder Protection System

IN SERVICE

TROUBLE

TRIP

ALARM

Figure 3-2: 350 Feeder Protection System Front Panel - Programmable LEDs

Description

The relay front panel provides an interface with a liquid crystal display, LED status indicators, control keys, and a USB program port. The display and status indicators show the relay information automatically. The control keys are used to select the appropriate message for entering setpoints or displaying measured values. The USB program port is also provided for connection with a computer running the EnerVista 3

software.

Setup

Series

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 3–3

Page 74

FRONT CONTROL PANEL INTERFACE CHAPTER 3: INTERFACES

ACTUAL VALUES COMMANDS QUICK SETUP SETPOINTS MAINTENANCE

█

CLOCK

A1 STATUS

CONTACT INPUTS OUTPUT RELAYS

█

ACTUAL VALUES

A1 STATUS A2 METERING A3 RECORDS

█

CONTACT INPUTS

A1 STATUS

OUTPUT RELAYS

CLOCK

█

A1 STATUS

LOGIC ELEM SUMMARY

. . .

2 clicks

▽

△

▶

▼

◁▷

▼

◁▷

Click to end

▼

Back

1 click

Display

The 80-character liquid crystal display (LCD) allows visibility under varied lighting conditions. When the keypad and display are not being used, system information is displayed after a user-defined period of inactivity. Pressing the Menu key during the display of default message returns the display to the last message shown before the default message appeared. Any trip, alarm, or pickup is displayed immediately, automatically overriding the default message.

Working with the

Keypad

The 350 display messages are organized into a Main Menu, pages, and sub-pages. There are four main menus labeled Actual Values, Quick Setup, Setpoints, and Maintenance. Pressing the MENU key followed by the MESSAGE key scrolls through the five Main Menu headers, which appear in sequence as follows:

Figure 3-3: The five Main Menu headers

Pressing the MESSAGE ► key or the ENTER key from these Main Menu pages will display the corresponding menu Page. Use the MESSAGE ▲ and MESSAGE ▼ keys to scroll through the Page headers.

Figure 3-4: Typical paging operation from Main Menu selection

3–4 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 75

CHAPTER 3: INTERFACES FRONT CONTROL PANEL INTERFACE

When the display shows SETPOINTS, pressing the MESSAGE ► key or the ENTER key will display the page headers of programmable parameters (referred to as setpoints in the manual). When the display shows ACTUAL VALUES, pressing the MESSAGE ► key or the ENTER key displays the page headers of measured parameters (referred to as actual values in the manual).

Each page is broken down further into logical sub-pages of messages. The MESSAGE ▲ and MESSAGE ▼ keys are used to navigate through the sub-pages. A summary of the setpoints and actual values pages can be found in the Chapters : Setpoints and Actual Values, respectively.

The ENTER key is dual purpose. It is used to enter the sub-pages and to store altered setpoint values into memory to complete the change. The MESSAGE ► key can also be used to enter sub-pages but not to store altered setpoints.

The ESCAPE key is also dual purpose. It is used to exit the sub-pages and to cancel a setpoint change. The MESSAGE ◄ key can also be used to exit sub-pages and to cancel setpoint changes.

The VALUE keys are used to scroll through the possible choices of an enumerated setpoint. They also decrement and increment numerical setpoints.

The RESET key resets any latched conditions that are not currently active. This includes resetting latched output relays, latched Trip LEDs, breaker operation failure, and trip / close coil failures. The Autoreclose Scheme is also reset with the shot counter being returned to zero and the lockout condition being cleared.

The MESSAGE ▲ and MESSAGE ▼ keys scroll through any active conditions in the relay. Diagnostic messages are displayed indicating the state of protection and monitoring elements that are picked up, operating, or latched.

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 3–5

Page 76

FRONT CONTROL PANEL INTERFACE CHAPTER 3: INTERFACES

NOTE

898866A1.CDR

AND

LED: TRIP

RESET (comand)

TRIP (from any el;ement set tp TRIP)

LED status indicators - Front panel with non-programmable LEDs

• IN SERVICE: Green This LED will be continuously “ON”, when the relay is set to “Ready” under S1 RELAY

SETUP > INSTALLATION > RELAY STATUS

detected.

• TROUBLE: Orange This LED will turn “ON”, when the relay is in the not programmed (Not Ready) state

under S1 RELAY SETUP > INSTALLATION > RELAY STATUS, or upon detection of a major self-test error. The relay will turn back to “IN-SERVICE” if no major self-test error is present.

• SETPOINT GROUP 1, 2: Green These LEDs indicate the group of active protection elements. If setpoint group 1 is lit

green, only the protection elements under group 1 will be active. The protection elements from group 2 will be inactive. The settings for each protection element can be edited and displayed regardless of the active group.

• TRIP: Red This indicator turns on when the relay detects a fault and sends a trip command to

the trip output relay. The LED will reset by initiating a reset command from either the RESET pushbutton Breaker Control, or communications; in all cases after the fault condition has cleared.

, and no major self-test errors have been

NOTE:

3–6 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

• ALARM: Orange This LED will flash upon detection of an alarm condition, with element functions

selected as “alarm”. The LED will automatically turn off if the alarm condition clears. The LED will remain steady “ON”, if the function of the operated protection was selected as "latched alarm".

• PICKUP: Orange This indicator will light ON upon pickup condition generated by any of the relay

features. The indicator will turn off if no pickup condition is detected.

• BREAKER OPEN: Red/Green/Orange/Off – programmable color, default Green When the breaker is open, this indicator will be on continuously.

• BREAKER CLOSED: Red/Green/Orange/Off – programmable color, default Green When the breaker is closed, this indicator will be on continuously.

• MAINTENANCE: Orange This LED may indicate both breaker or relay maintenance depending on the

programmed maintenance elements. The LED will turn on upon operation of a maintenance element.

Refer to M7 Testing for information on testing LED status indicators.

Page 77

CHAPTER 3: INTERFACES FRONT CONTROL PANEL INTERFACE

NOTE

898866A1.CDR

AND

LED: TRIP

RESET (comand)

TRIP (from any el;ement set tp TRIP)

LED status indicators - Front panel with programmable LEDs

• IN SERVICE: Green

This LED will be continuously “ON”, when the relay is set to “Ready” under S1 RELAY

SETUP > INSTALLATION > RELAY STATUS

detected.

• TROUBLE: Orange

This LED will turn “ON”, when the relay is not programmed (Not Ready) state under S1

RELAY SETUP > INSTALLATION > RELAY STATUS

error. The relay will turn back to “IN-SERVICE” if no major self-test error is present.

• TRIP: Red

This indicator turns on when the relay detects a fault and sends a trip command to the trip output relay. The LED will reset by initiating a reset command from either the RESET pushbutton Breaker Control, or communications; in all cases after the fault condition has cleared.

, and no major self-test errors have been

, or upon detection of a major self-test

• ALARM: Orange

This LED will flash upon detection of an alarm condition, with element functions selected as “alarm”. The LED will automatically turn off if the alarm condition clears. The LED will remain steady “ON”, if the function of the operated protection was selected as "latched alarm".

• LED 1: Red - programmable source signal and type

• LED 2: Orange - programmable source signal and type

• LED 3: Orange - programmable source signal and type

• LED 4: Orange - programmable source signal and type

• LED 5: Red/Orange/Green/Off - programmable source signal, type, and color

• LED 6: Red/Orange/Green/Off - programmable source signal, type, and color

• LED 7: Red/Orange/Green/Off - programmable source signal, type, and color

• LED 8: Red/Orange/Green/Off - programmable source signal, type, and color

NOTE:

Refer to M7 Testing for information on testing LED status indicators.

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 3–7

Page 78

FRONT CONTROL PANEL INTERFACE CHAPTER 3: INTERFACES

A4 TARGET MESSAGES

Cause <function> State: Operate

Phase:

▼

A4 TARGET MESSAGES

Ph IOC1 Trip State: Operate

Phase:A

▼

Relay messages

Target messages Target messages are automatically displayed for any active condition on the relay such as

pickups, trips, or alarms. The relay displays the most recent event first, and after 5 seconds will start rolling up the

other target messages until the conditions clear and/or the RESET command is initiated. The Target Messages can be reviewed by pressing either the MESSAGE UP or MESSAGE DOWN key. If a RESET command is not performed but any of the other faceplate pushbuttons is pressed, the display will not show the target messages unless the user navigates to target messages have not been cleared before the user presses a pushbutton different from “RESET”, they will reappear on the screen after the time specified under the

SETPOINTS > S1 RELAY SETUP > FRONT PANEL > MESSAGE TIMEOUT setting, that will start

timing out from the last pressed pushbutton. The following shows the format of a typical Target Message:

Figure 3-5: Typical target message

ACTUAL VALUES > A4 TARGET MESSAGES, where they can be reviewed. If the

CAUTION:

Example of a Phase IOC1 operation - phase A: Phase IOC1 function: Trip

Cause <Function>

The first line contains information of the cause of operation (the name of the operated element), and the element function.

State: Operate

This line from the display shows the state of the element: Pickup, Operated, Alarm.

Phase: A

The last line from the display shows the phase that picked up or operated.

Self-test errors The relay performs self diagnostics at initialization (after power up), and continuously as a

background task to ensure that the hardware and software are functioning correctly. There are two types of self-test warnings indicating either a minor or major problem. Minor problems indicate a problem with the relay that does not compromise protection of the power system. Major errors indicate a problem with the relay which takes it out of service.

Self-Test Warnings may indicate a serious problem with the relay hardware!

Upon detection of a minor problem, the relay will:

• Turn on the "TROUBLE" LED at the same time as the "IN SERVICE" LED is on.

• Display the error on the relay display.

3–8 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 79

CHAPTER 3: INTERFACES FRONT CONTROL PANEL INTERFACE

A4 TARGET MESSAGES

UNIT FAILURE: Contact Factory: Error code:1

• Record the minor self-test error in the Event Recorder. Upon detection of a major problem, the relay will:

• De-energize critical failure relay (Output Relay 7).

• Inhibit operation of all other output relays (1 to 6).

• Turn off the "IN SERVICE" LED; turn on the "TROUBLE" LED.

• Flash the "ALARM" LED.

• Display the cause of major self-test failure.

• Record the major self-test failure in the Event Recorder.

Figure 3-6: Typical Self-test warning

Table 3-1: Minor Self-test Errors

Self-test Error Message

MAINTENANCE ALERT: IRIG-B Failure

MAINTENANCE ALERT: Clock Not Set

MAINTENANCE ALERT: Comm Alert 1, 2, or 3

MAINTENANCE ALERT : Ethernet Link Fail

MAINTENANCE ALERT: High Ethernet Traffic

Latched Target Message?

No A bad IRIG-B input

No Clock time is the

No Communication

No Every 5 seconds*

Description of Problem

signal has been detected.

same as the default time.

error between CPU and Comms board.

error between

and Network.

350

How Often the Test is Performed

Every 5 seconds* Ensure IRIG-B cable is

Every 5 seconds* Set the date and time in

Every 5 seconds* If alert doesn’t self-reset,

Detected Instantaneously

What to do

connected, check cable functionality (i.e. physical damage or perform continuity test), ensure IRIG-B receiver is functioning, and check input signal level (it may be less than specification). If none of these apply, contact the factory.

PRODUCT SETUP.

then contact factory. Otherwise monitor recurrences as errors are detected and self-reset.

Check Ethernet cable and Ethernet connection. Check health of the network. Check status of external routers and switches. Check that IP settings are not 0.0.0.0

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 3–9

Page 80

FRONT CONTROL PANEL INTERFACE CHAPTER 3: INTERFACES

Self-test Error Message

MAINTENANCE ALERT: High Ambient Temperature

MAINTENANCE ALERT: Daughter Error

MAINTENANCE ALERT: Comms Serial Invalid

Latched Target Message?

No The ambient

No The rear

No The internal

Description of Problem

temperature is above 80

Communications daughter board type does not match the order code.

communications board does not match the order code.

How Often the Test is Performed

Every 1 hour Increase ventilation to the

Every 5 seconds* Replace the rear

Every 5 seconds* Contact factory.

What to do

surroundings.

communications daughter board with the correct board.

* Failure is logged after the detection of 5 consecutive failures - that is after 25 seconds

Table 3-2: Major Self-test Errors

Self-test Error Message

UNIT FAILURE: Contact Factory (XXXX)

RELAY NOT READY: Check Settings

Latched Target Message?

Yes This warning is

No PRODUCT SETUP

Description of Problem

caused by a unit hardware failure. Failure code (XXXX) is shown.

INSTALLATION setting indicates that relay is not in a programmed state.

How Often the Test is Performed

Every 5 seconds* Contact the factory and

On power up and whenever the PRODUCT SETUP INSTALLATION setting is altered.

What to do

provide the failure code.

Program all required settings then set the PRODUCT SETUP INSTALLATION setting to "Programmed".

* Failure is logged after the detection of 5 consecutive failures - that is after 25 seconds

Flash messages Flash messages are warning, error, or general information messages displayed in response

to pressing certain keys. The factory default flash message time is 4 seconds.

Figure 3-7: Typical Flash message

SETPOINT STORED

This flash message is displayed in response to the ENTER key while on any setpoint message (see example above). The edited value was stored as entered.

COMMAND EXECUTED

This flash message is displayed in response to executing a command: ON, OFF, YES, NO, etc.

INVALID PASSWORD

This flash message appears upon an attempt to enter an incorrect password, as part of password security.

AR IN PROGRESS

This flash message appears when the Autoreclosure is in progress performing the configured sequence.

3–10 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 81

CHAPTER 3: INTERFACES SOFTWARE SETUP

Software setup

Quick setup - Software interface

• The Quick Setup window allows you to configure important settings from different

screens in the relay by adding them to a common window.

• Quick Setup window options are available for a single device or a file.

• The Quick Setup Window option is accessed from the "Tree" which launches on

clicking.

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 3–11

Page 82

SOFTWARE SETUP CHAPTER 3: INTERFACES

EnerVista 3 Series Setup Software

Although settings can be entered manually using the control panel keys, a PC can be used to download setpoints through the communications port. The EnerVista 3 Series

software is available from GE Multilin to make this as convenient as possible. With

Setup EnerVista 3

• Program and modify settings

• Load and save setting files to and from a disk

• Read actual values

• Monitor status

• Read pre-trip data and event records

• Get help on any topic

• Upgrade the 350 firmware

The EnerVista 3 Series Setup software allows immediate access to all 350 features with easy to use pull down menus in the familiar Windows environment. This section provides the necessary information to install EnerVista 3 and write and edit setting files.

The EnerVista 3 Series Setup software can run without a 350 connected to the computer. In this case, settings may be saved to a file for future use. If a 350 communications are enabled, the 350 addition, measured values, status and trip messages can be displayed with the actual value screens.

Series Setup running, it is possible to:

Series Setup , upgrade the relay firmware,

is connected to a PC and

can be programmed from the setting screens. In

Hardware and

software

requirements

Installing the

EnerVista 3 Series

Setup software

The following requirements must be met for the EnerVista 3 Series Setup software.

• Pentium 4 (Core Duo recommended)

• Windows XP with Service Pack 2 (Service Pack 3 recommended) , Windows 7 (32-bit or 64-bit), Windows 8.1 (32-bit or 64-bit), Windows 10 (32-bit or 64-bit)

• 1 GB of RAM (2 GB recommended)

• 500 MB free hard drive space (1 GB recommended)

• 1024 x 768 display (1280 x 800 recommended)

The EnerVista 3 Series Setup software can be installed from either the GE EnerVista CD or the GE Multilin website at

After ensuring the minimum requirements indicated earlier, use the following procedure to install the EnerVista 3

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 nocharge EnerVista software on the local PC.

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

4. Click the IED Setup section of the LaunchPad toolbar.

http://www.gegridsolutions.com/multilin

Series Setup software from the enclosed GE EnerVista CD.

3–12 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 83

CHAPTER 3: INTERFACES SOFTWARE SETUP

5. In the EnerVista Launchpad window, click the Add Product button and select the

350 Feeder Protection System 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 350 .

6. EnerVista Launchpad will obtain the latest installation software from the Web or CD

and automatically start the installation process. A status window with a progress bar will be shown during the downloading process.

7. Select the complete path, including the new directory name, where the EnerVista

3 Series Setup software will be installed.

8. Click on Next to begin the installation. The files will be installed in the directory

indicated, the USB driver will be loaded into the computer, and the installation program will automatically create icons and add EnerVista 3 Series Setup software to the Windows start menu.

9. The 350 device will be added to the list of installed IEDs in the EnerVista Launchpad

window, as shown below.

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 3–13

Page 84

SOFTWARE SETUP CHAPTER 3: INTERFACES

If you are going to communicate from your computer to the 350 Relay using the USB port:

10. Plug the USB cable into the USB port on the 350 Relay then into the USB port on your computer.

11. Launch EnerVista 3 Series Setup from LaunchPad.

12. In EnerVista > Device Setup:

13. Select USB as the Interface type.

14. Select 350 Relay as the USB device.

3–14 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

Page 85

CHAPTER 3: INTERFACES SOFTWARE SETUP

Upgrading the

software

Connecting EnerVista 3 Series Setup to the relay

Configuring serial

communications

The latest EnerVista software and firmware can be downloaded from:

https://www.gegridsolutions.com/

After upgrading, check the version number under Help > About. If the new version does not display, try uninstalling the software and reinstalling the new versions.

Before starting, verify that the cable is properly connected to either the USB port on the front panel of the device (for USB communications) or to the RS485 terminals on the back of the device (for RS485 communications). This example demonstrates an USB connection. For RS485 communications, the GE Multilin F485 converter will be required. Refer to the F485 manual for additional details. To configure the relay for Ethernet communications, see Configuring Ethernet Communications below.

1. Install and start the latest version of the EnerVista 3 Series Setup software (available

from the GE Multilin web site). See the previous section for the installation procedure.

2. Click on the Device Setup button to open the Device Setup window and click the Add

Site button to define a new site.

3. Enter the desired site name in the "Site Name" field. If desired, a short description of

the site can also be entered. In this example, we will use “Substation 1” as the site name.

4. The new site will appear in the upper-left list in the EnerVista 3 Series Setup window.

5. Click the Add Device button to define the new device.

6. Enter the desired name in the "Device Name" field and a description (optional) of the

device.

7. Select “Serial” from the Interface drop-down list.

350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL 3–15

Page 86

SOFTWARE SETUP CHAPTER 3: INTERFACES

8. Click the Read Order Code button to connect to the 350 device and upload the order code.

9. Click OK when the relay order code has been received. The new device will be added to the Site List window (or Online window) located in the top left corner of the main EnerVista 3 Series Setup window.

The 350 Site Device has now been configured for USB communications. Proceed to Connecting to the Relay below, to begin communications.

Using the Quick

Connect feature

The Quick Connect button can be used to establish a fast connection through the front panel USB port of a 350 relay, or through the Ethernet port. The following window will appear when the QuickConnect button is pressed:

As indicated by the window, the "Quick Connect" feature can quickly connect the EnerVista

Series Setup software to a 350 front port if the USB is selected in the interface drop-down

3 list. Select "SR3 Relay" and press the Connect button. Ethernet can also be used as the interface for Quick Connect as shown above.

When connected, a new Site called “Quick Connect” will appear in the Site List window.

3–16 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

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CHAPTER 3: INTERFACES SOFTWARE SETUP

NOTE

Configuring Ethernet

communications

NOTE:

The 350 Site Device has now been configured via the Quick Connect feature for either USB or Ethernet communications. Proceed to Connecting to the Relay below, to begin communications.

Before starting, verify that the Ethernet cable is properly connected to the RJ-45 Ethernet port.

350 supports a maximum of 3 TCP/IP sessions.

1. Install and start the latest version of the EnerVista 3 Series Setup Setup software

(available from the GE EnerVista CD). See the previous section for the installation procedure.

2. Click on the Device Setup button to open the Device Setup window and click the Add

Site button to define a new site.

3. Enter the desired site name in the "Site Name" field. If desired, a short description of

the site can also be entered. In this example, we will use “Substation 1” as the site name.

4. The new site will appear in the upper-left list.

5. Click the Add Device button to define the new device.

6. Enter the desired name in the "Device Name" field, and a description (optional).

7. Select “Ethernet” from the Interface drop-down list. This will display a number of

interface parameters that must be entered for proper Ethernet functionality.

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Connecting to the

relay

8. Enter the IP address, slave address, and Modbus port values assigned to the 350 relay (from the S1 RELAY SETUP > COMMUNICATIONS > ETHERNET menu).

9. Click the Read Order Code button to connect to the 350 and upload the order code. If a communications error occurs, ensure that the Ethernet communication values correspond to the relay setting values.

10. Click OK when the relay order code has been received. The new device will be added to the Site List window (or Online window) located in the top left corner of the main EnerVista 3 Series Setup window.

The 350 Site Device has now been configured for Ethernet communications. Proceed to the following section to begin communications.

Now that the communications parameters have been properly configured, the user can easily communicate with the relay.

1. Expand the Site list by double clicking on the site name or clicking on the «+» box to list the available devices for the given site.

2. Desired device trees can be expanded by clicking the «+» box. The following list of headers is shown for each device:

Device Definition Actual Values Quick Setup Setpoints Maintenance.

3. Expand the SETTINGS > RELAY SETUP list item and double click on Front Panel to open the Front Panel settings window as shown:

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4. The Front Panel settings window opens with a corresponding status indicator on the

lower left of the EnerVista 3 Series Setup window.

5. If the status indicator is red, verify that the serial, USB, or Ethernet cable is properly

connected to the relay, and that the relay has been properly configured for communications (steps described earlier).

The Front Panel settings can now be edited, printed, or changed. Other setpoint and command windows can be displayed and edited in a similar manner. "Actual Values" windows are also available for display. These windows can be arranged, and resized at will.

Working with setpoints and setpoint files

Engaging a device The EnerVista 3 Series Setup software may be used in on-line mode (relay connected) to

directly communicate with a relay. Communicating relays are organized and grouped by communication interfaces and into sites. Sites may contain any number of relays selected from the product series.

Entering setpoints The System Setup page will be used as an example to illustrate the entering of setpoints. In

this example, we will be changing the voltage sensing setpoints.

1. Establish communications with the relay.

2. Select the Setpoint > System Setup > Voltage Sensing menu item.

3. Select the Bus VT Secondary setpoint by clicking anywhere in the parameter box. This

will display three arrows: two to increment/decrement the value and another to launch the numerical keypad.

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4. Clicking the arrow at the end of the box displays a numerical keypad interface that allows the user to enter a value within the setpoint range displayed near the top of the keypad: Click = to exit from the keypad and keep the new value. Click on X to exit from the keypad and retain the old value.

5. For setpoints requiring non-numerical pre-set values (e.g. 3-Phase voltage connection below), clicking anywhere within the setpoint value box displays a dropdown selection menu arrow. Select the desired value from this list.

6. For setpoints requiring an alphanumeric text string (e.g. "relay name"), the value may be entered directly within the setpoint value box.

7. In the Setpoint > System Setup > Voltage Sensing dialog box, click on Save to save the values into the 350 . Click YES to accept any changes and exit the window. Click

Restore to retain previous values. Click Default to restore Default values.

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Setting

programmable LEDs

Front panels with programmable LEDs have eight LEDs that are off by default, and must be set to a source signal and type. Four of these LEDs can also be set to different colors.

1. Establish communications with the relay.

2. Select the Setpoint > S1 Relay Setup > Front Panel menu item.

3. Select an LED Source setpoint by clicking anywhere in the parameter box beside an

LED Source label. This opens a Quick Navigation window.

4. Select a Type for the LED (Latched or Self-Reset), and a Color if applicable.

5. Repeat this process for all programmable LED Source, Type, and Color parameters.

6. In the Setpoint > S1 Relay Setup > Front Panel dialog box, click Save to save the

values into the 350 . Click YES to accept any changes. Click Restore to retain previous values. Click Default to restore Default values (all LEDs Off and colors Orange).

7. Click View Layout and Print to create a printable label for the front panel showing the

programmable LED settings. Edit LED names manually by clicking the LED label and entering up to 20 characters. (Manual edits can be printed, but are not saved.)

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8. Click Print to print a copy of the customized front panel label.

File support Opening any EnerVista 3 Series Setup file will automatically launch the application or

provide focus to the already opened application. If the file is a settings file (has a ‘SR3’ extension) which had been removed from the Settings List tree menu, it will be added back to the Settings List tree.

New files will be automatically added to the tree.

Using setpoint files The EnerVista 3 Series Setup software interface supports three ways of handling changes

to relay settings:

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

• Directly modifying relay settings while connected to a communicating relay, then saving the settings when complete.

• Creating/editing settings files while connected to a communicating relay, then saving them to the relay when complete.

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:

• Device Definition

•Relay Setup

•System Setup

•Protection

• Control

• Inputs/Outputs

Factory default values are supplied and can be restored after any changes. The EnerVista 3 Series Setup displays relay setpoints with the same hierarchy as the front

panel display.

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Downloading and

saving setpoint files

Adding setpoint files

to the environment

Back up a copy of the in-service settings for each commissioned 350 unit, so as to revert to the commissioned settings after inadvertent, unauthorized, or temporary setting changes are made, after the settings default due to firmware upgrade, or when the unit has to be replaced. This section describes how to backup settings to a file and how to use that file to restore settings to the original relay or to a replacement relay

Setpoints must be saved to a file on the local PC before performing any firmware upgrades. Saving setpoints is also highly recommended before making any setpoint changes or creating new setpoint files.

The setpoint files in the EnerVista 3 Series Setup window are accessed in the Files Window. Use the following procedure to download and save setpoint files to a local PC.

1. Ensure that the site and corresponding device(s) have been properly defined and

configured as shown in Connecting EnerVista 3 Series Setup to the Relay, above.

2. Select the desired device from the site list.

3. Select the Online > Read Device Settings from Device menu item, or right-click on the

device and select Read Device Settings to obtain settings information from the device.

4. After a few seconds of data retrieval, the software will request the name and

destination path of the setpoint file. The corresponding file extension will be automatically assigned. Press Receive to complete the process. A new entry will be added to the tree, in the File pane, showing path and file name for the setpoint file.

The EnerVista 3 Series Setup software provides the capability to review and manage a large group of setpoint files. Use the following procedure to add an existing file to the list.

1. In the files pane, right-click on Files and select the Add Existing Setting File item as

shown:

2. The Open dialog box will appear, prompting the user to select a previously saved

setpoint file. As for any other MS Windows® application, browse for the file to be added then click Open. The new file and complete path will be added to the file list .

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NOTE

Creating a new

setpoint file

The EnerVista 3 Series Setup software allows the user to create new setpoint files independent of a connected device. These can be uploaded to a relay at a later date. The following procedure illustrates how to create new setpoint files.

1. In the File pane, right click on File and select the New Settings File item. The following box will appear, allowing for the configuration of the setpoint file for the correct firmware version. It is important to define the correct firmware version to ensure that setpoints not available in a particular version are not downloaded into the relay.

NOTE:

Discontinued order codes may be included to maintain back-compatibility of setpoint files. For current order codes, refer to the GE Multilin website at http://

www.gegridsolutions.com/multilin.

NOTE:

Refer to the 3 Series Retrofit Instruction Manual for instructions on converting existing Multilin MIF II or MIV II setpoint files.

2. Select the Firmware Version, and Order Code options for the new setpoint file.

3. For future reference, enter some useful information in the Description box to facilitate the identification of the device and the purpose of the file.

4. To select a file name and path for the new file, click the button beside the File Name box.

5. Select the file name and path to store the file, or select any displayed file name to replace an existing file. All 350 setpoint files should have the extension ‘SR3’ (for example, ‘feeder1.SR3’).

6. Click OK to complete the process. Once this step is completed, the new file, with a complete path, will be added to the EnerVista 3 Series Setup software environment.

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Upgrading setpoint

files to a new revision

It is often necessary to upgrade the revision for a previously saved setpoint file after the 350 firmware has been upgraded. This is illustrated in the following procedure:

1. Establish communications with the 350 relay.

2. Select the Maintenance > M1 Relay Info menu item and record the Firmware

Revision.

3. Load the setpoint file to be upgraded into the EnerVista 3 Series Setup environment as

described in the section, Adding Setpoints Files to the Environment.

4. In the File panel, select the saved setpoint file.

5. From the main window menu bar, select the Offline > Edit Settings File Properties

menu item and note the File Version of the setpoint file. If this version is different from the Firmware Revision noted in step 2, select a New File Version that matches the Firmware Revision from the pull-down menu.

6. For example, if the firmware revision is SR350_V140.sfd (Firmware Revision 1.40) and

the current setpoint file revision is 1.20, change the setpoint file revision to “1.4x”.

NOTE:

Discontinued order codes may be included to maintain back-compatibility of setpoint files. For current order codes, refer to the GE Multilin website at http://

www.gegridsolutions.com/multilin.

7. Enter any special comments about the setpoint file in the "Description" field.

8. Select the desired firmware version from the "New File Version" field.

9. When complete, click OK to convert the setpoint file to the desired revision. See

Loading Setpoints from a File below, for instructions on loading this setpoint file into the 350 .

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Printing setpoints and

actual values

The EnerVista 3 Series Setup software allows the user to print partial or complete lists of setpoints and actual values. Use the following procedure to print a list of setpoints:

1. Select a previously saved setpoints file in the File pane or establish communications with a 350 device.

2. From the main window, select the Offline > Export Settings File menu item.

3. The Print/Export Options dialog box will appear. Select Settings in the upper section and select either Include All Features (for a complete list) or Include Only Enabled Features (for a list of only those features which are currently used) in the filtering section and click OK.

4. The process for Offline > Print Preview Settings File is identical to the steps above.

5. Setpoint lists can be printed in the same manner by right clicking on the desired file (in the file list) or device (in the device list) and selecting the Print Device Information or

Print Settings File options.

Printing actual values

from a connected

device

3–26 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

A complete list of actual values can also be printed from a connected device with the following procedure:

1. Establish communications with the desired 350 device.

2. From the main window, select the Online > Print Device Information menu item

3. The Print/Export Options dialog box will appear. Select Actual Values in the upper section and select either Include All Features (for a complete list) or Include Only Enabled Features (for a list of only those features which are currently used) in the filtering section and click OK.

Actual values lists can be printed in the same manner by right clicking on the desired device (in the device list) and selecting the Print Device Information option

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Loading setpoints

from a file

CAUTION:

An error message will occur when attempting to download a setpoint file with a revision number that does not match the relay firmware. If the firmware has been upgraded since saving the setpoint file, see for instructions on changing the revision number of a setpoint file.

The following procedure illustrates how to load setpoints from a file. Before loading a setpoints file, it must first be added to the EnerVista 3

Series Setup environment as

described in the section, Adding Setpoints Files to the Environment.

1. Select the previously saved setpoints file from the File pane of the EnerVista 3 Series

Setup software main window.

2. Select the Offline > Edit Settings File Properties menu item and verify that the

corresponding file is fully compatible with the hardware and firmware version of the target relay. If the versions are not identical, see Upgrading Setpoint Files to a New Revision for details on changing the setpoints file version.

3. Right-click on the selected file and select the Write Settings File to Device item.

4. Select the target relay from the list of devices shown and click Send. If there is an

incompatibility, an error of the following type will occur:

Uninstalling files and

clearing data

If there are no incompatibilities between the target device and the settings file, the data will be transferred to the relay. An indication of the percentage completed will be shown in the bottom of the main window.

The unit can be decommissioned by turning off the power to the unit and disconnecting the wires to it. Files can be cleared before uninstalling the EnerVista software or

device, for example to comply with data security regulations. On the computer,

350 settings files can be identified by the .sr3 extension.

To clear the current settings file do the following:

1. Create a default settings file.

2. Write the default settings file to the relay.

3. Delete all other files with the .sr3 extension.

4. Delete any other data files , which can be in standard formats, such as COMTRADE or

.csv.

You cannot directly erase the flash memory, but all records and settings in that memory can be deleted. Do this using these commands:

ACTUAL VALUES > RECORDS

• EVENTS RECORDS > CLEAR

• TRANSIENT RECORDS > CLEAR

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NOTE

SR350_200.SFD

Firmware Rev #

Upgrading relay firmware

To upgrade the 350 firmware, follow the procedures listed in this section. Upon successful completion of this procedure, the 350 will have new firmware installed with the factory default setpoints.The latest firmware files are available from the GE Multilin website at

http://www.GEgridsolutions.com/multilin.

NOTE:

EnerVista 3 Series Setup software prevents incompatible firmware from being loaded into a 350 relay.

NOTE:

Loading new relay

firmware

Before upgrading firmware, it is very important to save the current 350 settings to a file on your PC. After the firmware has been upgraded, it will be necessary to load this file back into the 350 . Refer to Downloading and Saving Setpoints Files for details on saving relay setpoints to a file.

Loading new firmware into the 350 flash memory is accomplished as follows:

1. Connect the relay to the local PC and save the setpoints to a file as shown in Downloading and Saving Setpoints Files.

2. Select the Maintenance > Update Firmware menu item.

3. The EnerVista 3 Series Setup software will request the new firmware file. Locate the folder that contains the firmware files to load into the 350 . The firmware filename has the following format:

4. EnerVista 3 Series Setup software now prepares the 350 to receive the new firmware file. The 350 front panel will momentarily display "BOOT PROGRAM Waiting for Message,” indicating that it is in upload mode.

5. While the file is being loaded into the 350 , a status box appears showing how much of the new firmware file has been transferred and the upgrade status. The entire transfer process takes approximately 10 minutes.

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6. The EnerVista 3 Series Setup software will notify the user when the 350 has finished

loading the file. Carefully read any displayed messages and click OK to return the main screen. Cycling power to the relay is recommended after a firmware upgrade.

After successfully updating the 350 firmware, the relay will not be in service and will require setpoint programming. To communicate with the relay, the communication settings may have to be manually reprogrammed.

When communications is established, the saved setpoints must be reloaded back into the relay. See Loading Setpoints from a File for details.

Modbus addresses assigned to firmware modules, features, settings, and corresponding data items (i.e. default values, min/max 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.

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Advanced EnerVista 3 Series Setup features

Flexcurve editor The FlexCurve Editor is designed to allow the user to graphically view and edit the

FlexCurve. The Flexcurve Editor screen is shown below:

• The Operate Curves are displayed, which can be edited by dragging the tips of the curves

• A Base curve can be plotted for reference, to customize the operating curve. The Blue colored curve in the picture (in both curves) is a reference curve. It can be Extremely Inverse, Definite Time, etc.

• The Trip Times in the tables and curves work interactively i.e., changing the table value will affect the curve shape and vice versa.

3–30 350 FEEDER PROTECTION SYSTEM – INSTRUCTION MANUAL

GE 350-A9, 350-AD, 350-AA, 350-AE, 350-AF Instruction Manual

Feeder Protection System

Table of Contents

Overview

Introduction

Description of the 350 Feeder Protection System

350 order codes

Specifications

Password security

Protection

Metering

Data capture

Control

Monitoring

Inputs

Outputs

Power supply

Communications

Testing and certification

Physical

Environmental

Mechanical installation

Installation

Dimensions

Product identification

Mounting

Drawout unit withdrawal and insertion

IP20 Cover (optional)

Arc flash sensors

Electrical installation

Typical wiring diagrams

350 Terminal identification

Wire range

Phase sequence and transformer polarity

Current inputs

Ground and sensitive ground CT inputs

Zero sequence CT installation

Voltage inputs

Control power

Contact inputs

Trip and Close output relays

Serial communications

IRIG-B

Interfaces

Front control panel interface

Description

Display

LED status indicators - Front panel with non-programmable LEDs

LED status indicators - Front panel with programmable LEDs

Relay messages

Software setup

Quick setup - Software interface

EnerVista 3 Series Setup Software

Connecting EnerVista 3 Series Setup to the relay

Working with setpoints and setpoint files

Upgrading relay firmware

Advanced EnerVista 3 Series Setup features