Overview of Digital Relays

ISO Training

John S. Levine, P.E.

Levine Lectronics & Lectric [email protected] www.L-3.com

1

ISO Training July 22, 2008 Outline

• • •

Introduction Overview of Digital Relays

• • •

Tools

• • •

Enervista Launchpad PowerPoint presentations at GE Digital Relays

• • • •

Protection Basics SR489 GE Multilin G30 Training Post Glover NGR Training ANSI Symbols handout Conversion of Electro-Mechanical to Electronic sheet GE Multilin Training CD’s 2

Trends

• • • •

75% of Installed Base of Relays are Electromechanical 90% of New Relays Purchased are Digital/Electronic Lingering Issue of “Putting All Eggs In One Basket”

–

“No Backup”

– – –

“Like to See Disk Move” Solve with Backup (such as DIAC as backup to SR760 or F60) Gain Excellent Accuracy and No Setting Drift Manufacturers have Created Relay Families, thus reducing maintenance, O&M costs and training.

3

Microprocessor-Relay Benefits

•

Multi-Function Protection Cost Effectiveness

•

Configurable/Programmable Logic

–

User Configurable Time Current Curves

•

Self Testing of Relay’s Algorithms with Alarm Contact

–

Reduce Periodic Testing

» »

Every 1-2 years for Electromechanical Every 5-10 years for Digital (or More!)

•

Improved System Data

– –

Fault Location & Reporting Internal Operation Data

– –

Breaker Health Monitoring Sequence of Event Reporting - Waveform Capturing - Metering - Demand Interval Records 4

Microprocessor-Relay Benefits

•

Flexible Settings

–

Multiple Setting Levels

•

Communication Capabilities

– – –

Local via Keypad Remote via Computer and Modem Networks can be created

•

Reduced Panel Space & Wiring

– – –

Compact Packaging Tested at Factory Eliminate Component Panel Metering 5

Digital Relays - Areas Of Use

• • • • • • • • •

Distribution Feeder Protection Reclosing Down Conductor Detection Breaker Failure Protection Generator Protection Transmission Line Protection Transformer Protection Bus Protection Motor Protection 6

OLD NEW 7

Programmability

•

Digital Relays Have:

– – –

Programmable Inputs Programmable Outputs (ALARM & TRIP) Programmable Logic

»

Boolean Logic - AND, OR, NOT Logic

–

Programmable Time Current Curves 8

Waveform Capturing

Including Bar Plotting of Unit Operation 9

Metering

• •

0.25 - 5% Accuracy on I & V Typical Values

• • • • • •

Current Voltage Watts, Vars, PF Frequency kWh, kVarh Phase Angles

• • • • •

Min & Max Values with Date & Time Stamp Harmonic Values of I Symmetrical Components Operation Counters Breaker Position

• •

Can Be Accessed Locally or Remotely Some Relays Have Analog Outputs Proportional to Metering Values (i.e. 0-1mA) 10

Metering

11

Other Monitoring

• • •

Breaker Health Monitoring

– –

Cumulative I 2 T or IT Activate Alarm At Set Level Demand Interval Reporting

– –

15, 30, 60 Minute Intervals over Several Days I, Watts, Vars, VA, PF Peak Values Recorded

–

Date & Time Stamped

• •

Trip & Close Coil Monitor Fault Location & Fault Reporting 12

Sequence Of Events Recording

•

Events Stored with Date & Time:

– – – – – – –

Alarms Contact Operations Logins & Logouts Waveform Captures Remote Operations Resets Setting Changes

•

Last 100-1000 Events Stored 13

Settings

• • • • • • •

Easier Than Electromechanical/Static Flexible settings Relays Have Multiple Setting Groups

–

Can be Switched with Input Contacts or Remotely Settings Are Stored in Files and Down Loaded to Relay with PC Easy to Copy Existing Setting Files and Modify Accurate Implementation of Settings

– –

No Overtravel No Large Drifts in Set Points Selection of Reset Times

–

Fast (Digital) or Slow (Electromechanical) 14

Local Communications

• • • • •

Thru Keypad, Up, Down Arrows, Enter/Select Keys or RS232 Port on Relay Local LED Display Reset Key/Button LED Targets Password Protection Phase TOC1 OP Phase A Phase B Phase C Alarm 87 UP DN ENTER 15

Communications

16

Remote Communications

• • • •

Thru Rear RS232 or RS485 Port Using Standard Modem Software or Relay Manufacturer’s Communication Software Password Protection 10Mbps Ethernet Connections - Wire or Fiber Multiple Protocol Support (DNP3.0, Modbus RTU, Devicenet, Profibus, and IEC 61850) Modem DSL or Telephone Modem RELAY 17

Substation Communications - LAN & WAN

18

Communications

19

Memory Map Example

Group Current Address 0300 0301 0302 030D 030E 030F Description Phase A Current Phase B Current Phase C Current Phase A Differential Phase B Differential Phase C Differential

20

Available Control by Digital Relays

via Communications & Protocols

• • • • •

Reset Data

–

Min/Max, Demand, etc.

Reset Targets Operate Output Contacts Trip & Close Trigger Waveform Capture

• • • •

Set Date & Time Force Input Contact Operation Block Relay Functions Perform Setting Changes 21

Maintenance Benefits

• • • • • • •

Self-Test Capabilities Remote Communications Easy Setting Changes One Model Could Be Used for Several Applications No Setting Drift of Digital Relay Reduced Wiring Flash Memory

–

Upgradeable Firmware 22

Today’s Feeder and Transformer Digital Relays

23

DIAC,DIFC,DSFC Single Phase Overcurrent Protection

• • • • • • • • •

Digital Overcurrent Relay Platform w/ True RMS Overcurrent Measurement (50/51) Replace IAC, IFC and SFC relays. . .

– – –

Self Powered (no DC Battery Required) Same case size, no metal modifications Simply add surge ground lead User Selection of 16 curve characteristics

–

Exact Duplication of IAC51, IAC53 & IAC77 Characteristics Instantaneous Overcurrent Delay Setting Reset Characteristic Selection (Fast or E/M) Draw-out Case with Test Facilities Retrofit existing IAC, IFC and SFC Cases Very Low Burden (1.8VA) No Communications 24

SR760 - Feeder Protection

• • • • • • • • • • • • • • • • • • •

16 Samples/Cycle 3 Phase & Ground Overcurrent Protection Programmable Time Current Curves Over/Under Voltage Over/Under Frequency Synch Check 4 Shot Reclosing Fault Location 4 Setting Groups Analog Outputs/Input (8/1) Metering I, V, W, Var, VA, PF, Hz, Wh, Varh Waveform Capturing RS485 Communications DNP3.0 and Modbus RTU Protocols Flash Memory for Upgrades Drawout Construction Programmable Display Simulation Test Mode IRIG-B Time Sync 25

SR489 Generator Management Relay

Product Overview

•

Ideal Protection for Induction and Synchronous Generators at 25, 50 and 60Hz

•

Complete Generator Protection including:

» » »

Generator Stator Differential 2 Zone Distance Backup 100% Stator Ground

• • •

High speed sampling, 12 samples per cycle Drawout Case Installation Powerful Fault Recording: Waveform, Sequence of Events

• • •

Ethernet and Serial Communications EnerVista Suite of Software supported Metering of all important parameters 26

SR489 Protection Functions

Protection Functions Include: • Generator Stator Differential • Backup Distance Protection • 100% Stator Ground • Generator Unbalance • Loss of Excitation • Accidental Energization • Breaker Fail • Phase Overcurrent – Voltage Restraint • Neutral Inst. / Timed Overcurrent • Neg. Sequence Overcurrent • Under / Over Voltage • Under / Over Frequency • Generator Thermal Model • RTD Temperature • Overexcitation – Volts/Hertz

27

SR745 - Transformer Protection

• • • • • • • • • • • • • • • • • • • •

64 Samples/Cycle 3 Phase Differential Protection 3 Phase & Ground Overcurrent per Winding Adaptive Time Overcurrent Programmable Time Current Curves Loss of Life Monitoring (Opt.) 4 Setting Groups Harmonic Analysis (up to 25st) Angle & Zero Sequence Compensation Analog Outputs/Input (Opt.) 2 & 3 Winding Models Configurable Logic Waveform Capturing & Playback Simulation Test Mode Flash Memory for Upgrades RS485 Communications Modbus RTU and DNP3.0 Protocols Programmable Display Dynamic CT Ratio Correction IRIG-B Time Sync Transformer Management Relay SR745 28

The UR Family - One Common Architecture

TRANSMISSION

•

L60 (Transmission Line: Phase Comparison)

•

L90 (Transmission Line: Current Differential)

•

D30, D60, abd D90 (Transmission Line: Distance)

•

B30 and B90 (Busbar: 6 to 24 Feeder) DISTRIBUTION

•

F35 (Feeder: Multiple Feeders - Basic Protection)

•

F60 (Feeder: Comprehensive w Hi-Z)

•

T60 (Transformer: Comprehensive)

•

C30 (Control IED)

•

C60 (Breaker Management IED) GENERATION / MOTOR

•

G30 and G60 (Generator: Comprehensive)

•

T60 and T35 (Transformer: Basic up to 6 Windings)

•

B30 and B90 (Busbar: Comprehensive up to 24 Feeders)

•

M60 (Motor)

“The Engine for Substation / Plant Automation”

29

Modular Hardware Family

30

Modules

Physical Realization

High-Speed Data Bus 19’’ Chassis (4RU high) or Vertical Unit Modular HMI (Hinged & Removeable) 31

‘Upgradeability’/Serviceability ‘Plug n Play’

CPU Automatically Recognizes New Hardware upon Initialization Easy Module Draw-out Module Keying Field Wiring Undisturbed CT Shorting ‘Clips’ 34

Example: Busbar with 5 Feeders

CT1 50/ 51 W 81 79 CT2 W 51 27P 50/ 51 W 81 79 CT3 VT1 50/ 51 W 81 79 CT4 50/ 51 W 81 79 CT5 50/ 51 W 81 79 35

Example: Inputs in to UR Relay

CT4 CT2 CT1 CT5 CT3 VT1 36

Example: UR Relay using Sources

Physical 3-phase I &V Inputs VT1 CT1 CT2 CT3 CT4 CT5 Universal Relay CT1 VT1 CT2 VT1 CT3 VT1 CT4 VT1 CT5 VT1 CT1..CT5

VT1



I I Source #1 V

50/51 

I I Source #2 V

50/51 

I I Source #3

50/51

I



I I Source #4

50/51

V



I I Source #5

50/51

V



I I Source #6 V

50-Inst, 51-Time, 81-Freq, 79- Reclose 51 81 81 81 81 81 27P W W W W W W 79 79 79 79 79

37

F60

Feeder Protection • • • • • • • • • • • • • • • • • • • • • • • • • • • • •

Single Feeder Protection with Bus Voltage

Phase, Neutral & Ground Time Overcurrent (51P, 51N, 51G) Phase, Neutral & Ground Inst.Overcurrent (50P, 50N, 50G) Negative Sequence Time Overcurrent (51_2) Negative Sequence Inst.Overcurrent (50_2) Fast or EM Reset Characteristic for TOC Elements Phase, Neutral and Negative Sequence Directional Control Phase Undervoltage & Overvoltage Negative Sequence Overvoltage Underfrequency (6 elements) Overfrequency 4 Shot Autoreclosing with Sequence Coordination VT Fuse Failure Programmable Fast & Slow Operations Breaker Failure (50BF) Synchrocheck (25) Cold Load Pickup Breaker Arcing Current (I2t) Data Logger & Fault Location Transducer I/O FlexLogic with gates and timers Programmable LED Panels Metering Harmonic Metering (up to 25 th ) Oscillography Event Recorder & Fault Records Demand Recording DNP, Modbus RTU & UCA Protocols 8 Setting Groups Down Conductor Detection (Optional)

38

F35

Multiple Feeder Protection • • • • • • • • • • • • • • • • • • •

5 Feeder Protection with Bus Voltage 6 Feeder Protection w/o Bus Voltage

Programmable LED Panels (6) Phase TOC elements (12) Phase IOC elements (6) Neutral TOC elements (12) Neutral IOC elements (6) Ground TOC elements (12) Ground IOC elements (1) Phase Undervoltage element (6) (6) Underfrequency elements Autoreclosing elements FlexLogic with gates and timers Transducer I/O Data Logger Metering Oscillography Event Recorder Demand Recording DNP, Modbus RTU & UCA Protocols 8 Setting Groups

39

LED Programmability

S T G IN E

G O 1 G O 2 G O 3 G O 4 G O 5 G O 6 G O 7 G O 8

B E R 1

O E K R N R A D C O D T IP B A A

B E K 2

O E B D C O D E O B K

F E 2

R A R N R A R O D T IP A A IC P B D P O E O K T

STATUS

IN SERVICE TROUBLE TEST MODE TRIP ALA RM PICKUP

EV ENT CAUSE

VOLTA GE CURRENT FREQUENCY OTHER PHASE A PHASE B PHASE C NEUTRAL/GROUND RESET USER 1 USER 2 USER 3

F35 MULTIPLE FEEDER MANAGEMENT RELAY

ALA RM

FEEDER 2

BREA KER OPEN BREA KER CLOSED TRIP ALA RM PICKUP AR ENA BLED AR IN PROGRESS AR LOCKOUT

FEEDER 3

BREA KER OPEN BREA KER CLOSED TRIP ALA RM PICKUP AR ENA BLED AR IN PROGRESS AR LOCKOUT

FEEDER 4

BREA KER OPEN BREA KER CLOSED TRIP ALA RM PICKUP AR ENA BLED AR IN PROGRESS AR LOCKOUT

FEEDER 5

BREA KER OPEN BREA KER CLOSED TRIP ALA RM PICKUP AR ENA BLED AR IN PROGRESS AR LOCKOUT

MENU HELP ESCAPE ENTER M ESS AGE VALUE 7 4 1 0 2 .

8 5 9 6 3 +/ -

832739A1.CDR

40

T60

Transformer Protection • • • • • • • • • • • • • • • • • • • • • Up to 4 Restraint Inputs •

2 & 3 Restraint with Three Phase Voltage Inputs

•

4 Restraint without Voltage Inputs

Dual Slope Percent Differential Protection (87T) •

Harmonic Inhibit Feature

•

Overexitation Inhibit Feature

Instantaneous Differential Element (50/87) Overcurrent Protection Per Winding (50/51) •

Phase, Neutral & Ground Time Overcurrent

• •

Phase, Neutral & Ground Inst.Overcurrent

Fast or EM Reset Characteristic for TOC Elements

Phase Undervoltage Phase Overvoltage Phase & Neutral Directional OC Volts/Hz Restricted Ground Fault RTD and dcmA Inputs Available Underfrequency (6 elements) Data Logger FlexLogic with gates and timers Programmable LED Panels Metering per Winding (I, V, W, Var, VA, PF) Harmonic Metering (up to 25 th ) Differential and Restraint Currents Oscillography & Event Recorder Demand Recording DNP, Modbus RTU & UCA Protocols 8 Setting Groups

41

Option 1

T60 - Transformer Protection F60 - Main Feeder Protection F35 - Backup Feeder Protection

UR Applications

42

UR Applications Option 2

T60 - Transformer Protection F35 - Main Feeder Protection F35 - Backup Feeder Protection 43

Tools

44

Free PC Software and Firmware

• • • • • • •

Windows based Access all:

– – – –

Actual Values Setpoints Status Event records Oscillography Graphical trending Setpoint programming Setpoint files Download updated firmware to Flash memory 45

46

47

Enervista Launchpad:

http://www.geindustrial.com/multilin/enervista/ launchpad/ 48

49

50

Demo Relays at L-3

51

ANSI Symbols

52

Conversion of Electro-Mechanical to Electronic sheet

53

PowerPoint presentations at:

http://l-3.com/private/levine/ 54

GE Multilin Training CD’s

55

Thank You Questions?

56