Automate and Preserve Electromechanical Relay Investment€¦ · January 20 – 23, 2009 Welcome to NovaTech Automate and Preserve Electromechanical Relay Investment Part 3 of 3 Using

January 20 – 23, 2009

Welcome to NovaTech

Automate and PreserveElectromechanical Relay Investment

Part 3 of 3Using the Bitronics 70 Series

to Improve Remote Monitoring and Control

Paul Grabowski

January 20 – 23, 2009

About the Author

Paul Grabowski implemented automation in over 100substations during his 29-year career with PennsylvaniaPower and Light. More recently, Paul spent five yearsas a US protection application engineer for AREVA T&D.He is now a Senior Application Engineer for theBitronics product lines. Paul is a registered ProfessionalEngineer in the State of Pennsylvania.

January 20 – 23, 2009

Contents

• Introduction

• Definitions and Elements of Remote Monitoring and Control

• Improvements to Remote Monitoring and Control using monitoring and

recording IEDs

• Incorporating the monitoring and recording IED in the RTU

January 20 – 23, 2009

Introduction

January 20 – 23, 2009

Meeting Automation Requirements

• Technology

• Microprocessor based technology provides a solution

• Two alternatives

1) Install microprocessor based relays

- Replace electromechanical relays

OR

2) Install microprocessor based recording and monitoring IEDs

- Such as the Bitronics 70 Series

- Allows retention of electromechanical relay scheme

Realize substantial cost savings

January 20 – 23, 2009

Some Typical Automation Goals

1) Fault Analysis and Recording

2) Improve Local Monitoring and Control

3) Provide/Improve Remote Monitoring and Control

4) Monitor Power Quality

5) Provide Protective Function Setting Groups and BackupProtective Features

January 20 – 23, 2009

Conclusions from Part 1

• Comparison of costs• Alternative 1 Replace electromechanical relays with microprocessor based relays more costly• Alternative 2 - install microprocessors based non-relay IED such as Bitronics 70 Series• Relay replacement is 3x to 5x as costly

January 20 – 23, 2009

Some Typical Automation Goals

1) Fault Analysis and Recording

2) Improve Local Monitoring and Control

3) Improve Remote Monitoring and Control

4) Monitor Power Quality

5) Provide Protective Function Setting Groups and Backup ProtectiveFeatures

January 20 – 23, 2009

Definitions and Elements of

Remote Monitoring and Control

January 20 – 23, 2009

Remote Monitoring and Control

• SCADA = Supervisory Control and Data Acquisition

• Remote monitoring and control has traditionally meant installing a SCADAsystem

• Installed at the control location (e.g. central office)• Referred to as a Master Station (SCADA Master)

• Purpose of SCADA Master• Centralized monitoring and control• Unmanned substation operation

• Function of SCADA Master• Read currents, voltages and power• Read accumulators• Monitor control device (e.g. breaker) status• Send control commands (e.g. trip/close breaker)• Send set-points

January 20 – 23, 2009

SCADA Development

• SCADA can be applied to various system• Electrical substations• Water systems• Oil and gas pipelines

• SCADA in electrical systems – 1960s

• Focus – Electrical Substations• With Electromechanical relays

January 20 – 23, 2009

Elements of a SCADA system

Central Office

Substation

Substation

Substation

RTU*

RTU*

RTU*

SCADAMaster

Computer

Communicationsmedium

*RTU = Remote Terminal Unit

Poll RTUs

Master Station

Remote Stations

Send commandsand setpoints

January 20 – 23, 2009

Master Station

• Major investment

• Main frame computer

• Special software

• High cost

• Initial cost $100,000s to $1,000,000s

• Upgrades

• Example – Add new protocols

• Complex

• $100,000s

January 20 – 23, 2009

Communications and RTUs

• Communications medium

• Often leased phone line

• Costly

• Limited bandwidth

• Remote Terminal Unit (RTU)

• Details to follow

January 20 – 23, 2009

Typical RTU

Leased Phone Line

Electronics Trans-ducers

ControlInterface

CT and PTcables

• Dedicated cabinet or panel• Very large

• All currents and voltages are brought in from bays or control panels

• All control cables are brought out to each bay or control panel

Controlcables

January 20 – 23, 2009

Courtesy of BPA

Transmission Substation RTU

LineBays

CircuitBreakers

Control House

Transformers

RTU

January 20 – 23, 2009

Transmission Substation Basic Infrastructure

Line Bays

CircuitBreaker

ControlPanels

RelayPanels

Control House

Status

Trip/Close

(Protection &Monitoring)

(SubstationEquipment)

January 20 – 23, 2009

Transmission Substation RTU – Major Investment

Line Bays

CircuitBreaker

ControlPanels

RelayPanels

RTU

Control House

Status

Trip/Close

CT & PT CablesStatus & Control Cables

Costly ($50,000+)

Engineering/Drafting

Materials

LaborExposure



January 20 – 23, 2009

Distribution Substation RTU

LineBays

CircuitBreakers

TransformersControl House not shown(RTU in Control House)

January 20 – 23, 2009

Distribution Substation Basic Infrastructure

Line Bays

CB

ControlCabinet

Control House

Status

Trip/Close

Basic Infrastructure



January 20 – 23, 2009

Distribution Substation RTU - Major Investment

Line Bays

CB

ControlCabinet

RTU

Control House

Status

Trip/Close

CT & PTCables

Status &ControlCables

January 20 – 23, 2009

Distribution Substation RTU - Major Investment, cont’d

Line Bays

CB

ControlCabinet

RTU

Control House

Status

Trip/Close

CT & PTCables


Costly ($50,000+)


Materials

Labor

Exposure

Labor (cables - direct burial)

January 20 – 23, 2009

Improvements to Remote

Monitoring and Control using

monitoring and recording IEDs

January 20 – 23, 2009

Improvements using monitoring and recording IEDs

1) Expand Master Station’s limited data base

2) Add Master monitoring and control functions

3) Simplify circuitry at Substation

4) Improve set-point control from Master Station

5) Improve Master Station breaker control using logic in the IED

January 20 – 23, 2009

1) Expand Master’s limited Data Base

3

current

3 Volts 1

(Line)

3 Volts 2

(Bus)

Remote Monitoring & Control IED

Completeview

Limitedview

No idea Operators perspectiveof events

No RTUExisting

RTU

70 Series

IED

Ia

Ib

Ic

Van

Vbn

Vcn

3 Watts 3 Watts

3 VARS 3 VARS

Line Data

Ia

Vbn

No RTUExisting

RTU

70 Series

IED

Van

Vbn

Vcn

Bus Data

Vbn

January 20 – 23, 2009

No RTUExisting

RTU70 Series IED

Vab

Vbc

Vca

Bus Data

Vbn

No RTUExisting

RTU 70 Series IED

Ia

Ib

Ic

Vab

Vbc

Vca

3 Watts 3 Watts

3 VARS 3 VARS

Harmonics

Distance to Fault

Sequence I&V

Line Data

Ia

Vbn

1) Expand Master’s limited Data Base, cont’d

3

current

3 Volts 1

(Line)

3 Volts 2

(Bus)


Improved and new information

January 20 – 23, 2009

2) Add Master monitoring and control functions

Central Office

Substation

Substation

Substation

RTU*

RTU*

RTU*

SCADAMaster

Computer

Communicationsmedium

*RTU = Remote Terminal Unit

Polling

New Localmonitoring fromWebinar Part 2

January 20 – 23, 2009

2) Add Master monitoring and control functions, cont’d

• Trip circuit monitor – normal trip circuit

Fuse

+VDC

TC

-VDC

5052a

Input

Mx70 DigitalInput

Link

51

External LED on

SCADA Alarm– Trip Circuit

Normal


January 20 – 23, 2009

2) Add Master remote monitoring and control functions, cont’d

• Trip circuit monitor – open trip circuit

Fuse

+VDC

TC

-VDC

5052a

Input

Mx70 DigitalInput

Link

51

External LED off

One of these is open

SCADA Alarm– Trip Circuit

Open


January 20 – 23, 2009

3) Simplify Circuitry at Substation

ElectronicsTrans-ducers

macurrentloops

A phsamp

W/VARCTs &PTs

Voltage

Hardware Cables Hardware

• Existing RTU uses complex circuitry to acquire data

• Currents and Voltages shown, similar case for status and control

Digital Outputs

3 Watts

3 VARS

Ia

Vbn

SCADA Data - Digital

January 20 – 23, 2009

3) Simplify Circuitry at Substation, cont’d

• One box solution

• Fewer components – More reliable

Three phasecurrent, line &bus voltages in

SCADA Data - Digital

Register Data

1 Health

2 Ia

3 Ib

4 Ic

5 Line - Vab

6 Line - Vbc

7 Line - Vca

8 Bus - Vab

9 Bus - Vbc

10 Bus - Vca

11 Watts - three phase

12 VARS - three phase

Monitoring & Control IED

January 20 – 23, 2009

4) Improve Master Set-point control

PowerSystem

Gen

GatesH2O

Exciter

• Example: Controlling Hydro-generation

January 20 – 23, 2009

4) Improve Master Set-point control, cont’d

PowerSystem

Gen

GatesH2O

Exciter

Control VARoutput

Control poweroutput

• Example: Controlling Hydro-generation

January 20 – 23, 2009


Monitoring & Recording IED

VoltagesCurrentsDigital Inputs

Monitor system

PLC / DCS

Provide logic andcontrol functions

LAN

Operate Digital Outputswhen requested

By Monitoring &Recording IED

ByPLC/DCS

• Use non-relay IED to improve

January 20 – 23, 2009



VoltagesCurrentsDigital Inputs

Monitor system

PLC / DCS

Provide logic andcontrol functions

LAN

Values

Commands

Operate Digital Outputswhen requested

SCADAMaster

By Monitoring &Recording IED

ByPLC/DCS

January 20 – 23, 2009


Gen

GatesH2O

ExciterSCADAMaster

Control system

LAN

1) Send

set-points

MonitorMW &MVAR

2) Read set-points &

MW/MVAR from IED

• Operation of generation control, 1 of 2

January 20 – 23, 2009


Gen

GatesH2O

ExciterSCADAMaster

Controlsystem

LAN

5) Pulse digital

outputs

3) Set-points

MW/MVAR flow

4) Issue output

commands to IED

• Operation of generation control, 2 of 2

January 20 – 23, 2009

5) Improve Master breaker control using IED Logic

PowerSystem

Gen

GatesH2O

Exciter

Breaker control

Sync check /

Live or dead system

• Example, generator CB control

Controlling Master operation

January 20 – 23, 2009

5) Improve Master breaker control using IED Logic

PLC / DCSLAN

Va1 Va2

AngleVa1-Va2

52b

fVa1 fVa2

SCADAMaster


January 20 – 23, 2009

5) Improve Master breaker control using IED Logic, cont’d

PLC / DCSLAN

SCADA Master

1) Issue

Close

command

2) Permissive Contact

developed from M870 data

Closecontact

SCADA Close Command

Permissive Contact from PLC

from M870 data

Close contact


Monitoring & Recording IED Logic

January 20 – 23, 2009

Incorporate the IED into an RTU

January 20 – 23, 2009

Case 2 No RTU Existing SCADA Master

Case 2a Provide RTU capability in a Transmission Substation

Case 2b Provide RTU capability in a Distribution Substation

Case 1a Incorporate when adding a new line and terminal

Case 1b Incorporate when replacing all the existing transducers

Incorporate the non-relay IED in the RTU

Case 1 Existing RTU Existing SCADA Master

Case 3 No RTU No SCADA Master

• The interface problem

• Three cases are developed based on the availability of an RTU andSCADA Master

Develop a SCADA system using a non-relay IED in conjunction

with and Orion

January 20 – 23, 2009

Line 1 XdcrsLine 2 XdcrsLine 3 Xdcrs

Line 1 T&CLine 2 T&CLine 3 T&C

Case 1a - Adding points points in an existing RTU

• Scenario• SCADA master uses legacy protocol• The legacy RTU functions• No spare boards available• Add a new line and terminal

ElectronicsTrans-ducers

ControlInterface

Add New line but nohardware is available

January 20 – 23, 2009

Case 1a - Adding points in an existing RTU, cont’d

Line Bays

CircuitBreaker

ControlPanels

RelayPanels

RTU

Control House

Status

Trip/Close

New project


Don’t needto run

cables fornew bay

New Panels

January 20 – 23, 2009


Line Bays

CircuitBreaker

ControlPanels

RelayPanels

RTU

Control House

Status

Trip/Close

New Panel

Monitoring &Recording IED

Interface?

Master

LegacyProtocol

January 20 – 23, 2009


Line Bays

CircuitBreaker

ControlPanels

RelayPanels

RTU

Control House

Status

Trip/Close

New Panel

BitronicsAOC8 channels

ma

In panel

Serial to AnalogConverter in RTU

Master

LegacyProtocol

DNP or ModbusRS485 twisted pair

January 20 – 23, 2009


RTU

BitronicsAOC8 channels

maSerial to Analog

Converter in RTUMaster

LegacyProtocol

DNP or Modbus RS485twisted pair

• Existing RTUs limited ability to interface with new equipment

• Serial to Analog solution fits into existing RTU functionality

• Transparent to existing SCADA system

January 20 – 23, 2009












with and Orion

January 20 – 23, 2009

Case 1b - Total Transducer Replacement

LeasedPhoneLine

Electronics Trans-ducers

ControlInterface

CT and PTcables from

eachpanel/breaker

Status andcontrol cables

to eachpanel/breaker

OK

Replace Replace

• Scenario• The legacy RTU functions well• Multiple transducer failures and Status/Control interface hardware failures• No spare boards available

January 20 – 23, 2009

Case 1b - Total Transducer Replacement, cont’d

Install inside on rear panel

• Project• Gut the transducer cabinet• Install 70 series• Utilize wiring already existing in transducer cabinet

Electronics Trans-

ducers

Control

Interface

Electronics Trans-

ducers

Control

Interface

Master

Legacy

Protocol

Master

Legacy

Protocol

January 20 – 23, 2009


Install inside on rear panel

• Project• Gut the transducer cabinet• Install 70 series• Utilize wiring already existing in transducer cabinet

Electronics Trans-

ducers

Control

Interface

Electronics Trans-

ducers

Control

Interface

Master

Legacy

Protocol

Master

Legacy

Protocol

Interface?

January 20 – 23, 2009

ma


Inside Transducer cabineton rear panel

• Additionally install Bitronics Serial to Analog Converters

• Works seamlessly with legacy protocols

DNP or ModbusRS485 twisted

pair

8 channelsSerial toAnalog

Converter

Electronics Trans-

ducers

Control

Interface

Electronics Trans-

ducers

Control

Interface

Master

Legacy

Protocol

Master

Legacy

Protocol

January 20 – 23, 2009

ma


• Existing RTUs limited ability to interface with new equipment

• Serial to Analog solution fits into existing RTU functionality• Transparent to existing SCADA system

DNP or ModbusRS485 twisted pair

8 channelsSerial toAnalog

Converter

Electronics Trans-

ducers

Control

Interface

Electronics Trans-

ducers

Control

Interface

Master

Legacy

Protocol

Master

Legacy

Protocol

January 20 – 23, 2009


To Master

RS232 orRS485 DNP3.0

or Modbus

To Master

Ethernet Hub

ProtocolConversion

• Another interface option

Serial communications Ethernet communications

ProtocolConversion

January 20 – 23, 2009


Transducer cabinet insideon rear panel

Communicationsas on previous

slideProtocols

DNP3.0 / Modbus

ConitelHarrisL&G+ others

Comms Processor forProtocol Conversion

Master

January 20 – 23, 2009

Case 1a/1b - Additional benefits

• Cost Savings• Retaining the electromechanical relay investment• AND Retain the investment in the existing SCADA System

• Why?

• SCADA Master• Use existing legacy protocols• Upgrade to Master not required

• Substation• Retain all or part of the RTU

January 20 – 23, 2009

Case 1b – Another Additional Benefit

Dial-in

phone lineSCADA via DNP3.0/MODBUS/IEC61850

Internet

Hub or Switch

Select one of two

options

Comms Processor for

Engineering Access

• Engineering Access• Records

• Waveform, sequence of events, etc.• Monitor operation real time• View and change settings

January 20 – 23, 2009












with and Orion

January 20 – 23, 2009

Case 2 - When is a new RTU required

• Two cases

• The existing centralized RTU cannot be used

• Faulty cables costly to replace

• Faulty hardware

• There is no RTU currently in service

January 20 – 23, 2009












with and Orion

January 20 – 23, 2009

Case 2a - New Transmission Sub RTU

Line Bays

CircuitBreaker

ControlPanels

RelayPanels

RTU

Control House

Status

Trip/Close


Costly to replace or add

January 20 – 23, 2009


Line Bays

CircuitBreaker

ControlPanels

RelayPanels

RTU

Control House

Status

Trip/Close


Don’t need to add this

Non-relay IEDs such as 70series have RTU features +communications

January 20 – 23, 2009


Bay 1Line 1

Bay 1Line 2

Bay 2Line 1

Bay 2Line 2

To SCADA Master

RS485 DNP3.0 or Modbus

or Ethernet

RS485 RS485

Transmission Substation control panels

Comms Processor for

Protocol Conversion

ConitelHarrisL&G+ others

• Supporting Legacy protocols

January 20 – 23, 2009

Case 2a - Added Feature

Dial-in


Internet

Hub or Switch

Select one of two

options

Comms Processor for

Engineering Access



January 20 – 23, 2009












with and Orion

January 20 – 23, 2009

Case 2b - New Distribution Sub RTU

LineBays

CircuitBreakers

Transformers

Control House not shown

January 20 – 23, 2009

Case 2b - New Distribution Substation RTU, cont’d

Line Bays

CB

ControlCabinet

RTU

Control House

Status

Trip/Close

CT & PTCables


Costly ($50,000+)


Materials

Labor

Exposure

Labor (cables - direct burial)

January 20 – 23, 2009


Line Bays

CB

ControlCabinet

RTU

Control House

Status

Trip/Close


CT & PTCables


Non-relay IEDs such as 70series have RTU features +communications

January 20 – 23, 2009


Line Bays

CB

ControlCabinet

Control House

Status

Trip/Close


M571 in eachControl Cabinet

RS485 Network,

Ethernet – wire or fiber

or **Wireless

Legacy or modernprotocols or Ethernet

**Wireless provided byothers

Comms Processor for

Protocol Conversion

January 20 – 23, 2009

Case 2b - Added Feature

Dial-in


Internet

Hub or Switch

Select one of two

options

Comms Processor for

Engineering Access



January 20 – 23, 2009












with a communications processor

January 20 – 23, 2009

Case 3 – Develop an entire SCADA System

• Requirements for SCADA

• SCADA Master computer

• Communications with protocol

• RTU

• None of these exist

• conventional SCADA installation very costly

• Is there any other low-cost option?

• Yes

January 20 – 23, 2009

Case 3 – Develop an entire SCADA System, cont’d

SubstationUser

Internet

LAN

Comms Processor w/

multiple functions

Monitoring &

recording IEDs

• Configuration

January 20 – 23, 2009


SubstationUser

Internet

LAN

Comms Processor w/

multiple functions

Monitoring &

recording IEDs

• Critical functions – Where are they?• RTU• Communications with Protocols• SCADA Master

January 20 – 23, 2009

Substation LAN (EthernetWire or fiber / RS485)

Polls the 70 series

Comms Processor as

Data Concentrator

Protocols (DNP3.0 /Modbus / IEC61850)

IEDs located in eachbay or panel

( Provide monitoring andrecording function )


• The RTU functionality• Comms processor as data concentrator / controller• IEDs monitor data and trip/close breakers• Interface from substation LAN

January 20 – 23, 2009

SubstationUser

Internet

Comms Processor as

Web Page Server


• The SCADA Master Functionality• Shared between user PC and Orion• Comms via Internet

• Orion

• Serves out a series of web pages

• Web pages provide one line, control, etc.

• As many as desired

• Web page built using Scalable VectorGraphics program

• Reads data from IED

• Sends commands to IEDs

January 20 – 23, 2009

SubstationUser

Internet

Comms Processor as

Web Page Server


• The SCADA Master Functionality• Shared between user PC and Orion• Comms via Internet

• User PC

• Only one software required

• Mozilla Firefox web browser

• No drivers

• No special protocols

• Loads web pages from Orion

• Initiates commands through the Orion

• Orion provides security

January 20 – 23, 2009

• Bitronics Substation Model

• Located in factory in Bethlehem, PA

• Access using Mozilla Firefox from an Internet connection

• Accessible worldwide 24 hours a day

• To connect go to http://72.44.181.55/home.svg

• This allows your PC in conjunction with the ORION to function as the SCADAMaster

• Substation model is a model of a functioning 3 phase substation

• View one line

• Operate various elements


January 20 – 23, 2009

Conclusions

January 20 – 23, 2009

Conclusions

• Electromechanical relay schemes

• Provide adequate protection

• Lacks remote monitoring and control features required and desired

• Improving remote monitoring and control can be provided by Bitronics

70 Series monitoring and recording IED

• Allows retention of the Electromechanical relays

• RTU related

• Existing RTU - allows retention of the RTU

• No existing RTU - allows installation of an RTU

• Provides improvements in remote monitoring and control

• Allows new features to be developed

January 20 – 23, 2009

Don’t forget

• This presentation focuses on using the 70 series to improve remotemonitoring and control

• This is only part of the automation picture

• In addition, you get• Fault recording and monitoring• Improved local monitoring and control• Improved power quality monitoring

January 20 – 23, 2009

Future Webinars

• Part Four – Improve power quality monitoring June 25, 2009

January 20 – 23, 2009

Questions?

Thank you.

January 20 – 23, 2009

Part Three of Four

Using the Bitronics 70 Series

to Improve Remote Monitoring and Control

The End

Documents

Automate and Preserve Electromechanical Relay Investment€¦ · January 20 – 23, 2009 Welcome to NovaTech Automate and Preserve Electromechanical Relay Investment Part 3 of 3 Using