Substation Automation with IEC 61850 - WordPress.com

©A

BB

Ltd.

INP

SS

-SA

S-1

2014

-11-

10

Substation Automationwith IEC 61850

Prakash Rao [email protected]

StationAutomation

Contents

§ Why Substation Automation?

§ IEC61850 Standard

§ Interoperability

§ What is GOOSE?

§ Engineering Workflow

§ Micro SCADA Pro

§© ABB Group§November 10, 2014 | Slide 2

WHY SUBSTATION AUTOMATION SYSTEMS ?

vThe technological developments that led to the present availability of fast,powerful microprocessors and communication systems give us thepossibility to build Substation Automation Systems (SAS).

vThe substation secondary equipment evolved from electro-mechanicaldevices to microprocessor based numerical devices with built incommunication features.

vThis in turn provided the possibility of implementing SAS using severalintelligent electronic devices (IEDs) to perform the required functions(protection, local and remote monitoring, control, etc.).

vThus need arose for efficient communication among the IED’s usingappropriate protocols

WHY SUBSTATION AUTOMATION SYSTEMS ?

1 - Distance protection2 - Three phase power swing unit3 - Directional earth fault protection4 - AC supervision circuits5 - DC supervision circuits6 - STUB protection7 - Auxiliary relays8 - Fault locator9 - (Printer for fault locator)10 - Disturbance recorder11 - Signaling unit12 - Parts of event recorder13 - Breaker failure protection - 1 CB14 - Tripping relays15 - Autoreclosing for one CB16 - Synchro check for one CB17 - Auxiliary transformers for

disturbance recorder

1

23

4 56 789

10

11 1213 14

1516

17

Two relay panels 600mm x 650mm x 2250mm

The main requirement = Right information with ITG

M

§ IT is more that Information Technology

§ IT = Informative technology which provides processedinformation which is easy to access and understand

§ IT = Integration Technology which means thatinformation from one part is directly available throughoutthe system so it can be utilized wherever needed

§ IT = Intelligent Technology means that all availableinformation is used to optimise the performance

§ Right information in right time for right actions

§ The “right” information means that the right informationis filtered out for each protection & control algorithm

§ The “right” information also means that the availableinformation is made useful for each responsible individualsuch as the control centre operator, the relay engineeretc.

§ The right time is measured in milliseconds for theprotection and control functions including the inter baycommunication

§ The right time also means that the operator will get theinformation needed to act rapidly

§ IED670 + MicroSCADA Pro = IT2

Type of disturbanceTime to recoverNo. of customers affected

Repair and Maintenance

Work reportWork order

CustomerService

Recovery informationCustomer complaints

StationAutomation

Customer

AssetManagement

SparesFault statistics

Disturbance informationDisturbance report

Engineering

Asset recordsDisturbance report

Sales

Customers affected

Accounting

ReportsReports

Compensation

Real-time informationDisturbance records

Control Center

Managing the Power Grid

Why we need Substation Automation System?

§ To manage

- Repetitive operation

- Complex operation

§ To have

- Accurate, timely information about all powersystem components

- Faster response

- Quicker decisions

- Faster restoration after breakdown

- Less or nil human interference

- Lower operational cost


Why Automation?

Benefits

§ Sequential control with interlocks

§ Increased safety of personnel and of equipment

§ Increased security availability, reliability and efficiency.

§ Reduced start up and shut down time.

§ Reduced configuration time.

§ Less or nil dependence on human beings

§ Lower operational cost.

Why Automation?

§ To supply the power, meeting the power quality standards:

§ Reliability : Maintain uninterrupted power supply§ Availability : Meet the demand.§ Quality : limit ,within permitted range,

Frequency deviationsVoltage FluctuationsTransientsHarmonics distortions

The electrical utility should meet the above with optimum economy.

What is Substation Automation ?

§ Substitution for conventional control panels

§ Substitution for other sub systems

§ A more efficient way of controlling your substation

8

§ A combination of

§ Protection

§ Monitoring

§ Control

§ Communication

What is Substation Automation ?

Trends in Substation Automation (SA)

ABB Substation Automation Systems > 20 years

1980ies: ABB introduces Substation Control with SPA (SCS100) and Ethernet (SCS200)1990ies: ABB implement Substation Automation with LON and IEC60870-5-1032000 + : ABB implement Substation Automation with IEC61850

§ABB Network Partner AG

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§Center NCC

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125VDC Dis tributuion Battery A 125VDC Dis tributuion Battery B

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BUSBAR PRO TECTIO N REB500

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ABB

=D04 ABOBO 1

- Q2S E L

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F E R M E RO U V R IR

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§PISA

§PISA§A§PISA§B

§PISA§A

§-Q1 §-Q2

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§Process

§Bus

§Process bus§Star coupler§ABB §Power Automation AG §RER111

§500SCM§01

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§Rx2

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§Rx3

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§Rx3

§Tx3

§Rx2

§Tx2

§Rx1

§Tx1

§500SCM§01

§Rx3

§Tx3

§Rx2

§Tx2

§Rx1

§Tx1

§Interbaybus

§Star coupler §d§g§i§t§a§l

§Tx2

§Rx1

§Tx1

§500SCM§01

§Rx3

§Tx3

§Rx2

§Tx2

§Rx1

§Tx1 §d§i§g§i§t§a§l

§NCC / RCC

§MicroSCADA

§ABB§Power Automation AG §COM581

§C

§Communication§Converter

§ABB §Power Automation AG §RER111

§500SCM§01

§Rx3

§Tx3

§Rx2

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§Rx1

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§Rx3

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§Rx2

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§Rx1

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§Rx3

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§Rx2

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§Rx1

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§Rx3

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§Rx2




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E X EE S C

L A M P ET E S T E

D IS T A N C E

L OC


§? §LOCAL§REMOTE

§SET§OPERATION

§M

§M

§M

§Drive control &

§ monitoring

§ circuitry

§Sampling

§AD-Conversion

§Signal Processing

§Signal Filtering

Implementation of Intelligent Technology

Bay LevelProtection

Line (Distance, O/C, Differential)Transformer (Differential, Thermal Overload)Generator

Basic ControlCB, Isolator and Earth Switch controlInterlocksSynchro checkTap Changer Control

Enhanced ControlIntelligent auto recloseSwitching sequenceAutomatic change of bus barsAutomatic isolation of faulty sections

Basic MonitoringStatus IndicationsMeasurementsEvents and Alarms

Enhanced MonitoringFault recordsDisturbance recordsTrends

Functions of a Substation Automation System

Other Enhanced Station Level Functions

Analysis and DiagnosticsSuppression of non-relevant alarmsFailure AnalysisSequence of Events AnalysisAutomatically generated fault reportsAutomatic Disturbance evaluation

Support for intelligent operationIntegrated Condition MonitoringIntegrated Substation DiagnosticsPlausibility checksLimit SupervisionAlarm categorization (class 1, class 2, etc.,)Automatic notification of problemsMaintenance prediction (performance based)Detection of incipient faults and preventive measuresAutomatic Load sheddingAutomatic Power restoration


Other Enhanced Station Level Functions

Automatic DocumentationSubstation changes, modification, upgrades or extensionsRecording of all operating activitiesHistorical data storageAutomatic report printing

Safe and Secure OperationThe probability of wrongly executed command is extremely smallEnhanced reliability and availability

Multiple use of DataProtectionLoad monitoringOperational valuesDisturbance recording

Communication to higher end Network Control CentresOver serial lines or LAN/WANSupport for Multiple mastersSupport for Different protocols


Data Exchange in a Substation Automation System

Monitored Information:

§ Single Bit indications (alarms, events)§ Double Bit indications (on/off status of devices)§ Step position indication (Transformer tap position)§ Analog measurements (voltages, currents, power, etc.,)§ Pulse counter data (kWH, kVARH, etc.,)§ Protection Events,§ Sequence of event records,§ Disturbance records,§ IED configuration data.

Control Information:§ Close or trip commands§ Set point (analog output) commands§ Regulating step command§ Time synchronization§ Parameter setting commands

§ Data exchange in a SAS involves communication betweenthe various IED’s, using relevant protocols.

Intelligent SA Architecture


§C

§E

§COM581

§Network Control

§Center NCC

§PIS

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§PIS

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E X EE S C

L A M P ET E S T E

D IS T A N C E

L OC


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Design Principles of Modern SA

§Mainstream Hardware

§Features

§Mainstream Software platforms§Integrated SA System§• Control

§• Monitoring (protection)

§• Disturbance recording

§• Metering

§• etc.§Open System§Bus (serial) communication§Using fibre optic media

§for communication§Compact design§Decentralised system structure§closer to process§No conventional mimic board

§Less inventories and spare parts

§Benefits

§Less training & Familiarisation§Less Hardware and panels§Less operation and maintenance

§costs§More availability§Minimising outage breaks§Integration of third-party

§equipment§Less cabling and installation

§costs§Less testing and commissioning

§costs§Less space and civil works

Highlights of Modern SA

§Features

§Numerical protection§Numerical control

§Benefits

§Safe interlocking§Self supervision§Modern MMI§Operator guidance§Maintenance support

§Easy to use and to customise

§Efficient operation§• Avoiding errors

§• Less hazards and breaks

§Increasing availability

§• Reduction of operation costs

§Reducing maintenance costs

§Higher power quality

Enhanced Functionality of Modern SA

§Features

§Process status information§On-line Primary equipment

§monitoring

§Benefits

§SA System status information§Events and Alarms evaluation§Disturbance records§Trends and calculations§Reports

§Better planning§• more timely data§Efficient trouble shooting

§All information at one glance

§Better monitoring

§Efficient asset management

§Supports operation decisions

§Intelligent or “smart”

§AIS / GIS Switchgear

§Data acquisition

§Sensors & Actuators

§Power Transformers

§Surge Arrestors


§C

§E

§COM581

§Network Control

§Center NCC

§PIS

A

§PIS

A§A

§PIS

A§B

§PIS

A§A

§-Q1

§-Q2

§-Q51

§-Q0 §-T1 §-Q9 §-Q8

§Monitoring

§Protection

§Control

§Condition monitoring

§Data exchange

§Remote communication

§Advanced functions & Tools

§Monitoring

§Protection

§Supervision & Control

§Data exchange

§ Functional Structure §Functions Allocation




1


2

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E X EE S C

L A M P ET E S T E

D IS T A N C E

L OC


§? §LOCAL§REMOTE

§SET§OPERATION

§M

§M

§M

§Pro

cess

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tion

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lIntelligent Substation Automation

Intelligent SA: Features and Benefits

§Features

§Bus (serial) communication

§to primary equipment

§Benefits

§Further reduction in yard

§cabling and installation costs§More information from primary

§equipment§Operation enhancements

§Reducing operation and

§maintenance costs

§Intelligent primary equipment

§Sampling and signal processing

§locally in primary equipment

§Less primary equipment costs

§Less project execution time

§ABB

§Interbay bus 1§Interbay bus 2§Phase L1

§PISA

§PISA

§PISA§PISA

§PISA§A

§PISA§A§PISA§B

§opt. §opt.§el.

§opt. §opt.§el.

§Abgangsschutz I

§Sternkoppler§Feldleitgerät

§Abgangsschutz II

§Line Protection 1

§Bay Controller

§Line Protection 2

§Busbar Protection

§Star Coupler

§Process Bus

§Sensors for

§current &

§voltage

§measurement

§Actuator for

§circuit breaker

§control

§Actuator for

§isolator &earthing

§switch control

Intelligent SA: Control, Protection and Sensors=D04+R01225kV LIGNE ABOBO 1ABB

125VDC Distributuion Battery A 125VDC Distributuion Battery B

BAY CONTROL RELAY REC316*4

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FERM ERO UVRIR

EXEESC

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DISTANCE

LO C

ABBPOWER MONITORING UNIT

§? §LOCAL

§REMOTE

§SET

§OPERATION

§M

§M

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§ABB Power Automation AG §REC580

§BB1:UL1=500kV§IL1=0A

§One row with informations, etc..............................................

§IL1=0A

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00kV

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00kV

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§Q51 §Q53 §Q55 §Q57

§Q15 §Q91

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§Q25

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§Q92

§Q82

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00kV

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§Q03 §Q64 §Q62 §Q02 §Q2

§Q25

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§Q92

§Q82

Bay level control via built-in mimic

Bay Level Protection Systems

§C

§E

§1

§2§3

§4§5§6

§7§8

§9

§10§11§12§13§14

§15§16

§ABB Network Partner AG §REC 316*4

§Line Protection

§C

§E

§1

§2§3

§4§5§6

§7§8

§9

§10§11§12§13§14

§15§16


§Transformer Protection

§C

§E

§1

§2§3

§4§5§6

§7§8

§9

§10§11§12§13§14

§15§16


§Generator Protection

§Advanced analysis

§ tools

§Alarm Classes

§GPS

§Universal Time

§synchronization

§User friendly

§visualization

§# Of trips

§Sequence of Events

§Automatic printing

§Summary report

§CONCISE / FAST

§Distance to Fault

§IED Parameter§ABB Network Partner AG

§C§E

§Mo 12. 11. 96 GMT 17:02.43.305

§Ay er Rajah & Labrador Feeder One

§Bay

§C§E

§R§F

§I§O

§1

§2

§3

§4

§5

§6

§7

§8

§9

§10

§11

§12

§13

§14

§15

§16

§ABB Network Partner AG §REL 316*4

§C

§E

Monitoring via IEDs for Protection

• Single line diagram

– U, I =>”fast”

– P, Q, E => “slow”

• Overview pictures

– P, Q, => “slow”

• Customised measurements

– P,Q, E

– Summation

– Minimum / maximum

– Average values

– Lists

– Bar charts

– etc. upon request

Station level supervision

§Recording and time stamping of events

Event Processing

Alarm Processing

§Persisting and

§Fleeting alarms

§Recording and time stamping of alarms

Recording of Trends and Alarm Generation

§Upper Alarm (A)

§hysteresis§Upper warning (W)§Lower warning

§Lower alarm

§A §W

Diagnostic: Fault Recording and Evaluation

§Automatic faultlocation printout

SAS-Expectation


§ Monitored Information

1. Alarms

2. Status of switching devices

3. Step position indication (Transformer tap position)

4. Analog measurements (voltages, currents, power, etc.,)

5. Pulse counter data (kWH, kVARH,etc.,)

6. Protection Events

7. Disturbance records

8. IED configuration data



§ Control Information

§ Close or trip commands§ Regulating step command§ Parameter setting command

§ Exchange of Information between devices throughGOOSE


Communication in Substation Automation:

Function in Substations & SA

Function in Substations & SA

§Today a substation automation system comprises three hierarchical levels,

• the station level

• the bay level

• the process level

§The communication between station level and bay level is realized by means ofdifferent incompatible protocols such as IEC 60870, Profibus, DNP, LON, Modbusand many of other proprietary and non-proprietary ones.

§Parallel wiring is mostly used for the communication between the bay level and theprocess level.

IEC 61850 – Communication Networks & Systems inS/S


The conventional way

§MARSHALING RACK

§TELE- §ALARMING§NISATION

§BUSBAR§PROTECTION

§Local

§Control

§Inter-

§locking§Measuring

§Bay

§Protection

§Telecontrol

§RTU§Alarming

§Synchro-

§nization

§Busbar

§Protection

§Control Board


The new way

§LAN/WAN

§TCP/IP

§Async protocols

§LON

§. . . . .

§GW

§E

§C

§RE. 5XX

§ABB

§REC 561

§E

§C

§E

§C

§RE. 5XX§REC 561

§E

§C


§ 100 – series

§ 200 – series

§ 300 – series

§ 500 – series

+ Further enhanced algorithms

+ Further increased functionality

+ Further improved tools

+ New user friendly HMI

+ Full IEC61850 implementation

= Introducing IED670

ONE high performance IEDfor ALL transmission applications

The next step in our IED evolution

§© ABB Group

§November 10, 2014 | Slide 43

IED670 IN SUBSTATION AUTOMATION

§IED = Intelligent Electronic Device used forProtection & Control of the Power System

§IED670 = is the designation of a range of newIEDs for high end transmission & generationapplications utilizing common modularhardware and software for protection andcontrol

§REC670 = Single or multi bay

§REL670 = Lines & Cables

§RET670 = Transformers & Reactors

§RED670 = Multi terminal networks

§REB670 = Bus and breaker


§Pro

cess

Leve

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tion

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l

§GIS or AIS

§Switchgear

§-Q1

§-Q0 §-Q8§-Q9

§-Q2

§1

§3§8

§=D04+R01§225kV LIGNE ABOBO 1§ABB

§ 125VDC Distributuion Battery A §125VDC Distributuion Battery B

§Fault

§Recording§=D04+R01§225kV LIGNE ABOBO 1§ABB


§BAY CONTROL RELAY REC316*4

§1§ABB

§2§4§3§5§6§7§8§9§12§11§13§14§15§16§10§LOCAL CONTROL § METERING

§LINE PROTECTION RELAY REL316*4

§1§ABB

§2§4§3§5§6§7§8§9§12§11§13§14§15§16§10§BUSBAR PROTECTION REB500

§ABB

§-Q1§1§2§3§4§5§6§7§8§9§10§11§12§13§14§15§16§c§c

§Bay Protection

§Local

§Control



§Busbar Protection§SCADA

§RTU §=D04+R01§225kV LIGNE ABOBO 1§ABB


§RTU 200§ IN 1§ IN 2§ IN 3§ IN 4§ IN 5§ IN 6§ IN 7§ IN 8§OUT

§ON/OFF


§ON/OFF

§RTU 200§ IN 1§ IN 2§ IN 3§ IN 4§ IN 5§ IN 6§ IN 7 § IN 8§OUT

§ON/OFF



§Event

§Recording

§BayControl


§ABB

§ -Q2§SEL

§ -Q1§SEL

§ -Q0§SEL

§=W1

§=W2

§FERMER§OUVRIR

§EXE§ESC

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§DISTANCE§LOC

§ABB §ABB §ABB


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§ -Q1§SEL

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Conventional Control & Protection


§Pro

cess

Leve

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tion

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§GIS or AIS

§Switchgear

§-Q1

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§Fault

§Recording§=D04+R01§225kV LIGNE ABOBO 1§ABB


§BAY CONTROL RELAY REC316*4

§1§ABB

§2§4§3§5§6§7§8§9§12§11§13§14§15§16§10§LOCAL CONTROL § METERING

§LINE PROTECTION RELAY REL316*4

§1§ABB

§2§4§3§5§6§7§8§9§12§11§13§14§15§16§10§BUSBAR PROTECTION REB500

§ABB

§-Q1§1§2§3§4§5§6§7§8§9§10§11§12§13§14§15§16§c§c

§Bay Protection

§Local

§Control



§Busbar Protection§SCADA

§RTU §=D04+R01§225kV LIGNE ABOBO 1§ABB



§ON/OFF


§ON/OFF

§RTU 200§ IN 1§ IN 2§ IN 3§ IN 4§ IN 5§ IN 6§ IN 7 § IN 8§OUT

§ON/OFF



§Event

§Recording§Bay

Control §=D04+R01§225kV LIGNE ABOBO 1§ABB

§ABB

§ -Q2§SEL

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§FERMER§OUVRIR

§EXE§ESC

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§DISTANCE§LOC

§ABB §ABB §ABB

§For each function a dedicated device

§ and separate kiosks §Extensive station wide cabling

§

§Extensive bay cabling

§

Conventional Control & Protection


§-Q1

§-Q0 §-Q8§-Q9

§-Q2

=D04+R01225kV LIG NE ABO BO 1ABB



1

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= W 1

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F E R ME ROU V R IR

E X EE S C

L A MP ET E S T E

DIS T A NCE

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ABBPOW ER MONIT ORING UNIT

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§C

§E

§COM581

§Network Control

§Center NCC

§Inter Bay Bus (Proprietary)

Modern SA Architecture



§C

§E

§COM581

§Network Control

§Center NCC

§PIS

A

§PIS

A§A

§PIS

A§B

§PIS

A§A

§-Q1

§-Q2

§-Q51

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Future SA Architecture


WHAT IS A PROTOCOL?

Protocol:

§ Set of rules that determines the behavior of functionalunits in achieving and performing communication.

Open Protocol:

§ A communication protocol whose stack is eitherstandardized or publicly available.

Up to now: different protocols used


StationAutomation

StationAutomation

Control Center Control Center

SPA, LON, DNP 3.0, MODBUS, UCA 2, Profibus, IEC60 870-5-103, K-Bus, ZZZ

IEC60870-6 (TASE2)

SCADAIEC60870-5-101IEC60870-5-104DNP 3.0ELCOM 90RP570/571XXX

Metering & BillingIEC61107IEC62056IEC60870-5-102YYY

WindfarmsIEC51400-25

IEC G703IEEE C37.94WWW

IEC 61850

IEC 61850

= IEC 61850

IEC61970 (CIM)

With a number of communication protocols

Towards a Global Solution for...

“A solid background creates stronginnovations”

...Substation AutomationSystems

Experience in:§ International standards

§ De facto standards

§ Customer requirements

§ Proprietary solutions

§ System engineering

Goals:§ Interoperability

§ Future-proof standard

… is ready now!

… products are indevelopment!

… attracts a lotof attentionfrom customersand vendors!

A Global Standard for IEC and ANSI ...

Basics:

§ Ethernet 100 MBps

§ Station Bus 61850-8-1

§ Process Bus 61850-9-2

§ Bay-to-bay communication (GOOSE)

§ Common Object Modeling (logical nodes)and Configuration Language (SCL)

Much more than a protocol:

§ Modularization and structuring of data

§ Standardized Logical Nodes

§ Mapping of functions in IEDs

§ Structured engineering & services

“Combining the best properties in a new way...”

What is IEC 61850 Open Communication?

A Breakthrough for Substation Automation

“Combining the best properties in a newway...”

§ One world

§ One technology

§ One standard

IEC 61850

What is IEC61850 Open Communication?

IEC61850 allows interoperabilityBut NOT Interchangeability

Basic Function(e.g. O/C protection)

Configuration data

Inputdata Output

data

Function still remain vendor specificData exchange is standardized in 61850

Logical Node Concept Separation IEC61850

Application(e.g. Protection)

Service(e.g. Report)

Communication(e.g. Ethernet)

Data Model

Service Rules

Mapping

IEC 61850 Time scale


Up to now: different protocols used

§IEC 61850


IEC 61850

n The IEC 61850 deals with communication within a substation only!

§“This standard applies to Substation AutomationSystems (SAS). It standardizes the communicationbetween Intelligent Electronic Devices (IEDs) and therelated system requirements.”

§From ‘Scope’ of IEC 61850


IEC 61850 a breakthrough for SA

§“Combining the best properties in a new way...”

§ IEC 61850 is a global standardfor “Communication Networksand Systems in Substations”

n One world

n One technology

n One standard

§© ABB Group


The goal of the IEC 61850 standard

§ Interoperability The ability for IEDs from one or severalmanufacturer to exchange information and use theinformation for the their own functions.

§

§ Free Configuration The standard shall supportdifferent philosophies and allow a free allocation offunctions e.g. it will work equally well for centralized(RTU like) or decentralized (SCS like) systems.

§ Long Term Stability The standard shall be futureproof, i.e. it must be able to follow the progress incommunication technology as well as evolving systemrequirements.


The New Standard for Intelligent Investment

Savings from efficient IED engineering

n IEDs are engineered using manufacturer specific IEDconfiguration tools

n Configuration tools translate the IED capabilities to the SCL(Substation Configuration description Language)

n SCL enables information exchange between IEDconfiguration tools from different manufacturers

n SCL secures backwards compatibility between differentversions of IEDs and IED configuration tools


What’s in the IEC 61850 Documentation?

§Part 1: Introduction and Overview

§Part 2: Glossary

§Part 3: General Requirements

§Part 4: System and Project Management

§Part 5: Communication Requirements

§Part 7: Communication model (Data model and Services)

§Part 6: Substation Configuration Language (SCL)

§Part 10: Conformance testing

§Part 8-1: Mapping for

§MMS-TCP/IP-Ethernet§Part 8-x:For future mappings

§Part 9-1: Mapping for point-

§to-point connections§Part 9-2: Mapping for busconnections

§Process busmappings

§Information andunderstanding

§Impact on tenders

§and product mgmt.

§Base req. forthe standard

§Enables

§interoperable

§engineering

§The real stuff!

§Realization of themodels on

the Ethernet

§Station busmappings

§Specifiesconformance test


Standard Family IEC 61850

User-near, object oriented Data model

What Is Not Included in the IEC 61850?

n Product functions are notstandardized and not included

n Operator functions and operatorinterfaces are not standardizedand not included

n Products from different vendorsare interoperablebut not necessarilyinterchangeable

§Competitionremains …


A Standard for Open Communications

Connecting:

n Devices from different suppliersn Engineering information from different

tools from different manufacturers

n Present and future installations

n New communication technologieswith existing applications

n Different and changing SAarchitectures


What is IEC61850 Open Communication?

§IEC61850 allows interoperability

§But NOT Interchangeability

§Basic Function

§(e.g. O/C protection)

§Configuration data

§Input

§data§Output

§data

§Function still remain vendor specific

§Data exchange is standardized in 61850

§Logical Node Concept §Separation IEC61850

§Application

§(e.g. Protection)

§Service

§(e.g. Report)

§Communication

§(e.g. Ethernet)

§Data Model

§Service Rules

§Mapping


Introduction of Logical nodes: Functional view

Naming and Groups of Logical Node (First letter listed)

Logical Nodes

Indicator Logical node groups QtyL System Logical Node 3

P Protection Functions 28

R Protection Related Functions 10

C Supervisory control 5

G Generic Function References 3

I Interface and Archiving 4

A Automatic control 4

M Metering and Measurement 8

S Sensors, Monitoring 4

X Switchgear 2

T Instrument Transformer 2

Y Power Transformer 4

Z Further (power system)equipment

5

- PDIR Directional Comparison

- PDIS Distance

- PSCH Protection scheme

- PTOC Time overcurrent

- PTOV Overvoltage

- more…

- MMXU Measuring (Measurand unit)

- MMTR Metering

- MSQI Sequence and imbalance

- MHAI Harmonics and inter-harmonics

- more …..- XCBR Circuit breaker

- XSWI Circuit switch

- RDIR Directional element

- RDRE Disturbance recorder function

- RBRF Breaker failure

- RFLO Fault locator

- RREC Autoreclosing

- more…


Logical Groupings


Allocation of LNs to devices (IEDs)

Data Hierarchy

Mapping the Data Model to the Stack

Approach of IEC 61850

Data access and transfer (Services)

The mechanism Client-Server messages

Common features of Reports, GOOSE and SV

How to handle these spontaneous services?

§Remote control

§Bay Level

§Process Level

§Station Level

§Station or interbay bus (LAN)

§IEC61850-8-1

§Process bus (LAN)

§IEC61850-9-2

§Station

§Computer§StationGateway

§Protection

§Process Interface

§Control§Protection§Control §Control &Protection

§Process Interface §Process Interface

§SMS & PCM

§TCP/IP LAN

§Office

The ABB SA implementation of IEC 61850


IEC 61850 based SAS Architectures

§GPSReceiver

§REC 670 §REL 670 Main I§REC 670

§RET 670 Main I

§RET 670 Main II

§REC 670

§REB 500 Main I

§REB 500 Main II

§Busbar§Line x 2 §Autotransformer x 2 §Auxiliaries

§IEC 61850 Ring network

§IEC 60870-5-101/104

§Gateway

§DR WS §Redundant HMI

§Ethernet Switch§Ethernet Switch§Ethernet Switch

§Ethernet Switch§Ethernet Switch

§Laser Printer

§DMP

§REC 670

§Bus Coupl. x 1

§REL 670 Main II


IEC 61850 based SAS ArchitecturesLASER

PRINTER

DMP

DR WORK STATION

REDUNDANT HMI

ETHERNET SWITCHES

PRINTERSERVER

RET 670

REL 670

REC 670

REB 670

REC670

Ø Single Faulttolerant ring

Ø Distributedarchitecture

Ø No Single Pointfailure


IEC 61850 based SAS ArchitecturesLASER

PRINTER

DMP

DR WORK STATION

REDUNDANT HMI

ETHERNET SWITCHES

PRINTERSERVER

RET 670

REL 670

REC 670

REB 670

REC670

§ Single Faulttolerant ring

§ DistributedArchitecture –

§ No Single Pointfailure


Interoperability

§ Interoperability according to the 61850 standard means thecapability of two or more IEDs from the same or differentvendors to exchange information and to use it in theperformance of their functions.

§ It is much more than simple data transfer.


Horizontal Communication

§ GOOSE stands for Generic Object Oriented SubstationEvent.

§ It is a mechanism for the fast transmission of substationevents, such as commands, alarms, indications, asmessages.

§ A GOOSE message sent by one IED can be received andused by several other IEDs.


GOOSE


Horizontal (peer-to-peer) communication

§Station

§computer

§Stationgateway

§Protection

§Process Interface §Process Interface §Process Interface

§Control§Protection§Control §Control &Protection

§GOOSE


IEC 61850 GOOSE Priority tagging

n IEC 61850 uses standard Ethernet

n IEC 61850 can therefore take advantage from all the options of modernEthernet

n These options are not avilable in other protocols

§NormalTelegrams

§GOOSE

§Buffer for normaltelegrams

§Overtake lane for IECGOOSE

§Ethernet-Switch


Vertical Communication

§ The HMI and gateways are IEC 61850 clients, while the IEDs are IEC 61850servers.

§ The communication between the servers and clients is usually by means ofreports.

§ IEC 61850 defines two types of reporting - buffered reports and unbufferedreports.


Buffered Reports

§ Buffered reports are messages sent to specific clients, andhave to be acknowledged by the client.

§ If a client does not acknowledge the receipt of the messagethen the IED will retransmit the report to that client.

§ In ABB system we always use buffered reports for all IEDsthat support buffered reporting.


Unbuffered Reports

§ Unbuffered reports are broadcast messages and clients donot acknowledge them.

§ Loss of data is not detected when unbuffered reports areused.


Substation Configuration Language

§SCL

§SCL: Substation ConfigurationLanguage, is a formal descriptionof the communication in asubstation

§All communication related configurations are supported by one neutral andformal description. The description can serve as support for engineering andautomatic testing.


IED Engineering

§IED Tool

§ICD-File

§Format: XML

n The .icd file describes the data model of the IEDn logical devices, logical nodes

n data sets

n control blocks


§ICD-File§ICD-File

§ICD-File

Substation Engineering

§ICD-File§SCD-File

§Substation Configuration Tool

n The .scd file describes the complete substation configuration

n single line diagramn communication network

n IED configurations

n binding information


IED configuration

§ICD-File

§IED Engineering Tool§SCD-File


© ABB GroupNovember 10, 2014 | Slide 97

Substation AutomationMicroSCADA Pro

Substation Automation system

Protection Parameter

Management

§Protection Parameter

§Management

Process visualization

§Human System Interface (HSI) Process view

§Graphical Display§Zoom, Panning and Decluttering

§Trending

§Data Analysis

§Supervisory Control

§Alarm Management

§Time synchronised

§events

§Reporting


TYPICAL SLD


HSI Overview§ Superior User Interface

§ Process Displays

§ Alarm and Event Lists

§ Blocking List

§ Trends

§ System Self Supervision

§ Reports

§© ABB Group


Monitor Pro Layout Overview

Status bar

Process Display area

Alarm

Shortcuts

Toolbar

Busbar

Coloring

ToolbarProcess

Displays

Alarm

Row

Zoom

Pan

Toolbar

View Info

Standard

menu


Event List

n All texts in several languages

n Layout settingsn Find

n Filtering

n Programmable coloringn Copy/Paste

n Comments


Alarm Listn Two list templates

n All texts in several languagesn Layout settings

n Find

n Filteringn Programmable coloring

n Copy/Paste


Blocking List

n Object texts in severallanguages

n Findn Copy/Paste


Trend Displays

n Zoom/Pan

n Copy/Pasten Export .csv


Remote communication to “SCADA”n MicroSCADA Pro is designed to

communicate and connect toControl Centers

n Flexible gateway functionalityintegrated in HSI or asa stand alone gateway

Experience in:n International standards and De

facto standards

n IEC 60870 – 5 – 101n IEC 60870 – 5 – 104nDNP 3.0 SerialnDNP 3.0 TCP/IP


§NCC

§Gateway

§MicroSCADA Pro

§COM 500*

§IEC 61850-8-1

§REx670 IEDs connected and REx 5xx terminals via

§SPA-ZC 40_ to IEC 61850-8-1 and MicroSCADA Pro

§Completely new SA system of today

§Operators workstation

§MicroSCADA Pro

§SYS 600

§COM 500§NCC

§COM581 and COM610 are alternative gateways


§NCC

§Gateway

§MicroSCADA Pro

§COM 500

§IEC 61850-8-1

§TCP/IP

§REx670 IEDs connected to IEC 61850-8-1 and MicroSCADA Pro

§Completely new SCS/SA system of today

§Operators workstation

§MicroSCADA Pro

§SYS 600

§Remote SMS workplace

§with PCM600


§NCC

§Third party Gateway

§IEC 61850-8-1

§TCP/IP

§REx670 IEDs connected to IEC 61850-8-1 and MicroSCADA Pro

§Completely new SCS/SA system of today

§Third party HSI§Remote SMS workplace

§with PCM600


Open to integration

§Capacitor

§Bank

§ Meas.

§Cubicle

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§110 kVBus Bar

§6 kVBus Bar

§Cable

§Feeder

§Overhead line

§Feeder

§S / Aux.

§Tr.

§Section

§CB

§Motor

§Feeder

§Overhead line

§Feeder

§Cable

§Feeder

§ Meas.

§Cubicle

§Capacitor

§Bank

§110kV

§Incoming Line

§110kV

§Incoming Line

§Tr. 1. Incoming

§Feeder

§Tr. 2. Incoming

§Feeder

§Section

§CB

§MicroSCADA Pro§Process Automation

§OPC

§Information Integration§Superior information handling

§One environment

§ … an integration solution


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