asia smart grid 2010_application of iec61850 substation

7/26/2019 Asia Smart Grid 2010_Application of IEC61850 Substation

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SUCCESSFUL APPLICATION OFIEC61850 SUBSTATION AND REAL

TIME ASSET-FOCUSED RISK

MANAGEMENT

Truong Huu Thanh

Power Transmission Company No.4, National

Power Transmission, Vietnam Electricity

Tran Anh ThaiApplied Technical Systems Company, Ltd.

Presentation Overview

Introduction to Power Transmission

Company No.4

Substation modernization initiative

First phase

Second phase

Third phase: IEC 61850 @STATION Real-time and Historian Data application


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Electricity of Vietnam (EVN)

State-owned utility established 1995

Generation, transmission, and distribution

for whole country

4 transmission

companies

79,800 km of

distribution lines

Power Transmission Company No.4

OHL

500KV 11 765 Km220KV 57 3,376 Km

Total 68 4,142 Km

GRID STATION

500KV 6 5,476 MVA

220KV 25 9,530 MVA

Total: 31 15,006 MVA


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Growing Electricity Demand

Forecasted growth 17% per annum until 2025

0

100

200

300

400

500

600

1995 2000 2005 2010 2015 2020 2025

Production

Sales

Terawatt-Hours

Measuring P/Q/U/I/Cos

Getting status ON/OFF/OK

Work orders/permit

Technical document

Maintenance log-book


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Measuring P/Q/U/I/Cos

Counting kWh/kVArh/TOU Geting ON/OFF/OK

Work schedule

Customer Information

Maitenance Log-book


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Open system

Multi Protocol compatible Multi data transmission media

Off-the-Shelf

SMART GRID-Conceptual Model


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The overall picture

Highlights of Substation Automation

and Integration in Vietnam

First Phase Substation

Modernization Began in 1999

First computerized 220 kV

substation commissioned

in Ho Chi Minh City

This success resulted

in digitizing more

substations through

2003


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Early Substation Modernization

Digital protection and control using legacyserial and hardwired connections

Problems with incompatibilities between

multiple manufacturers IEDs

Second Phase Standardization

To improve IED compatibility, EVN issued

specification for substation automation based

on UCA2

Based on this, first large-scale substation

automation system (SAS) was implemented


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Second Phase Standardization

To improve IED

compatibility, EVN

issued specification

for substation

automation based on

UCA2 in 2003

The first large-scale

substation automation

system (SAS)commissioned in 2002

220 kV Thu Duc Substation


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220 kV Thu Duc SubstationSAS makes theretrofit works

much easier.

Upgraded

Protection

System

Architecture


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Third Phase IEC 61850

IEC 61850 Part 10 approved Oct. 2005

EVN standardized for future projects

new and retrofit

All 500 kV

backbone

substations

upgraded by

2012

New System Requirements

Dual redundant fiber-optic LAN with no

single point of failure affected SAS operation

IEC 61850 for all substation communication

IEC 60870-5-101/104 for SCADA


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Host 1 Host 2 Engineering(Bridge to SCADA) HIS Server Router to WAN

BackupIED

BackupIED

MainIED

MainIED

BayDevices

BayDevices

MainNIM

BackupNIM

Bay CubicleBay Cubicle

Bay Cubicle

Option 2

Option 1

LAN 1

LAN 2

GPS Clock

Backup

IED

Main

IED

BayDevices

Fiber-OpticEthernet

100 Mbps

Standard System Hardware Architecture

Standard System Hardware Architecture

Target Fully Redundant SAS Architecture

protective relays

certain IEDs connect to the substation bus viaNetwork Interface Modules

Ethernet 100 Mbps

Redundant LAN

Main

Backup

Backup Network InterfaceModule

Main Network InterfaceModule

Backup

IED

Main

IED

Bay Device

Backup

IED

Main

IED

Bay Device

Backup

IED

Main

IED

Bay Device

Backup

IED

Main

IED

Bay Device

I/O modulessynchrophasors revenue meters

Internet

Substation Computer

Host 2

Substation Computer

Host 1

HIS/WEB

Servers

Engineering

WorkstationGPS clock

Gateway /

Router

WAN / Corporate

LAN


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Computerized Control and Monitoring

Local HMI,engineering console,

and historian

Redundant system

servers running on

Windows 2000 or Linux

Old Protect ion Panels Replaced

Microprocessor-based relays perform

protection, control, and monitoring


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Outdoor Cubicles Reduce Cabling

Old Copper CablingThu Duc Substation


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Copper

Cabling

Reduced

@STATION System Overview


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Legacy Device GatewayRugged Computing Platform

SCADA Gateway


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Copyright ATS, EVN, and SEL 2009

Job-done at Sites


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Real-time web access


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Real-Time Database Management

System (RTDMS)

Integrates over 100

IEDs

Handles more than

60,000 data points

Provides customized

applications

Real-Time Database Management

System (RTDMS)

Integrates over 100 IEDs

Handles more than 60,000 data points

Provides customized applications


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Controls Ensure Uninterrupted

Operation

Four-level hierarchical system

Protection and control functions at bay and

substation levels

Traditional hardwiring

Soft interlocking logic

Remote controls from local mimic panel

Controls Ensure Uninterrupted

Operation

Remote supervision and

bay controls from PDA


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Performance and Functional Tests

Factory acceptance testing conducted atATS factory

10 engineers, 3 weeks

System capacity

Communications failure

System successfully passed all

requirements

Performance and Functional Tests

FAT testing conducted atATS factory 10 engineers, 3 weeks Individual tests Functional tests System tests

System successfully

passed all requirements


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Test Results

User Interface Feature Required byEVN

Tested

Display Response Time < 1 s < 1 s

Data Entry Response Time < 1 s < 1 s

Display Update Rate < 2 s < 2 s

Update Completion Rate < 1 s < 1 s

Test Results

User Interface FeatureRequired by

EVNTested

Alarm/Event

Response Time< 1 s < 1 s

Alarm Acknowledge/

Delete Time< 2 s < 2 s

Report and Logbook

Response Time< 0.5 min < 0.5 min

Display Color PrintoutResponse Time

< 0.5 min < 0.5 min


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User Interface Feature Required byEVN

Tested

Console Inhibit Time for

Display Hardcopy< 2 s < 1 s

Analog Data

Collection Rate < 2 s

Status Indication

Collection Rate < 1 s

Failover Time Between

Main 1 and Main 2 0 s

GOOSE Exchange Time < 10 ms < 8 ms

Test Results

Benefits of SAS

Faster system integration with IED

interoperability

Reduction of copper cabling and

hardwiring

GOOSE for peer-to-peer data

exchange

Outdoor cubicles adjacent to feeder or

bay System malfunctions reduced by nearly

50%


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Benefits of SAS

Interoperability between

different IEDs fastersystem integration

Reduction of copper

cabling and hardwiring

GOOSE for peer-to-

peer data exchange

Outdoor cubicles

adjacent to feeder or

bay

System malfunctions

reduced by nearly 50%

Substation LAN Architecture

Facil itates Integrated Systems

Easy expansion

Less complex connections

Multiple communications types

Metering

SCADA

Peer-to-peer

Engineering access

Synchrophasors


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Substation LAN Architecture

Facilitates Integrated Systems Easy expansion

Less complex

connections

Multiple comm types

Metering

SCADA

Peer-to-peer

Engineering access

Synchrophasors

Benefits of Legacy Gateways

Provide common network connection

for all devices

Eliminate dependence on legacy

protocols


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Benefits of Legacy Gateways

Eliminates

dependence on

legacy protocols

Provides commonnetwork connection

for all devices

Copyright ATS, EVN, and SEL 2009

Real time and HIS

Application


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Vietnam Back-bone Transmission Lines

707 MW (1 line)

1440 MW (2 lines)

1080 MW (1 line )

1420 MW (2 lines )

1503 MW (2 circuit)

2005 Black-out in Vietnam

Background Conditions

Longitudinal system

three distinc t electrical areas

South - Center - North

signif icant MW transfer from South

to North on 500 kV line

double circuit South - Center

one circuit Center - North

second circuit due in 2005

Major deficit in the North unusual load level in 2005

28% increase from 2004

severe draught

on May 17, 2005, the Northern Region

hydro reservoirs w ere almost empty


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Simulation calculations for

the Northern area predicted

that the system would

approach instability if morethan 887.44 MW were

transferred from Center to

North across the 500 kV line

Calculations before the May 17

2005 Blackout (cont 'd)

After Fault Analysis 2005 Blackout

(cont'd)

... evaluated thi s new case (882.2 MW transfer from Center to North) as

critically stable (less than 1% stability reserve)


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Improve System Reliabili ty

and Stability

Increase power transmission across existing

infrastructure

Monitor and control voltage and angle

instabilities

Require dynamically calculated maximum

loading conditions in real time

Wide-Area Synchrophasor

Application

New IEDs with synchrophasor measurement

capability

Minimal incremental cost

Fewer CT and VT connections

High reliability and availability


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Monitor ing Principle

Synchrophasor Application

Architecture


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Use MATLAB for Complex Calculations

Desktop Application Provides

Real-Time Transmission Capacity


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Web Application for Remote Access

Visualized system loading


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Transformer and OHL on-line

Ampacity

Detailed Display of 220 kV Transformer Dynamic Loading Capacity User Interface

Questions?

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