Smart Substationsin MEA’s Distribution System

Pichit Jintagosonwit

Uses information technologies to improve how electricity travels from power plants to consumers

Allows consumers to interact with the grid

Integrates new and improved technologies into the operation of the grid resulting in new services and functions

Electrical Infrastructure + Intelligence Infrastructure

Smart Grid

MEA’s Smart Grid Objectives

Power System

• Enhance reliability of the existing grid• Improve efficiency of MEA power system

Services

•Create opportunities for new services•Enable active participation by consumers

Energy Saving and Renewable Energy

•Promote energy saving and integration of renewable energy resources

•Support new technologies i.e., electric Vehicle-to-Grid (V2G)

MEA’s Smart Grid RoadmapStage 1

2012– 2016

Laying the Foundations

Stage 2

2017 – 2021

Large Scale Implementation

Stage 3

2022 – 2026

Ultimate Stage

Power System

Implement Substation Automation based on IEC61850 for existing substations

40 substations 100 substations 100% (approx. 170 substations)

Implement Distribution Management System

30% of service area 60% of service area 100% of service area

Employ outage monitoring system in HV and MV Extend outage monitoring system to LV

Initiate self-healing capability in HV and MV for some areas.

Expand self-healing capability in HV and MV to

cover the entire service area

Implement asset management to reduce operation and maintenance costs

Smarter Substation

Focusing on secondary devices (protective relay, CT/PT) commonly called IEDs (Intelligence Electronic Device).

Layer-3 Ethernet switches and TCP/IP (instead of serial comm.)

IEC61850 (Trend of application protocol).

Substation applications have to utilize real-time information as much as possible.

The old smart substation ‘s applications normally use only DI/DO and can not utilize AI which maybe required for very fast decision such as 3-bays BTO.

Substation + The Latest Information Technologies

IEC61850 Messaging (1)

IEC61850 Messaging (2)

3-Bays BTO Function (1)

27

L1 L2

BCA

BCB

BC

DS2A

DS2B

DS1A

DS1B

Auto

Bus A

Bus B

2

Termainal Station 1

Termainal Station 2

Subtation

3 Bays-BTO

Do not Close due to Tr.2 may be overload

1

2

3-Bays BTO Function (2)

27

L1 L2

BCA

BCB

BC

DS2A

DS2B

DS1A

DS1B

Auto

Bus A

Bus B

3

4

2

Termainal Station 1

Termainal Station 2

Subtation

3 Bays-BTO

1

2

Smart Substation for Smart Grid

Supporting future grid applications in scale of bay-level response time (4ms by native GOOSE, super fast for grid level) by using VLAN across WAN.

GOOSE/UDP is coming for across network via gateways /firewalls.

Making us can share communication infrastructure such as fiber-optic cores. For Example ,in the past, we had to use dedicated cores and PLCs for LTF (Line Transfer Function between substations)

Because of TCP/IP, Switch, IEC61850 technologies

LTF (1)

Inline Substation

Managed Switch

IED withLTF function

Open-loop Substation

IED with LTF function

Managed Switch

IP Network

LTF (2)

27

L1-A L2-A

BCA-A DS-B

L1-B L2-B

BCB-A

BC-A

DS2A-A

DS2B-A

DS1A-A

DS2B-A

Inline Substation

Auto

27 Trip

2

3 4

DS1-B DS2-B

From Terminal Station 1

From Terminal Station 2

Open-loop Substation

Delay of 0.2 Sec

1

CCU#2

Station bus

Station Gateway

CCU#1HMI

Processinterface Processinterface Processinterface

Bay controlProtection& Control

Protection& Control

Protection& Control

Bay control

SCADA

TDS

Protective Relay BCU

Consolidation Concept

Smart Substation > Substation Automation

14

Typical System Topology

HMI

EngineeringPortable MMI

Main 21/21N,27/59, 79, 50BF

67/67N,27/59 50BF+ BCU

Line Bay

Main87

50/51, 50/51N, 50BF+BCU

Trans. Bay

50/51, 50/51N, 50BF+BCU

BS/BC. Bay

Main 21/21N,27/59,79,50BF

67/67N,27/59 50BF+ BCU

Line Bay

Main 87

50/51, 50/51N, 50BF+BCU

Trans. Bay

Gateway With Firewall(CGW)

DCC

115/69kV

Station Computers

Switch Switch Switch Switch Switch

Switch Switch

TDS

GPS

CCU#1 CCU#2

LAN A

LAN B

Station Level

Bay Level

Substation Automation (SA)

Substation Automation (SA)

230 kV Switchgear

Station-LAN:

IEC 61850; Ethernet 100 Mbps

Fibre Optic Double Loop with

redundancy function

Power Transformer

No.1

Line Incoming

No.1

230 kV Switchgear

SICAM PASStation Unit

7SJ61 (50/51)

192.168.1.83

7SJ61 (50BF)

192.168.1.84

7SD61 (87L)

192.168.1.867SJ61 (50BF)

192.168.1.87

7SA52 (21/21N)

192.168.1.85

7UT61 (87T)

192.168.1.82

Bus Coupler

7SJ61 (50/51)

192.168.1.887SJ61 (50BF)

192.168.1.89

Power Transformer

No.2

Power Transformer

No.3

Line Incoming

No.2

7SJ61 (50/51)

192.168.1.91

7SJ61 (50BF)

192.168.1.92

7UT61 (87T)

192.168.1.90

7SJ61 (50/51)

192.168.1.94

7SJ61 (50BF)

192.168.1.95

7UT61 (87T)

192.168.1.93

7SD61 (87L)

192.168.1.977SJ61 (50BF)

192.168.1.98

7SA52 (21/21N)

192.168.1.96

SA Physical Allocation

• 2 Station Computers• 2 Man Machine Interface Servers • 2 Operator Man Machine Interface (HMI)• Engineering Work Station and Fault Evaluation System• Communication Gateway (CGW)• Time and Date Server (TDS)• Station LAN• Ethernet Switches

• Main and Backup Protection Relay (87L, 21, 87B, 87T, 67, 50/51,…) • Backup Protection (Breaker Failure Protection : 50BF)• Bay Control Unit (BCU)

Process Level• Conventional Type CT/VT• Conventional Hardwire Connection

Process Level: Hard Wiring

SA Functions (1)

HMI and Related Station Level

Operator or Control Functions

Monitoring and Measurement

Protection (Main and Backup)

• Line : 87L,21,67, 50BF,…

• Busbar : 87B (Low impedance)

• Transformer : 87, 50/51, 50/51N, 50BF

• Feeder : 50/51, 50/51N, 50BF

SA Functions (2)

Automatic Functions• High Speed Automatic Transfer Scheme

• Voltage Selection

• Automatic Load Shedding

• Automatic Load Restoration

• Interlocking

• Breaker Failure Protection

• Rate-of-Change Calculations and Alarming for Selected Analog Input Variables

• Heartbeat Function

• Maintenance of TRIP Counters for Breakers

• Breaker Operating Time Checks

SA Functions (3)

Local/Remote Control and Monitor

Voltage and Var Control

Trend Records

Events, Alarm and Disturbance Records

Fault Location

Implementation of SA Chidlom Terminal Station

Substation Automation Systems

Base on IEC 61850

Energized on May 09, 2009

22

Indoor Type Substation

23

Chidlom Terminal Station Building

Primary Equipment : 230kV GIS

24

Transformer : 300 MVA

25

Primary Equipment : 69kV GIS

26

Primary Equipment : 24kV GIS

27

Mimic Board and HMI

28

Station Computers

Station Computers

• 2 Station Computers

• 2 Man Machine Interface

Servers

• 2 Operator Man Machine

Interface (MMI)

• Engineering Work Station

• Communication Gateway

(CGW)

• Time and Date Server (TDS)

• Station LAN

• Ethernet Switches

29

Bay Level : Relay & BCU Panel

30

IEC61850 Experiences

CCU#2

Station bus

Station Gateway

CCU#1HMI

Processinterface Processinterface Processinterface

Protection& Control

Protection& Control

Protection& Control

SCADA

TDSOur protective relay handles automatic,control, interlocking, metering andprotection functions, but actually anyprotective relay has its limitation andalso differ from other vendors. e.g.logic-gate capacity, processing time andfunctionalities giving us severaldifficulties and deviations from ourtechnical specification.

Protection& Control

Protection& Control

The main point is that we have torequire specific protective relaysfor sparing due to it is almostimpossible for replacing by other-vendor in no time.

IEC61850 Experiences To maintain SA as easy as possible easily changing a relay with the minimal time. easily procuring a relay as spare from multi-vendors. needing the minimal number of maintenance guys and knowledge for maintaining.

Purposed Solutions allocating the fewest functions to each device as much as possible. purchasing size of a relay as small as possible. More bigger more difference of

capabilities among vendors such as a number of reports , a number of logic gates , a number of CSWI , number of physical I/O . Consequently, in the case of the full capacity implementation of a relay, It may not be able to put all same functions of the relay to other relay of other vendor resulting in maintenance difficulties.

Preparing function compatible list (FCL) including configuration files for purchasing any spare relays

Function Compatible List (1)

Station Level

Bay Level

A B C

A

A B C

B

A B C

C

Function Compatible List (2)

Station Level

Bay Level

A B C

A

A B C

B

A B C

CMain Function Main Function Main Function

Sub Function Sub Function Sub Function

Number of Physical I/Os

Main Protection

Equipment Status by GOOSE

Back-up Protection

Equipment Status by Hardwiring

Main Protection Back-up Protection

Equipment Status by Hardwiring

Misunderstanding, proposed protective relays from a contractor may have not enough physical I/Os to supportprotection schemes with high reliability resulting in changing new protective relays and causing a project delay. Duringissue of the technical specification, MEA has found that one of the most important points is to specify minimal numberof physical I/O of any protective relay to support the required functionality making bidders have the clearest view ofwhat protective relays be proposed to MEA. Figure 2 shows two solutions that can do same functions, but they havedifferent reliability level from serial and parallel arrangements.

Sim Box

Plant Simulation Box

New Control Cable

Switchgear still is on service

During the installation process of the SA devices in an existing substation, all the automatic, control and meteringfunctions have to be tested to assure correct functioning when put in services. Due to shutdown time may be not longenough or difficult to fully perform all equipment tests causing project delay. Consequently, MEA has to use plantsimulation boxes acting as substation equipments for testing all functions shown as Figure 4. Therefore the neededshutdown time of such substation is as short as the required time for checking equipment connections whether arecorrect

Benefits (1)

Standardization

Natural Resources Reduction with

Modern Networking Technology

Cost Reduction

• More Vender Competition

• More Intelligence Functions

• One Time Investment

Commissioning and Maintenance Time Saving

37

Benefits (2)

Open System Architecture• Spare Parts Availability

• Future Extension Convenience

Information support for system planning and system analysis

Fully Automated Substation System

Stability and Reliability for MEA Network Services

Smart Substation to Support MEA future Smart Grid Project

38

Thank you for your attention.