Smart Substations
in MEA’s Distribution System
Pichit Jintagosonwit
Smart Grid
Electrical Infrastructure + Intelligence Infrastructure
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
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 Roadmap
Stage 2
Stage 1
2017 – 2021
2012– 2016
Large Scale
Implementation
Laying the Foundations
Stage 3
2022 – 2026
Ultimate Stage
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
Power
System
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
Substation + The Latest Information Technologies
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.
IEC61850 Messaging (1)
IEC61850 Messaging (2)
3-Bays BTO Function (1)
Subtation
3 Bays-BTO
27
Auto
Termainal
Station 1
Termainal
Station 2
L1
L2
Bus A
DS1A
BCA
DS2A
BC
DS1B
Bus B
2
1
2
Do not Close due to Tr.2
may be overload
BCB
DS2B
3-Bays BTO Function (2)
Subtation
3 Bays-BTO
27
Auto
Termainal
Station 1
Termainal
Station 2
4
L1
L2
Bus A
DS1A
BCA
DS2A
BC
DS1B
Bus B
2
1
2
3
BCB
DS2B
Smart Substation for Smart Grid
Because of TCP/IP, Switch, IEC61850 technologies
 Supporting future grid applications in scale of baylevel 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)
LTF (1)
Inline Substation
Open-loop Substation
Managed Switch
Managed Switch
IP Network
IED with
LTF function
IED with
LTF function
LTF (2)
Inline Substation
Open-loop Substation
From Terminal
Station 1
From Terminal
Station 2
Auto
1
27
27 Trip
2
Delay of 0.2 Sec
L1-A
3
L2-A
DS1A-A
BCA-A
DS2A-A
BC-A
DS2B-A
BCB-A
DS2B-A
L1-B
L2-B
DS1-B
DS2-B
DS-B
4
Consolidation Concept
Smart Substation > Substation Automation
SCADA
HMI
CCU#1
CCU#2
Station
Gateway
TDS
Station bus
Protective
Relay
Protection
& Control
Processinterface
BCU
Protection
& Control
Protection
& Control
Processinterface
Bay control
Bay control
Processinterface
Typical System Topology
Engineeri
ng
Portable
MMI
DCC
Station Computers
CCU#1
GPS
HMI
Gatewa
y
With
Firewall
(CGW)
CCU#2
Switch
Line Bay
Switch
Station Level
TDS
Switch
Trans. Bay
Switch
BS/BC. Bay
Switch
Line Bay
Switch
Trans. Bay Switch
LAN B
LAN A
Main
21/21N,
27/59,
79, 50BF
Main
87
67/67N,
27/59
50BF+
BCU
50/51,
50/51N,
50BF+B
CU
115/69kV
50/51,
50/51N,
50BF+B
CU
Main
21/21N,
27/59,7
9,50BF
Main
87
67/67N,
27/59
50BF+
BCU
50/51,
50/51N,
50BF+B
CU
Bay Level
14
Substation Automation (SA)
Substation Automation (SA)
SICAM PAS
Station Unit
Station-LAN:
IEC 61850; Ethernet 100 Mbps
Fibre Optic Double Loop with
redundancy function
7UT61 (87T)
192.168.1.82
7SJ61 (50/51)
192.168.1.83
7SJ61 (50BF)
192.168.1.84
7SA52 (21/21N) 7SD61 (87L)
192.168.1.85
192.168.1.86
7SJ61 (50BF)
192.168.1.87
7SJ61 (50/51) 7SJ61 (50BF)
192.168.1.88 192.168.1.89
230 kV Switchgear
Power Transformer
No.1
7UT61 (87T)
192.168.1.90
7SJ61 (50/51)
192.168.1.91
7SJ61 (50BF)
192.168.1.92
Line Incoming
No.1
7UT61 (87T)
192.168.1.93
7SJ61 (50/51)
192.168.1.94
Bus Coupler
7SJ61 (50BF)
192.168.1.95
7SA52 (21/21N) 7SD61 (87L)
192.168.1.96
192.168.1.97
7SJ61 (50BF)
192.168.1.98
230 kV Switchgear
Power Transformer
No.2
Power Transformer
No.3
Line Incoming
No.2
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
Chidlom Terminal Station
Building
23
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
SCADA
HMI
CCU#1
Our protective relay handles automatic,
CCU#2
control, interlocking, metering and
protection functions, but actually any
protective relay has its limitation and
also differ from other vendors. e.g.
logic-gate capacity, processing time and
functionalities
giving
us several
difficulties and deviations from our
technical specification.
Protection
& Control
Processinterface
Protection
& Control
Station
Gateway
TDS
The main point is that we have to
Stationrelays
bus
require specific protective
for sparing due to it is almost
impossible for replacing by othervendor in no time.
Protection
& Control
Processinterface
Protection
& Control
Protection
& Control
Processinterface
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
A
A
B
Bay Level
B
C
A
B
C
C
A
B
C
Function Compatible List (2)
Station Level
A
A
B
Sub Function
Bay Level
B
Main Function
C
A
C
Main Function
B
Sub Function
C
A
Main Function
B
Sub Function
C
Number of Physical I/Os
Misunderstanding, proposed protective relays from a contractor may have not enough physical I/Os to support
protection schemes with high reliability resulting in changing new protective relays and causing a project delay. During
issue of the technical specification, MEA has found that one of the most important points is to specify minimal number
of physical I/O of any protective relay to support the required functionality making bidders have the clearest view of
what protective relays be proposed to MEA. Figure 2 shows two solutions that can do same functions, but they have
different reliability level from serial and parallel arrangements.
Main Protection
Main Protection
Equipment Status by GOOSE
Back-up Protection
Equipment Status by Hardwiring
Equipment Status by Hardwiring
Back-up Protection
Sim Box
During the installation process of the SA devices in an existing substation, all the automatic, control and metering
functions have to be tested to assure correct functioning when put in services. Due to shutdown time may be not long
enough or difficult to fully perform all equipment tests causing project delay. Consequently, MEA has to use plant
simulation boxes acting as substation equipments for testing all functions shown as Figure 4. Therefore the needed
shutdown time of such substation is as short as the required time for checking equipment connections whether are
correct
Switchgear still is on service
Plant Simulation Box
New Control Cable
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.