automation in large urban power distribution system · 2019-09-02 · – wimax (pilot under...
TRANSCRIPT
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Automation in Large Urban Power Distribution System
CENTRAL TECHNICAL SERVICES, RELIANCE ENERGY LIMITED, MUMBAI
Dr. K Rajamani
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• Need for Automation and Current trends
• Automation Systems and Functionality
• REL Experience
• Best Practices
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Generation
• Bottleneck is here • Last mile reliability • Huge no. of elements • Theft • Revenue collection
Transmission
Distribution
Glamorous
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Load Demand in Mega cities
2006
Pea
k Lo
ad (
MW
)
2500 4200 656010380 13141
16680
33600
64300
Mumbai London Chicago HK NY Shanghai Osaka Tokyo
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What is Distribution Automation ?• “A set of technologies that enable an electric util ity to remotely
monitor, coordinate and operate distribution compon ents in a real-time mode from remote locations” - (IEEE definition)
• DA is an umbrella concept that embraces all the oth er real-time and operational functions for the distribution netw ork
Distribution Management (DMS)
Meter Reading(AMR)
Substation Automation (SA)
FeederAutomation (FA)
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With... …you receive ..which results to
What you get out of Automation
Remote Control Fast outage / fault management
Shorter outage times
Measurements More information from network
Accurate network analysis
Fault indication Faster fault management
Shorter outage times
Protection Actual current seen by relay
PM analysis
Quality monitoring Information on problem areas
Improved quality of power
Condition monitoring
Service information of switches
Reduced maintenance intervals
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Decision
Control
MonitoringManual &
Decentralised
Centralised
Decentralised
Centralised
Centralised
Decentralised
Centralised
Centralised
Centralised
PAST
(Manual RMU) (Automated RMU)(Manual RMU)
PRESENTSCADA
FUTURESCADA & DMS
Automation Roadmap
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Automation Systems and Functionality
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Automation Systems – Distribution Utilities
• SCADA
• Distribution Management System (DMS)
• Geographical Information System (GIS)
• Automatic Meter Reading System (AMR)
• Outage Management System (OMS)
• Communication Systems
• Billing and Business Process Automation
• Enterprise Resource Planning (ERP) Systems
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• Supervisory Control & Data Acquisition Systems (SCA DA)– Develop and integrate Real-time SCADA systems
• Distribution Management Systems (DMS)– Solutions for DMS systems for distribution utilitie s for
faster Fault Location, Isolation and Supply Restora tion (FLISR) and reduction in downtime
• Geographical Information Systems (GIS)– GIS systems for asset management
Automation Systems – Description
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• Automatic Meter Reading System
– Solutions for AMR systems for energy auditing– High end consumer load profile monitoring– Integrated with billing and other processes to redu ce
cycle time
• Communication System
– Fibre Optic (SCADA / partly DMS on Fibre)– Mobile – CDMA / GSM / GPRS (partly DMS on CDMA)– VSAT / Low Power Radio– Wimax (Pilot under progress)
Automation Systems – Description
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SCADA/DMS Functionalities• Monitoring and Control of EHV and HV network
• Fault Location, Isolation and Service Restoration ( FLISR)– To determine the location of feeder faults– Recommend actions to isolate the faulty sections & restore
supply to the healthy sections of feeders
• Voltage and VAR Control – For optimal switching of Capacitor banks and OLTC c ontrol
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Typical Integrated Solution – Distribution Utility
SCADA/DMS
CIS(Customer
Information System) GIS
AMR(Automatic Meter Reading System)
ERP system(SAP R/3)
OutageData
Trouble tickets
Maps, Equipment Data
Load Profiles
CustomerData
System & Equipment faults, Switching counts
Equipment Data
Billing & Settlement
Status data
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Present Operations
Circuit Breaker
R/S feederR/S feeder
Normally open point
RMU / DT
R/S feeder
Circuit Breaker
R/S feeder
Normally open point
Supply restored manually for part network typical
time 15 – 20 mins
Circuit Breaker
R/S feederR/S feeder
Normally open point
RMU / DT
CB Trips on fault
Circuit Breaker
R/S feederR/S feeder
Normally open point now closed manually
Additional network restored
manually, total time 40 mins
Faulty Section
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Automation Philosophy
Circuit Breaker
R/S feederR/S feeder
Remote operation to close switch
Additional network
restored, total time 11-18 mins
Circuit Breaker
R/S feederR/S feeder
Normally open point
Automated RMU / DT with FPI
Circuit Breaker
R/S feederR/S feeder
Normally open point
FPI indicates passage of
fault current
CB Trips
Circuit Breaker
R/S feederR/S feeder
Normally open point
Remote Operation of RMU Switch &
Partial Restoration of supply –
typically 1-2 mins
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Post RMU, FPI & Automation Scenario
11 KV 11 KV
415 V
DMS
Total Fault Restoration time
reduced from 65 to 35 minutes
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REL Experience
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REL MUMBAI DISCOM
� Total load served – 1400 MW
� Number of consumers – 25 lacs
� Area of supply - 384 sq. km
� No of Receiving stations – 61 (22kV or 33kV / 11 kV)
� No of substations – 4900 (11 kV / 415 V)
� Average availability (ASAI) – 99.92%
� Distribution loss (T & D) – 12%
� 33kV Cable Network – 400km
� 11kV Cable Network – 2400km.
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Approach
SCADASCADASCADASCADA
DMS DMS DMS DMS ApplicationsApplicationsApplicationsApplications
Integration with Integration with Integration with Integration with other business other business other business other business
processesprocessesprocessesprocesses
Network power flowSwitching procedure management
Fault isolation & service restorationVolt /VAR control
Capacitor bank control
Centralised data acquisition andControl / intelligent load shedding /
energy balance/Alarm & event handling/Historian/ Trending/Reporting
Integration with other systems (ERP / GIS /
AMR)
Priority
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• System integration and data engineering– DIAS/OPC DMS/GIS Interface
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DMS Implementation in REL
• Automate 20% of RMU (1000 out of 5000 substations)
• Installation of FRTU
• Integration of RMU with FRTU
• Selection of Communication Technology 150 Substations – CDMA; 20 Substations – Fibre
• System integration and data engineering
• Installation of Fault Passage Indicator
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Fault Passage Indicator (FPI)
• Earth Fault Indicator for underground cables.
• Detects earth faults only and helps in locating faulty cable section.
• Phase to phase faults will not be detected.Majority(>70%) – Earth faults
• Composed of:- Sensor - Split core CBCT- Indicator
CBCT
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Logic for Identification of faulty section with FPI
Conclusion: Fault is in the section between a glowing FPI and a Non glowing FPI
CB Trips
All FPIs glow
R/S feederR/S feeder
Normally open point
FPI shall not glowAutomated RMU
FPI indicates passage of
fault current
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• Integrated view of Generation, Transmission and Dis tribution
• Centralized remote monitoring of network elements
• Centralized remote control of switches and transfor mers
• Reliable Islanding after grid collapse and Optimal load sheddingafter islanding
• Network reconfiguration and load transfer switching performed remotely for most situations.
• Centralized storage of event logs, fault analysis a nd report generation.
REL Mumbai Distribution System - Experience
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• Real-time alarm on a network fault or abnormality
• Better assistance to field staff in pin-pointing fa ulty section by
utilizing FPIs at all DT stations ���� Reduction in time for fault
identification
• Interruption time reduced from 40 mins to 5-20 mins on an
average.
• Reduction in customer hour loss by 50%
• Improved power supply quality due to reduced test c harges.
• Equipment subjected to less stress ���� better equipment condition
REL Mumbai Distribution System - Experience
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Effect of DMS is reflected in Customer Average Inte rruption Duration Index (CAIDI) apportioned to HT tripping
599,376
577,010
No. of consumers
50.24103Post DMS(Y-2007)
95. 16102Pre DMS(Y-2006)
CAIDI in minutes
No. of HT Trippings
Central Zone (Jul-Sep)
Reduction in CAIDI by 50%
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Daily Operations at REL, Aarey BCC
• Tap changing operations from SCADA : 350 per day
• No. of breaker (switching) operations : 290 per day { 8700 operations per month – one of the highest
in the WORLD }
• No. of Isolator operations through DMS – 1000 per mo nth(During floods 120 operations per day!)
• Cable fault isolation
• Load transfer operation
• Capacitor switching in / off for power factor impro vement
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Best Practices
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Best Practice…General
• Phased Implementation– SCADA with Some Applications– Selected DMS Applications– Enterprise Integration
• Follow International Standards
• Flexible and Open Architecture
• Minimize Customization
• Disaster Recovery Capability
• No Single Point of Failure
• Selective Feeder Automation
• Establish Quality Indices Goals and Track Them
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Best Practice…Operation Criteria for SCADA
• All Grid Substations Unmanned with Central Decision Making Processes
• Decision Making based on Real-Time Accurate and Consistent Information
• Remote Control of all Key Field Equipment Devices
• Selected Distribution Substations (11kV/415V) contr ol
• Monitoring of All Data Required to Support continge ncies
• Monitoring of Power System Equipment (condition monitoring)
• Remote Monitoring of protective relay data
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Best Practice… Communication Criteria
• No Loss of Information due to Single Point Communic ation Failure
• Automatic Routing of Field Data to Active System in case of Communication Failure
• Transparent routing of users to active control syst em
• All communications on TCP/IP using standard protoco ls (i.e. IEC 104 )
• Maximum use of available bandwith for other uses su ch as video and voice transmission
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What can go wrong?
• Overly ambitious goals – too many features
• Inadequate specification
• Unclear objectives
• Not ready with data to kick start the project
• Lack of know-how within organization
• Poor implementation (SCADA/DMS adaptation)
• Lack of training
• Primary equipment compatibility
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SCADA
11 KV 11 KV
415 V
DMS100 MVA
20 MVA
33 kV
11 kV
220 kV
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11kV VOLTAGE PROFILE
0
1
2
3
4
5
6
7
8
9
10
11
12
0:00:00 2:24:00 4:48:00 7:12:00 9:36:00 12:00:00 14:24:00 16:48:00 19:12:00 21:36:00 0:00:00
Time
Vol
tage
in k
V
(+) 2%
(-) 2%
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Aarey BCC
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DMS STATION MODEL
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Thank You
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Geographic Information System - GIS
GIS asset information integrated by other business processes
Customer Interface, Marketing, Logistics
Site selection, Routing
GIS
Outage Management SystemOptimalSwitching
SCADA
IVRCIS
Internet / Intranet
Network Analysis
Assets Management, Land Records, RoW
Work Management System
Planning, Engineering & Progress Monitoring
SAP Integration
O & M, Crew Dispatch and Inspections
Energy Audit
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Metering Solutions – AMR Systems
Last Mile
Telephone / PLC
Telephone
Main Control Centre
Meter Interface Units
Master Data Concentrators
Sub – Data Concentrators
Information Portals
AMR systems for energy audit / billing / consumer profile monitoring
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Typical System Architecture : SCADA/DMS
WAN (SDH)
MCC BCCMCC –BCC- RTU links
IEC 104 RTU
Front EndFront End
CDMAModem
ModemModem
Serial links 9600 Baud
(45)(15)(200)
Serial link 9600 Baud
(55) (55) Serial link 9600 Baud2 Mbit 2 Mbit
2Mbit
IEC 101 RTU
IEC 104
FRTU
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CDMA Network
DAKC
MIDC HUB
MIDC SDH
BCC SDH
DMS FEP
2 Mbps Link
BCC
RMU RMU
FRTUFRTU
CDMA Modem
CDMA Modem
DMS Architecture
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SCADA System
DAHANU TPS
220kV
11kV OUTGOING
33 kV
11 kV
TransmissionSCADA
DistributionSCADA
( 4 EHV Stations )
( 61 Rec. Stations )
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� Load Shedding & Islanding Logic from Centralized Lo cation
� Redundant LAN
� Enhanced Communication System – Fault tolerant, Fast er,
scalable
� Centralized Control Concept for all Divisions
� IED Integration – Numerical Relays of all makes, Dig ital RTCC
� Inbuilt DMS Application extended to 11 kV Sub Trans mission
Network
� Data mining of SCADA database to unearth valuable i nformation
� Interface with other tools – GIS, SAP, CIS System
REL SCADA System - Highlights
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Recorded Fault Current
Trip Indication
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Conventional RTCC panel 600mm (W) x 600mm (D) x 2000mm (H)
Digital RTCC 250mm (W) x 100mm (D) x 300mm (H)
DIGITAL RTCC
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SUBSTATION
Wireless Network
DAKC
MIDC HUB
MIDC SDH
BCC SDH
DMS FEP
2 Mbps Link
BCC
RMU
FRTU
Wireless LAN Switch
BTS
BTS
BTS
MCNMUMBAI
BA RING
MA RING
BTS – Base Station
BA Ring - Building Aggregation RingMA Ring – Main Aggregation Ring
MCN – Media Convergence Node
Antenna
Antenna
Wi Max Technology
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Cost Per Substation for DMS Implementation
• Automated RMU supply and Installation - Rs. 12 lacs
(US$ 30,000)
• Automation including FRTU, Modem,
Hardware and software at Control centre - Rs . 2 lacs
(US$ 5,000)
COST OF AUTOMATION APPROXIMATELY
20% OF PRIMARY EQUIPMENT COST!
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REL 220kV Network
DAHANU
GHODBUNDER
VERSOVA
AAREY
TATA -BORIVALI (GRID)
S S
GT#116.5/220kV
GT#216.5/220kV
GEN#1250MW
GEN#2250MW
MSEB -BOISAR (GRID)
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REL’s ISLANDING & LOAD SHEDDING SCHEME
• REL islands from grid under following conditions:� Reverse power with under frequency (47.9Hz) � Steep fall in frequency ie. 49Hz + 0.5Hz/sec.
• Post islanding, load shedding is done to match load wi thavailable generation.
• Different load shedding schemes are implementeddepending on GT and tie line breaker status.
• Load shedding is done based on the set priority table.
• Real time tie line power flows, generator output and loa d are considered for load shedding.
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REL 220kV Network
DAHANU
GHODBUNDER
VERSOVA
AAREY
TATA -BORIVALI (GRID)
S S
GT#116.5/220kV
GT#216.5/220kV
GEN#1250MW
GEN#2250MW
MSEB -BOISAR (GRID)
REL ISLANDED!
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SCADA/DMS LAN
REDUNDANT APPLICATION SERVER
(SCADA/DMS/ICCP)
CORPORATE LAN & WEB SERVER
WORK STATION
DMS FEPREDUNDANT SCADA FEP
REDUNDANT
UDW SERVER
ROUTER
FIRE WALL
GIS GATEWAY