WELCOME TO A PRESENTATION ON DISTRIBUTION AUTOMATION S.PRATAP KUMAR

1. WELCOME TO A PRESENTATION ON DISTRIBUTION AUTOMATION S.PRATAP KUMAR DIRECTOR TRANSMISSION, KPTCL, BANGALORE

2. What is Distribution Automation

3. Function of Distribution Automation System Remotely monitors the distribution system, facilitates supervisory control of devices and provides decision support tools to improve the system performance • SCADA • (Supervisory Control And Data Acquisition) • Application Functions

4. Meter Substation Reading (AMR) Automation (SA) What is Distribution Automation ? • “A set of technologies that enable an electric utility to remotely monitor, coordinate and operate distribution components in a real-time mode from remote locations” - (IEEE definition) • DA is an umbrella concept that embraces all the other real-time and operational functions for the distribution network Distribution Management (DMS) Feeder Automation (FA)

5. Need for Automation and Current trends

6. What you get out of Automation With... …you receive ..which results to Remote Control Shorter outage times Fast outage / fault management Faster fault management Shorter outage times Fault indication Protection Actual current seen by relay PM analysis Measurements More information from network Accurate network analysis Quality monitoring Information on problem areas Improved quality of power Condition monitoring Reduced maintenance intervals Service information of switches

7. AutomationSystems and Functionality

8. 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

9. Automation Systems – Description • Supervisory Control & Data Acquisition Systems (SCADA) • Develop and integrate Real-time SCADA systems • Distribution Management Systems (DMS) • Solutions for DMS systems for distribution utilities for faster Fault Location, Isolation and Supply Restoration (FLISR) and reduction in downtime • Geographical Information Systems (GIS) • GIS systems for asset management

10. Automation Systems – Description • Automatic Meter Reading System • Solutions for AMR systems for energy auditing • High end consumer load profile monitoring • Integrated with billing and other processes to reduce cycle time • Communication System • Fibre Optic (SCADA on Fibre; Pilot for DMS completed) • Mobile – CDMA / GSM / GPRS • VSAT / Low Power Radio • Wimax (Pilot under progress)

11. C SCADA/DMS Functionalities • Monitoring and Control of EHV and HV network • Distribution Network Power Flow • To execute real-time power flow studies for optimal switching • 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 • Switching Procedure Management • To execute switching orders and inverted switching orders • Voltage and VAR Control • For optimal switching of Capacitor banks and OLTC control

12. SCADA/DMS Functionalities • Outage Management System (OMS) • Keep records of forced and planned outages • Load shedding and restoration • Short Term Load Forecasting and Calculation of Quality Service Indices • Optimal Feeder Reconfiguration (OFR) • Judicious network switching to reduce losses and voltage problems • Energy Balance • - Gives insight into the energy flow and losses in the network

13. Status data CIS (Customer Information System) Customer Data Maps, Equipment Data GIS Trouble tickets Outage Data SCADA/DMS Equipment Data System & Equipment faults, Switching counts Load Profiles ERP system (SAP R/3) AMR(Automatic Meter Reading System) Billing & Settlement Typical Integrated Solution – Distribution Utility

14. Key Design Parameters – SCADA/DMS system • User Interface Response Time • Communication Media • Type, Frequency and Quantity of Data Flow • Data flows between different elements of the SCADA / DMS network • RTU – SCADA / DMS communication • High load and Burst load scenarios • Hardware sizing (SCADA / DMS servers, RTU) • Scalability for future expansion • Data flows between SCADA / DMS and other IT systems

15. Levels of Automation Substation Level Automation Feeder Level Automation Customer Level Automation

16. Operational problems and Potential Applications of DAS • Fault location, isolation and Service Restoration • Maintaining good voltage profile • Load Balancing • Load Control • Metering • Maintaining Maps • Fuse-off call operations • Energy accounting Recent Buzz words !! Outage Management Customer Information Management

17. Candidate Distribution Automation Functions

18. Application Functions • Network Reconfiguration a) Fault localization b) Service Restoration c) Load Balancing • Integrated Volt-Var Control • Remote Metering • Automatic Load Shedding • Load Management • Automated Mapping and Facilities Management (AM/FM) • Trouble Call Management System (TCMS) • Load Survey and Energy Accounting

19. Considerations • Presence of alternate paths • Operation of LB switches • Need to have remotely controllable switches • Restoration based on • - satisfaction of current and voltage constraints • - minimum switches • - minimum losses Network Reconfiguration - Service Restoration • Restores service to non-faulty feeder sections by reconfiguration

20. Composition and hence consumption patterns of loads on • different feeders are different • To distribute loads among transformers/feeders • Remote control of switches for reconfiguration Network Reconfiguration - Load Balancing

21. Applied on feeders with capacitors and voltage regulators • Control of capacitor banks and voltage regulators • Schedule for switching and tap control • To meet reactive power requirements and reduce losses Integrated Volt-Var Control

22. Automatic Load Shedding • Under Frequency based load shedding • Sensing Frequency through transducers • Load shedding based on the frequency drop, current loading • conditions and priority of the load • Closed loop function at RTU level

23. Load Management - Emergency based load shedding • Gap between power generation and load demand due to • sudden contingencies • To shed the loads based on the relief required • Identification of loads to be shed based on • - current load magnitudes • - priority of the load • - time when last shed • Shed the load based on the above factors

24. Trouble Call Management System (TCMS) • Responds to customer complaints • Acceptance of interruption/restoration data from the operator • Distribution Transformer trip/close info from SCADA • Determination of source of interruption • Improvement of response time to customer complaints

25. Load Survey and Energy Accounting • Availability of continuous data on loads etc., • Determination of Load Patterns • Data for planning • Detection of abnormal energy consumption pattern • Identification of high loss areas

26. Reduction in O&M Costs of Breaker • switching for: • Routine Operations • Non-Routine Operations • Reduction in O&M Costs of: • Fault Location and Isolation • Service Restoration • Routine Switching Operations • Recloser Setting • Recloser Testing • Data Collection • Data Analysis • Feeder Reconfiguration • Capacitor Banks Inspection • Increased Revenue Due to: • Reduction of System Peak Load • Tamper Detection to Reduce • Electricity Theft • Reduced Payments for Customer • Claims • Reduction in O&M Costs of LTC • Operation for: • Routine LTC Operations • Non-Routine Operations • Reduction in O&M Costs for: • Routine Relay Testing • Relay Setting • Increased Revenue Due to: • Loss Reduction due to Feeder • Reconfiguration • Loss Reduction due to Capacitor • Banks Automation • Faster Service Restoration • Reduction in O&M Costs of: • Routine Data Collection • Non-Routine Data Collection • Data Analysis • Testing of Data Logging Devices • Repair of Data Logging Devices Tangible Benefits Customer interface Automation Feeder Automation Substation Automation • Reduction in Capital Expenditure • due to: • Deferment of additional substation • facilities • Effective utilization of substation • facilities • Reduction in O&M Costs of: • Regular Meter Reading • Reprogramming of Meters • Service Connect/Disconnect • Processing of Customer Claims • Reduction in Capital Expenditure • due to: • Deferment of additional feeders • Effective utilization of existing • feeders

27. Bangalore Distribution Automation System

28. Load Profile of Bangalore Metropolitan Area Existing Demand of Bangalore Metropolitan Area is 1437 MWS Bangalore is the fastest Growing city in the country Studies conducted to forecast future Load Requirement Load of Bangalore will be doubled by 2011-12 Projected Demand of Bangalore by 2011-12 is 2428 MWS Power Supply Reliability The present Reliability Index in Bangalore City is 99%. Annual Average consumer hours lost due to 11kV feeder interruption - 64.57 Hours 66kV feeder / sub-station – 20.22 Hours DTC / LT interruptions – 1.43 Hours. Total 86.2 Hrs/Year/Consumer Need of Distribution Automation in Bangalore City

29. Need of Distribution Automation in Bangalore City • Bangalore is the most potential location for software business, IT Enabled Services & Biotech owing to its inherent strength. • Majority of IT activity not only in the State but also in the country is concentrated in Bangalore. • Bangalore has been at the forefront of industrial growth in India with enterprising citizens – ideal choice for investment infrastructure. • Bangalore refer to as the Silicon Valley of India accounts for highest software exports in the Country. • Bangalore City Contributes more than 70% of BESCOM total revenue. • Support from State Government for foreign Investment. • Electronic equipment manufacturing as well as Garment industries are developing in Bangalore City. • In rush for investment from foreign investors. • Increased Demand from Residential Layouts • Demand due to establishing new International Airport

30. Scope of the Works in Bangalore DAS • Drawing 11kV new lines with Coyote ACSR conductor to suit the overhead system for distribution automation. • Providing 11kV, 400 Sq mm UG/AB cable to suit the overhead system for distribution automation. • Retrofitting of existing RMU Operating Devices (OD) with VCB’s and providing motorized mechanism. • Providing motorized mechanism for Vertical Lines (VL) and OD’s of new and old RMU’s. • Providing compact RMU’s for spur points of overhead lines. • Providing sectionalizers with communication facility between two VL’s. • Providing Remote Terminal Units (RTU) with communication facility at all RMU locations. • Providing SCADA system at each of the sub-station with necessary hardware and software. • Establishing Master Control Center at Corporate level with necessary communication, hardware and software.

31. The Bangalore Distribution Automation System aims at achieving • Control of 11 KV feeders • Operation of line sectionalisers, motorised isolators, auto reclosures • Data acquisition from load end CTs and PTs • Operation of CBs for switched capacitor banks • Use of customized EMS Software packages with real time data collected through RTUs • Issue, control and receiving back of line clears, introduce interlock and safety algorithm, password protected operating environment • Real time logging of data / archived records of hours of service,Equipment data base • Integration with Geographical Information System (GIS) Software packages

32. System Configuration of DAS

33. Integrated Distribution Automation system • Real time control over the costly energy sold. • Improved efficiency results in lower costs, • Better reliability in power supply, planned control actions, • Optimum power factor, reduction in losses. • Improved efficiency also results in reduction of the Green House gases and consequent improvement in the environment. • Enables online energy audit (AMR Systems) which is now receiving the focused attention of all utilities

34. Project Implementation • The project will be implemented in Phases. • Under Phase I, as a pilot project Peenya Industrial Area, EPIP area and Electronic city area are identified. Completion period 6 months. • In the second Phase BESCOM is planning to take up the Distribution Automation of the entire existing RMUs (Cable network) along with the improvements required for overhead distribution to suit the overhead system for Automation. Completion period 9 months. • Under Phase III, BESCOM is planning to take up the Distribution Automation of the entire over head network. Completion period 9 months. • Total Cost of the Project is about 563 Crores. • The Japan Bank for International Cooperation (JBIC) is extending financial assistance for this project