ISGF TECHNOLOGY SESSION (Last Mile connectivity in Smart Grid)

1. ISGF TECHNOLOGY SESSION(Last Mile connectivity in Smart Grid) “Regulatory Perspectives on Distribution Automation” Vijay L Sonavane ME(Elect.) Member(Tech) MERC Mumbai 400 005 Date: 1st June 2012

2. Maharashtra Power System • Area :3.08 L Sq. km, 40,615 Villages & 457 Towns, 121 M Citizens • Installed capacity: 24000 (+) MW • Daily Demand met: 325-375 MU • 4 DL, 3 GENCO, 4TRANSCO, 3 JV TRANSCO • 22 M Customers (3.4M Ag Pumps) • ARR: Rs 60,000 Crores • Demand Growth: 8% • Dist Losses: MSEDCL: 16.8% & Mumbai Utilities: 7-9.5 % • Load shedding free by Dec 2012

3. Existing Grid Operation in Maharashtra • Centralized Generation disseminated via a relatively passive limited control • Limited two- way communication between utilities & end users • Many Slow Analog & Electro Mechanical legacy systems (prone to failures leading to black outs)

4. Thomas Edison & Present Grid System “He has been dead for more than 75 years, but Thomas Edison- hailed as father of Electric blub- probably could have run the Nation’s modern day Electric Grid- It has not changed much” - Denver Business Journal (Mar. 2007)

5. EA 2003: Mandate for Reforms • An Act for taking measures conducive to • Development of electricity industry, • Promoting competition therein, • Protecting interests of consumers • Promotion of efficient & environmental friendly policies • S 61 (c): “ Commission…. shall be guided by the factors which would encourage competition, efficiency, economical use of resources, good performance & optimum investments”

6. Regulator’s Concern • Key Regulatory concepts: • “Prudent” management decisions • “Used & Useful” Technology • “Least cost/Least risk” • Investment approval only if it enhances service quality & Reliability/Efficiency • Cost Recovery more likely if: • Technology is proven & benefits are certain

7. Example for impact on Tariff (Consider a utility with ABR=Rs 4 PU & 10000 MU sale Rs 87 Cr additional ARR means PU tariff rise 8.7 Ps)

8. Difference in Objectives of Regulators & Innovators • Regulators set tariffs based on known cost & proven technology : to protect consumers from tariff shock • Regulators are Risk-averse: (strong disliking) “It’s the second mouse that gets the cheese”, first having proved its use. • Innovators seek capital to bring new technology to market & reap benefits of being an “early mover”. • Innovator: Risk-taker: “It’s the early bird that gets the worm”

9. Key issues in front of Regulators(Agent of “CHANGE”?) • What is Distribution Automation? • Is Dist Automation helpful for system? • Is technology sufficiently mature? • Whether DA Investments are prudent? • Who should bear “dry hole” risk? Main players of Dist Automation Market: Utilities/ Electricity Consumers/R&D Institutions/ Equipment Vendors & System integrators/ & REGULATORS

10. Distribution Automation (IEEE Definition) • “A system that enables an electric utility to monitor, coordinate & operate Dist components in a real-time mode from remote locations.’’ • WHY AUTOMATION?: • Improvement of Efficiency/ Reliability/ Quality of supply • HOW? By Using advanced communication & IT systems • Decision making feature of DA distinguishes it from the normal SCADA system. • BENEFITS OF AUTOMATION: • Released capacity/ Reduced Dist losses • Increased Service Reliability (Regulatory requirement). • Life Extension of equipments / Effective utilization of Assets

11. Dist Automation Functions • MONITORING FUNCTIONS:Meter reading/ System & equipment status/ Unusual events • CONTROL FUNCTIONS: Switching operations/ Feeder sectionalizers/ Change of settings/ Capacitor bank control /Voltage Regulators/ Protective equipment • PROTECTION FUNCTIONS : Over current protection/ Distance protection/ Differential protection • Dist Automation Sub-system CATEGORIZATION: Information management/ Reliability management/ Efficiency management/ Voltage & VAR management/Load management/ Power quality management

12. Need for DA in Indian Utilities. • T&D losses: 24%. DT failure Rate: 10-15% per year • DT failure: Due to non-availability of DT health parameters & its loading conditions. • O&M of Dist system: Non-availability of system topological information, current health information of Dist components • Lack of use of efficient tools for planning & quick detection of fault & service restoration • GOI’s positive step: Restructured Accelerated Power Development & Reforms Program (R-APDRP): Objective to introduce DA with IT solutions for better Management & Control of Dist system .

13. Attributes of Dist Automation • Acquire , distribute, Manage, correlate & share large amounts of real-time data & non-operational data • Enhance network security of real-time & non-operational data • Perform functions of several individual devices by one device (reduce Capex) • Utilize modern S/S communication solutions (reduce costs) • Support reuse of legacy equipment by communicating with existing devices & adding new functions on integrated devices (reduce Costs) • Monitoring of S/S equipment & feeders • Implement expandable scalable architecture to meet future physical & functional requirements (reduce life cycle costs )

14. Feeder Automation • Dist S/s Automation  Feeder Automation • By acquiring data & automating responses on feeder: Reliability to end customer significantly improves • Functions: • Voltage & load measurement, • feeder protection, • auto-sectionalizing, auto-restoration, • VOLTAGE/VAR control, • power quality monitoring & auto-restoration (in communications with other equipment) & load shedding.

15. Dist Transformer & other equipment Monitoring • Monitor DT load, Oil & winding Temp • Check Health of DT using DG Analysis • Controlled loading on Xmers under emergencies Reclosers & breakers: • Change settings remotely • Record energy interrupted by contacts/ • Refurbish contact only when necessary • Labour & parts savings/ Capacitor switching for voltage & VAR control • On Load-tap-changer & Voltage regulator control

16. Regulator’s views: How DA Can Help Dist. System in Maharashtra? • Effective Load Management: As Real Time info is available, LM can be effective. DR Scheme can also be implemented. • Solar & RE Issues: Wind/Solar power is infirm (can not be predicted). What happens when 20 % homes in a neighbourhood go solar & a cloud passes overhead?: Grids have trouble accommodating that two-way, intermittent flow. With too much solar/RE power: Local grid voltage could rise, Control can be effective through DA • Electricity Pilferage by meter tamper & Unauthorized tapping: DA gives real time alert in case of Pilferages.

17. Regulator’s views on DA: Risks • High capital costs: Communication network & large hardware costs: Investment approval needed • Software integration risk: Establishing Common Standard Interoperability: Comm. Protocol • Sharing of Benefits to customers & Utility due to: Loss reduction & efficiency improvements • Large scale integrated pilots needed in Metro cities. • Only after sharing pilot learning, there can be reduction of risk premium on capital & operating cost levels. • Integration of Distributed Gen, RE Gen & Captive Gen • IT enablness in Rural area: Communication issues

18. Case Studies: DA Initiatives in Maharashtra (Data Centre & Customer Facilitation Centre in MSEDCL)

19. Current Meter Reading Methods in MSEDCL • CMRI for HT & High value LT Customers • Dom : Low Revenue: Photo Meter Reading • Technology proposed – AMR • Common Frame Work developed • Protocols used: IEC 62056/21 • AMR Coverage : Feeder Meters, HT Consumers & DTC Meters& LT Commercial consumers (over 100,000 Customers) • Total Customers: 20 Million (+)

20. GIS Field Survey/Modem installations

21. New Technology initiated in Energy Metering • Meters with Infrared Ports: Rural Consumers • Meters with Low Power Radio Frequency Modems: Urban Consumers • Frequency : Free 2.4 GHz Global Band at 250kbps • Protocol used for RF Modems IEEE 802.15.4 Standard ZigBee • Pre-paid Meters with RF Modules: Online Recharge • Common Meter Protocol for Hand Held Units developed • Advantage: Single hand held Machine for Different Types of Meters (1/3 PH) & Different Make of Meters

22. R-Infra D Case Study Network Focus : State-of-Art Systems • State-of-the-Art Dist SCADA (certified ISO 27001) • Dist Management System • Integrated GIS • Remote Substation monitoring • Fault Passage Indicator & Relay intelligence • Faster Detection of faulty Section • Enhancing Equipment Life • Reduced voltage fluctuations Leading to a System Reliability of 99.98%

23. Equipment Monitoring System (EMS) (R-IN D) INTELLIGENT BLACK BOX FIRE- ALARM CAMERA FPI APFC TRANSFORMER SWITCHGEAR CONTROL-ROOM OIL TEMP. / LEVEL FIRE / INTRUDER ALARM FPI & SWITCHGEAR MGMT. AMR / APFC CONTROL DETECT MOTION / CAMERA OVERLOAD / PHASE IMBAL A TYPICAL SUB-STATION Future – Smart Substation monitoring- Predictive Approach

24. Technology for Meter reading (R-Infra D) • Grid Meters / Feeder meters/ DT Meters/ HT Consumers: AMR enabled: • AMR: Load forecasting, EA , LM, Equipment health monitoring/ Value added customer services/ Theft detection module • Near 100% Electronic Meters for LT Consumers • Over 100,000 meters read daily with (accuracy 99.7%) • Meter Reading date reminders Over SMS/On Energy Bill NEW METER INSTALLATION METER READING Tamper Evident electronic meter MRI enabled Built-in validations Time < 7 days Easy and Quick Mapping on GIS Reduced errors

25. TPC-D Dist Automation System • DA in all 17 DIST SS & 238/ 507 Consumer SS (FY 2005) • Remote control of all connected DSS & CSS • Monitoring of equipment status & analog values • Alarms & event logs with time stamping • Dynamic network coloring for indicating live & dead network • Server level redundancy / work Station at PSCC & zonal control centers. (ML, SAKI, BRVLY, VKRLY, SLSTE, DHRVY) • Success rate of remote operations thro’ DAS: 98% • Loss of Communication link/ CDMA & Modem related issues • Replacement being planed in FY 2013 to cater growing requirements & advanced features (LF/SE/Optimization)

26. DA in BEST Undertaking • DT Metering : 87 % of completed. • ALSTOM make SCADA at RSS level: WIP •  At 11 RSS, local level SCADA system is ON. Balance 23: WIP • Total DSS: 400 Nos. (RTU: Measurands/ Indications) • 115 DSS SCADA equipments Commissioned • DA Project: Orders on M/S R.F ARRAYS M/S EASUN RAYROLE • Control Centre at BackbayVeejBhavan & Pathakwadi • Communication link is  ZIG-BEE wireless 2.44 GHZ with router/repeaters.

27. Distribution System Reliability • System Reliability & Customer Satisfaction depends on: • No. of momentary & sustained interruptions • Duration of interruptions • No. of Customers interrupted • Reliable system: Regulatory requirements • Need: Maintenance scheduling & Resource allocation • Planning systems for future based on Reliability indices. • SAIFI (System Average Interruption Frequency Index) • SAIDI (System Average Interruption Duration Index) • CAIDI (Customer Average Interruption Duration Index) • MAIFI (Momentary Average Interruption Frequency Index)

28. DA & System Reliability DA can increase the System Reliability by • Increasing Utilization of Existing Infrastructure: enable more efficient operation of PS, allowing closer control of voltage profiles • Contributing to outage prevention & recovery, optimal system performance under changing conditions, & reduced operating costs. • Easy Operations & Improved efficiency, management of peak loads via predictive technologies (DR) & communications with equipments: Quick Restoration technologies

29. What is Smart Grid To a….? • Meter Engineer: Advanced Metering Infrastructure (AMI) • Protection & Control Engineer: Substation & Dist Automation • Control Room Operator: Dist & Outage Management • Design & Planning Engineer: Asset Management • IT Engineer: Challenge of bringing it all together • And they all are right!!!!!!!!

30. MERC Smart Grid Coordination Committee (MERC SG-CC) • MERC issued DSM Regulations in 2010 & also formulated DSM-CC for speeding up the DSM projects. • DSM-CC: Secretary MERC is the Chairman of the Committee, with members from utilities & IIT Mumbai, Experts in field • All DSM proposals received from utilities are discussed in detail in DSM-CC & comments on the scheme are sent to the Commission. No DSM scheme is approved unless it is cleared by DSM CC • On similar grounds, MERC SG-CC is being formed; with representatives from Utilities (GTD), IIT Mumbai, MERC. First meeting on 12th June 2012. Special Regulations for SG implementation

31. Let Us Make a SMART beginning towards Smart Grid • Operational Improvements: • Metering & Billing/Outage management • Work force management /Reduced losses/ Better Asset Utilization • Asset Management : System Planning (Deferment of CAPEX Program) /Improved Maintenance practices • DA empowers system operators & provides them unprecedented visibility & control over the system (Efficiency Improvement • DA helps in Promoting RE Gen & Captive Gen/ Reducing AT&C losses & Improving System reliability & quality of supply • Win-Win Situation: Regulator: to work as catalyst for benefit to customers

32. Utilities/ Consumers/R&D Institutions/ Equipment Vendors & System integrators/ & REGULATORS “If it is to be It is up to me!!” Thank You !! (Contact me: vlsonavane@gmail.com)