Smart Metering for Automatic Demand Response

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1 Smart Metering for Automatic Demand Response Sanjeev K Rana TATA Power Delhi Distribution Limited METERING BILLING/CRM BANGKOK 08-May-2012

2 Agenda Company Overview Challenges in Indian Power Sector Need and implementation of Automatic Demand Response Need and implementation of Smart Metering for Automatic Demand Response Metering scenario in TPDDL TPDDL AMI & ADR Project Way Forward.. 5/10/2012 2

3 TPDDL Profile The Tata Power Company Ltd. and Govt. of Delhi JV (51:49) License Area : N. Delhi- 510 sq. km Consumer Base : 1.25 Mln ; serving Joint Venture of Tata Power Company and Govt. of NCT of Delhi (51: 49) Licensed for distribution of power in North and North West Delhi population of 5 Mln Peak Load Served : ~ 1400 MW Tata Power Delhi Distribution : ISO 9001, 14001, ; SA 8000 Certified 5/10/2012 3

4 TPDDL s journey so far. At the time of inception AT&C Losses at a level of 53% Unreliable Power Situation - transformer failure rate of 11%, only 48% streetlights functional, power cuts of 8-10 hrs/day with hrs in summer No Concept of Consumer Service Erroneous consumer and asset database Lack of Performance orientation No Computerization / Automation / Tracking and Monitoring 5/10/2012 Current Scenario AT&C Loss level : 13.5% -- unprecedented reduction of 75% from opening loss levels Power Reliability improved manifolds transformer failure rate 1%, 99% streetlights functional, power cuts negligent despite continuous load growth One Stop solution for consumers- State of Art Call Center and Consumer Care GIS implemented 100% Assets and consumers mapped Performance Orientation through Change Management & Balanced Scorecard Approach Integrated CRM introduced, Automation roadmap implemented (SCADA, OMS, DMS, DA implemented) 4

5 & & Turnaround Industry Eminence Emerging Leader Steps to Pride Sustainability Long Term PPA, Own Generation, Green Power, SAP- ISU integrated with R3/GIS, Latest Technology (OMS,DMS,DA), Workforce Competency Building, Smart Grid initiatives Assessment Maturity & Self Sustenance Long Term PPA s, BD Group, Consultancy/Training to other utilities; Generation Plant. Performance Assurance Process Mapping; Technology upgradation, Network Augmentation Performance Consolidation Institutionalization of Score card, Adaptation of advance technology/applications e.g. SAMBANDH, GIS, SCADA, SAP, SANCHAY etc. Elimination of Electricity Theft Conversion of Network to Theft proof technologies such as HVDS, LT ABC etc., Mass Meter Replacement. Electronic Meter, AMR Technologies; PARIVARTAN (Change Management) Focus on Employee development and consumer orientation. Amalgamation of culture post privatization. Institutionalization of Training and development.

6 Challenges in Power Sector 5/10/2012 6

7 Peak Demand GW Demand Response - Market Potential India Market DR Potential Business-as-Usual (No DR) (Achievable) 5% Reduction in peak demand through DR (Achievable) 10% Reduction in peak demand through DR Maximum Achievable In Peak Demand GW 5% reduction - 8 GW 10% reduction - 16 GW 5/10/2012 7

8 Demand Response (DR) Demand Response (DR) is Peak Electrical Load Reduction, an historical perspective and business model for load control Demand Response explicitly refers to all those activities that involve utility action in the marketplace to modify the consumer's load profile through Consumer participation. Demand Response is a potent tool to address the peak energy and power deficit in India which stands at 12.1% and 10.6% respectively. 5/10/2012 8

9 Why Demand Response?? A. Gap between Demand side and supply side may be met by:- 1. Increasing the Generation Growth 2. Reducing the Load Demand B. Time, Resource and Capital Requirement issue can be addressed easily- crucial for Developing nations. C. Operational Concern addressed Virtual Peaking Generator D. Aligned with the Climate Concern 5/10/2012 9

10 Automatic Demand Response (ADR) Automatic Demand Response (ADR) is an integrated system with energy management control systems to initiate customer approved actions to curtail loads automatically during requirement of Grid. An Auto-DR event can be triggered by either real-time prices or system reliability triggers. The communication is based on open standards like Internet protocols Open ADR protocol. Facilities Utility Aggregator Facilities 5/10/

11 Infrastructure Model Utility will have direct customer relationship, contract and pay incentives Utility will design, develop, market and program manage the DR program Utility will engage DR infrastructure provider to provide multiple services like Auto DR infrastructure, Facility Commissioning and Shed strategy, BMS programming and management, customer training and problem resolution Demand Response (DR) DR Aggregator Model Utility will not have direct customer relationship Utility will engage service provider to provide Turnkey DR services like Auto DR infrastructure, BMS programming and management, customer training and problem resolution, design and development of DR program, incentive payment, DR program marketing and management, customer web portal, delivery of peak demand reduction 5/10/

12 5/10/

13 Smart Metering for ADR Smart Metering is one of the cornerstones of Smart Grid Vision as it: Allows customers to make informed decisions by providing highly detailed information Provides customers with greater control over their electricity use when coupled with time-based rates, potentially saving money on their monthly electric bill. Allows for faster outage detection and restoration of service, reduce call centre cost Increases privacy because electricity usage information can be relayed automatically to the utility for billing purposes without on-site visits

14 Current Metering Scenario at TPDDL Consumer Segment Xpress Consumer Key Consumer Profile DJB, DMRC, Malls etc. LIP, Hospitals, Institution Sanctioned Load > 499 KW > 99 KW % of TPDDL Consumer(Nos) 208 (0.02%) 1649 (0.14%) Meter Type HT Meter HT Meter Reading Type AMR AMR HRB Consumer SIP,Towers, Street light etc. 11 KW to 99 KW (2.88%) CT Meter AMR HCB Consumer Household, Shops & Agriculture 1 KW to 10 KW (85.98%) Single Phase HHD G & I Consumer Government & Institutional Consumers All Load 9361 (0.79 %) HT/CT/Prepa id Meters AMR HHD (Prepaid only) SCG Consumer JJ Clusters 2 KW (10.20%) Single Phase Group Meter Spot Billing 5/10/

15 Automatic Meter Reading at TPDDL Existing set up: meters are on AMR which serves 3% of the total consumers generating 60 % of total revenue GSM based CSD technology Challenges: Communication reliability Scalability (Capex, Opex, technical) Real time monitoring 1 way communication system 5/10/

16 AMI Meter Operation Real time meter reading Remote meter reading Remote connect & disconnect Interval metering Automated & timely billing Data storage Pre-payment metering Load Management/Outage handling Information for utility/customer Overall power usage information (meter reads) Power usage pattern information Granular information about power usage by devices inside the home Meter consumption reports Load profiling & history of usage Dynamic pricing peak/non-peak Customer Information for utility Comprehensive life sheet of consumer consumption Faster complaint redressal Remote notification & escalation Timely bill & payment alerts Meter Maintenance Remote meter health check Tamper proof Remote firmware upgrade

17 Smart metering solution framework Smart meters along with AMI Modems or the Meters having capability to communicate data over a media A Communication media that carries Data from Smart meter to designated Server (or a Data Centre) and An Enterprise Application Suite (like Data Acquisition Software, Meter Data Acquisition, SAP FICO /MM etc.) that helps process the data for billing /invoicing and other organization control & integration process

18 TPDDL AMI & ADR Project Project Objective: a) Peak Shaving by about 34 MW based on large C&I Customers identified by TPDDL and respective customer s potential and their agreement with TPDDL. b) Demonstrate the key features of AMI for C&I and Residential customers, c) Demonstrate the key features of Demand Response 5/10/

19 TPDDL AMI & ADR Project Triggers for DR: a) Price Trigger b) Reliability Trigger Scenarios identified by TPDDL: a) Shortage of Generation known in advance and the gap is not met through Short Term Trading. b) Freq <49.7 TPDDL within schedule and known that freq is likely to be there for more than 1.5 hrs. 5/10/

20 Benefits: TPDDL AMI & ADR Project a)facilitate the Customers for better Energy Management b) Potential Reduction of Expensive Power Purchases c) Achieve Grid Reliability 5/10/

21 TPDDL AMI & ADR Project Where: 250 large customers (Approx.150 MW contracted load) How: a)dr scenarios approved by Regulator b) MOU between Consumers and Utility c) Value added services to the customers d) Automatic Customer Load Curtailment 5/10/

22 TPDDL Metering Integration Service Level Agreement with Customer BMS Demand Load Control (DLC) through Open ADR Network Operations Centre (NOC) Demand Response Automation Server Custom Applications Meter Data Management System Customer Portal Meter Data Collection System GPRS / PLC Communication Network Service Level Agreement with Communication Network Provider Smart Meter Customer Customer s Home Area Network

23 ICCP Way forward Technology Integration CBM Enterprise Business Analytics HISTORIAN DER Operations Enterprise Service Bus ATO SCADA / EMS / DMS DA AMR / AMI OMS GIS SAP Substation Automation Network Planning SCADA : Supervisory Control & Data Acquisition EMS : Energy Management System DMS : Distribution Management System DA : Distribution Automation OMS : Outage Management System GIS : Geographical Information System SAP : System Application & Products CBM : Condition Based Maintenance ATO : Advanced Transmission Operations AMR : Automated Meter Reading AMI : Advanced Metering Infrastructure DR : Demand Response MDMS : Meter Data Management System TOD : Time of Day HAN : Home Area Network DER : Distributed Energy Resources ICCP : Inter Control Centre Protocol MDMS / TOD DR Consumer HAN Design Asset Management 5/10/

24 ? questions & queries /10/

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