Smart Metering for Automatic Demand Response

Smart Metering

for

Automatic Demand Response

Sanjeev K Rana

TATA Power Delhi Distribution Limited METERING BILLING/CRM BANGKOK

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

TPDDL Profile

• 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

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• 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

population of 5 Mln

• Peak Load Served : ~ 1400 MW

•Tata Power Delhi Distribution : ISO 9001,

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 10-12 hrs in summer

• No Concept of Consumer Service

• Erroneous consumer and asset database • Lack of Performance orientation

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

2004 2 0 0 5 & 2006 2007 20 08 & 2009 2003

PARIVARTAN (Change Management)

Focus on Employee development and consumer orientation. Amalgamation of culture post privatization. Institutionalization of Training and development.

Elimination of Electricity Theft

Conversion of Network to Theft proof technologies such as HVDS, LT ABC etc., Mass Meter Replacement. Electronic Meter, AMR Technologies;

Performance Consolidation

Institutionalization of Score card, Adaptation of advance technology/applications e.g. SAMBANDH, GIS, SCADA , SAP, SANCHAY etc.

Performance Assurance

Process Mapping; Technology upgradation, Network Augmentation

Maturity & Self Sustenance

Long Term PPA’s, BD Group, Consultancy/Training to other utilities; Generation Plant.

Turnar ound In du stry Emi ne nce Emer ging Lea de r 2010 -12 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

India Market DR Potential

Demand Response - Market Potential

Peak De m an d GW Business-as-Usual (No DR) Maximum Achievable (Achievable) 5% Reduction in peak demand through DR (Achievable) 10% Reduction in peak demand through DR In 2011-12 • Peak Demand - 152.746 GW • 5% reduction - 8 GW • 10% reduction - 16 GW

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.

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

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.

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

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

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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

Current Metering Scenario at TPDDL

Consumer(Nos) Meter Type Reading Type

Xpress Consumer

DJB , DMRC,

Malls etc. > 499 KW (0.02%) 208 HT Meter AMR

Key Consumer

LIP , Hospitals,

Institution > 99 KW (0.14%) 1649 HT Meter AMR

HRB

Consumer Street light etc. SIP ,Towers ,

11 KW to 99 KW (2.88%) 34087 CT Meter AMR HCB Consumer Household , Shops & Agriculture 1 KW to 10 KW (85.98%) 1018545 Single Phase HHD

Automatic Meter Reading at TPDDL

Existing set up:

•48000 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

AMI

• Real time meter reading • Remote meter reading

• Remote connect & disconnect • Interval metering

• Automated & timely billing • Data storage

• Pre-payment metering

• Load Management/Outage

handling

Customer Information for utility

• Comprehensive life sheet of

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

Meter Maintenance

•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

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,

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.

TPDDL AMI & ADR Project

Benefits:

a)Facilitate the Customers for better Energy Management

b) Potential Reduction of Expensive Power Purchases

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

Service Level Agreement with Customer

GPRS / PLC Communication Network

Meter Data Management System

Meter Data Collection System

Demand Response Automation Server

Network Operations Centre (NOC) Demand Load Control

(DLC) through Open ADR

Custom Applications Customer Portal

BMS

Enterprise Business Analytics

HISTORIAN CBM

ATO

Enterprise Service Bus

SCADA / EMS / DMS DA GIS

DER Operations

Substation Automation

OMS AMR / AMI

SAP

MDMS / TOD DR Consumer HAN

Network Planning

Design Asset

Management

ICCP

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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

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questions & queries