Project: IEEE P802.15 Working Group for Wireless Personal Area Networks (WPANs)

1. Project: IEEE P802.15 Working Group for Wireless Personal Area Networks (WPANs) Submission Title: [PG&E Smart Grid Discussion] Date Submitted: [09 May, 2008] Source: [Chris Knudsen, Director, Technology Innovation Center] Company [Pacific Gas & Electric] Address [77 Beale, San Francisco, Calif.] Voice:[415-973-4418], FAX: [415-973-0802], E-Mail:[CxKq@pge.com] Re: [] Abstract: [To provide information regarding PG&E efforts in the SmartGrid area and views about the need for a standard] Purpose: [Contribution to neighborhood Area Networks Interest Group (IG-NAN)] Notice: This document has been prepared to assist the IEEE P802.15. It is offered as a basis for discussion and is not binding on the contributing individual(s) or organization(s). The material in this document is subject to change in form and content after further study. The contributor(s) reserve(s) the right to add, amend or withdraw material contained herein. Release: The contributor acknowledges and accepts that this contribution becomes the property of IEEE and may be made publicly available by P802.15. Chris Knudsen, PG&E

2. Energy Services to about 15 M People: 5.0 M Electric Customer Accounts 4.1 M Natural Gas Customer Accts 70,000 square miles with diverse topography ~20,000 Employees Regulated by the California Public Utilities Commission (CPUC) About Pacific Gas and Electric Company

3. SmartMeterProgram Highlights • Largest planned implementation of AMI technology in the U.S. to date – 10.3 million meters • $1.7 B in funding (CPUC, July 2006) • 5 year deployment: 2006 – 2011 • The program will pay for itself over its 20 year useful life through operational savings, demand response, and energy efficiency • First critical peak pricing program for residential customers in the nation • The SmartMeter technology mix will evolve to take advantage of rapidly evolving technologies • We are moving toward our vision of the Smart Electric Grid • Technologies deployed through the SmartMeter program establish a platform for future innovations that will benefit our customers, our operations, and the State of California

4. Backup generation Grid 2 Vehicle / Vehicle to Grid Grid appliances Distributed storage SCADA T&D Automation Load limiting Fault prediction Micro-grid Load control Energy mgmt systems Solar monitoring & dispatch Distributed generation Outage management Interval billing Prepay In home displays Power quality management Generation / supply T&D Usage / demand Servers Data storage Web presentment Transactions Modeling Smart agents Intelligence Fiber/MPL RF Mesh Home Area Network (HAN) Broadband WWAN 3G Cellular Cap banks Reclosers Switches Sensors Transformers Meters Storage Substation Wires Customers Smart Energy Web Vision SmartGrid components 4 Business applications – “Smart Energy Web” Security 3 Computing / information technology 2 Communications infrastructure Energy information network 1 Energy infrastructure

5. PG&E SmartMeter Program Details • Automated meter reading for all customers • 10 Million meter upgrades • A network to collect meter reads remotely and communicate with the meters and into the home • Frequent meter reads - daily for gas, hourly or 15 minute interval for electric • Enables demand response programs • Enhanced capabilities over time

7. Coverage Requirements Total Meters / Square Miles • 90% of our meters are deployed within only 15% of our territory but… • Coverage probability must be 100%, so… • The less than 10% of our meters that are spread across 85% will drive our technology choice The technology choice must be robust in the dense areas and still be flexible enough to cover the rural areas

8. Capacity Requirements • Capacity requirements are in 10’s of kbps. There is no need for a broadband system • Traffic is raw data, no or very little formatting overhead • Distributed processing in meters can further reduce the traffic needs of the NAN kbps

9. Licensed Vs Unlicensed Comparison Matrix against Utility requirements <author>, <company>

10. Home Area Network and Smart Grid • SmartMeter Upgrade includes two separate RF Networks • RF Mesh Network to communicate from Meter to PG&E back office • Home Area Network to communicate Meter Data into home enabling home automation and energy management • Home Area Network enables: • Energy management systems/Home automation including policy-based control of HVAC and smart appliances • Integration of distributed micro-generation such as solar PV, Wind and PHEVs • Current and Future Potential DR applications include: • Load shifting/shaping • AC Cycling • Smartcharging • Load limiting Home Area Network Concept HVAC, IP-enabled appliances and distributed generation will all be tied together through an integrated EMS HAN IP-based RF Mesh

11. PG&E 2006 Annual Usage Peak Load July 25 @ 1700 hours 20,883 MWs MWs Month

12. PG&E’s 2006 Load Duration Curve The top “50 Hours” represent 0.6% of the total hours in a year

13. Top 100 Hours But it Represents 10% of Total Generation or 2,200 MW Eliminating the top 10% of energy usage through efficiency programs and demand response is worth over $100M annually

14. SmartMeter Program Benefits • Customer Benefits • Greater convenience - no need to unlock gates or secure dogs for monthly meter reads • Reductionindelayed, inaccurate and estimated bills • Voluntary pricing plan options that empower customers to shift or reduce energy usage when demand is at its highest (near term future) • Online access to energy usage informationthat enables customers to better understand their usage and manage their bills (near term future) • Improved outage detection (longer term future) • Operational Benefits (PG&E) • California Benefits • Reduced operating costs • Lower power purchase costs resulting from reduced peak loads • Improved billing efficiency • Improved power outage restoration • Enhanced grid reliability • Avoided rotating outages • Less reliance on older, less-efficient power plants to meet peak demand

15. SmartMeter Upgrade Provides Enabling Communications Layer Cumulative benefits Phase 3 – Future Enable future services and foster innovation Phase 2 – Near term Transform existing services using advanced communications capability • Customer Products and Services • Automated energy management system • Real-time pricing • Energy trading • Utility Operations Benefits • Micro-grids • Fault prediction • Smart Grid • Distributed battery • Vehicle to Grid • PHEV grid ancillary services • Other distributed generation (e.g., fuel cell technology) Phase 1 – Today Integrate existing services to new platform • Customer Products and Services • Prepay billing options • In-home displays • Basic energy management system • Utility Operations Benefits • Confirmed load control • Distribution automation • Advanced outage management • Load limiting • Distributed storage and generation • Backup generation • Solar generation output • PHEV smartcharging • Customer Products and Services • Interval rates • Net metering Utility Operations Benefits • Meter reading • Limited disconnect • Basic load control • Limited SCADA • Basic outage management SmartMeter Upgrade network seamlessly exchanges information between utility assets Time

16. Thank You