09 May 2008 doc IEEE 802 15 doc

  • Slides: 16
Download presentation
09 May 2008 doc. : IEEE 802. 15 -<doc#> Project: IEEE P 802. 15

09 May 2008 doc. : IEEE 802. 15 -<doc#> Project: IEEE P 802. 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: [Cx. Kq@pge. com] Re: [] Abstract: [To provide information regarding PG&E efforts in the Smart. Grid 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 P 802. 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 P 802. 15. Submission to IG NAN Group 1 Chris Knudsen, PG&E

About Pacific Gas and Electric Company ► Energy Services to about 15 M People:

About Pacific Gas and Electric Company ► 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) 2

Smart. Meter Program Highlights ► ► Largest planned implementation of AMI technology in the

Smart. Meter Program 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 ► ► The Smart. Meter technology mix will evolve to take advantage of rapidly evolving technologies ► ► First critical peak pricing program for residential customers in the nation We are moving toward our vision of the Smart Electric Grid Technologies deployed through the Smart. Meter program establish a platform for future innovations that will benefit our customers, our operations, and the State of California 3

Smart Energy Web Vision 3 Computing / information technology 2 Communications infrastructure 1 Energy

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

PG&E Smart. Meter Program Details ► Automated meter reading for all customers ► 10

PG&E Smart. Meter 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 5

6

6

Coverage Requirements Total Meters / Square Miles 0 -100 ► 90% of our meters

Coverage Requirements Total Meters / Square Miles 0 -100 ► 90% of our meters are deployed within only 15% of our territory but… 101 -500 501 -1, 000 1, 001 -2, 500 2, 501 -5, 000 5, 001 -10, 000 ► ► Coverage probability must be 100%, so… 10, 001 -20, 000 >20, 000 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 7

Capacity Requirements Capacity requirements are in 10’s of kbps. There is no need for

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 ► 8

Licensed Vs Unlicensed Comparison Matrix against Utility requirements Un-Licensed Coverage ► Robust w/ Mesh,

Licensed Vs Unlicensed Comparison Matrix against Utility requirements Un-Licensed Coverage ► Robust w/ Mesh, 100% coverage probability ► Fill incramental cost is low ► Typically Spectral Efficiency/ Capacity ► significantly ► Typically Interference ► Narrow band, FSK limited receive(2 d. B FM capture window), low power, 1 watt max EIRP ► FCC part 15 rules apply, all in band must play by the same rules ► Self interference is the dominant mode for FHSS WWAN systems ► Only Spectrum Cost ► Free ► at Spectrum Availability ► National lower than licensed due to part 15 rules (10 x lower or more) >. 5 bps/cell under load for current technology self interference $1 -$7 /MHz/POP the cost. ► Cost can range from $10 s of M to B depending on spectrum coverage for WWAN, Global for HAN ► Limited or must use existing carrier choice most likely proprietary or subject to shorter mobile operator product cycles ► Technology Re-Use/ Amount of Spectrum required ► Reuse Standards ► IP FCC ► Part <month year> 80%-90%% coverage probability, requires expensive incremental infrastructure to achieve 100% =1 and HAN, WWAN PHY, DL, MAC, proprietary, usually low or no royalties 15 ► Reuse =3+ ► Usually stds based but could be proprietary or strong IP royalties to a few big vendors ► Per spectrum <author>, <company> Confidential – For discussion purposes only 9

Home Area Network and Smart Grid ► Smart. Meter Upgrade includes two separate RF

Home Area Network and Smart Grid ► Smart. Meter 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 Concept HVAC, IP-enabled appliances and distributed generation will all be tied together through an integrated EMS 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 HAN IP-based RF Mesh 10

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

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

PG&E’s 2006 Load Duration Curve The top “ 50 Hours” represent 0. 6% of

PG&E’s 2006 Load Duration Curve The top “ 50 Hours” represent 0. 6% of the total hours in a year 12

Top 100 Hours But it Represents 10% of Total Generation or 2, 200 MW

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 $100 M annually 13

Smart. Meter Program Benefits Customer Benefits ► Greater convenience - no need to unlock

Smart. Meter Program Benefits Customer Benefits ► Greater convenience - no need to unlock gates or secure dogs for monthly meter reads ► Reduction in delayed, 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 information that enables customers to better understand their usage and manage their bills (near term future) ► Improved outage detection (longer term future) Operational Benefits (PG&E) ► Reduced operating costs ► Lower purchase costs resulting from reduced peak loads ► Improved billing efficiency ► Improved power outage restoration California Benefits ► Enhanced grid reliability ► Avoided rotating outages ► Less reliance on older, less-efficient power plants to meet peak demand 14

Cumulative benefits Smart. Meter Upgrade Provides Enabling Communications Layer Phase 3 – Future Enable

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

►Thank You 16

►Thank You 16