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Smart. Meter Program Update - Operational Benefits Realization Jim Meadows, Program Director August 2007 Smart. Meter Program Update - Operational Benefits Realization Jim Meadows, Program Director August 2007

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 ► ~20, 000 Employees ► Regulated by the California Public Utilities Commission (CPUC). ► Incorporated in 1905 2 2

The PG&E Smart. Meter program: ► will deploy a system for automated meter reading The PG&E Smart. Meter program: ► will deploy a system for automated meter reading – hourly meter reads for electric, and daily meter reads for gas ► includes two separate systems: a power line carrier system for electric and a radio frequency system for gas ► involves an upgrade to both gas and electric meters – approximately 10 Million meters will be upgraded ► will be deployed over a five year period. An initial, paced deployment began in Bakersfield in November, 2006. Deployment efforts are scheduled to conclude in late 2011 ► will introduce additional capabilities over time, including outage management and remote connect/disconnect ► will enable the introduction of demand-response rates for residential and small business customers 3 3

Smartmeter Program Has A Range Of Benefits Customers ► Receive usage information to better Smartmeter Program Has A Range Of Benefits Customers ► Receive usage information to better understand manage their bills, and be able to participate in future energy efficiency and demand response programs ► Experience less inconvenience and intrusion by no longer needing to unlock gates and tie up dogs for monthly meter reads ► Reduction in the causes of delayed, inaccurate and estimated bills ► Experience faster outage detection and restoration times ► Opportunity to turn service on and off remotely PG&E ► Reduced operating costs ► Reduced peak loads when customers shift to non-peak energy use and when they conserve (demand response) ► Lower procurement costs resulting from reduced peak load and enhanced load modeling ► Improved customer satisfaction stemming from enhanced customer service capability ► Improved billing efficiency ► Improved outage management ► Reduced energy theft CPUC/State ► 4 Supports the CPUC’s price-responsive tariff requirements 4

Smartmeter Program Will Pay For Itself Costs* Costs < Benefits O&M Benefits* Demand Response Smartmeter Program Will Pay For Itself Costs* Costs < Benefits O&M Benefits* Demand Response Remote turn on / off Outage detection Service restoration ISTS Deployment $189 M Operations Call volume reductions Meters Networks 90% of costs Records exception reductions ISTS O&M $191 M Installations IT Systems Field Deployment System Integration $1, 299 M Project Management Avoided dispatches / truck rolls Meter Reading Complex billing Capacity planning ► The Smart. Meter program has a positive business case: Projected benefits exceed projected costs over a 20 year program life ► Operational efficiencies (including meter reading savings) cover 90% of program costs ► 5 Demand response benefits (i. e. procurement cost savings) cover approximately 10% of program costs and promise to provide additional benefits in excess of costs * 20 year Present Value of Revenue Requirement 5

90% Of Smartmeter Program Costs Covered By Operational Benefits Breakdown of Operational Benefits By 90% Of Smartmeter Program Costs Covered By Operational Benefits Breakdown of Operational Benefits By Benefit Area 6 Total annual benefit from operations (at full deployment) = $160. 5 Million 6

Activated Meter Commitment to CPUC Savings Per Activated Meter Electric $ Gas $ Meter Activated Meter Commitment to CPUC Savings Per Activated Meter Electric $ Gas $ Meter Reader $ (0. 8235) $ (0. 8223) severance - Other Employee Related Costs $ (0. 1706) $ (0. 1705) Remote Electric Shut-off Benefits $ (0. 1429) $ - Avoided TOU Meter Maintenance $ (0. 1155) $ - Cash Flow on Summary Bills $ (0. 0927) $ (0. 0225) Exceptions Processing $ (0. 0809) $ - Avoided Dispatch Where Power is On $ (0. 0794) $ - Significant Outage Restoration-Capital $ (0. 0764) $ - Significant Outage Restoration-Expense $ (0. 0578) $ - Lower customer Call Volumes $ (0. 0515) $ - Deferred Meter Testing $ (0. 0445) $ - Improved TOU Rate Changes $ (0. 0190) $ - Momentary Outage Detection $ (0. 0106) $ - Load Research Capital Savings $ (0. 0069) $ (0. 0071) T&D Capital Savings (gas) $ - $ (0. 0143) TOTAL Savings/Meter/Month: $ (1. 7722) $ (1. 0366) Ø Once meters are activated, we pay either $1. 77 or $1. 04 to the SM balancing account each month. 7 7

An “Activated” Meter Has Several Characteristics ► Installed: the endpoint equipment (meter for electric, An “Activated” Meter Has Several Characteristics ► Installed: the endpoint equipment (meter for electric, module for gas) has been placed on customer premises ► Readable: the Smart. Meter system communicates with the endpoint equipment ► Billable: the billing system can use interval data collected through Smart. Meter to bill the customer ► Part of a virtual meter reader route string: the meter reader can be re -deployed when the virtual route string is removed from the manual meter reading workload Meters are activated in batches, by virtual route string Once a meter is activated, actual meter reading benefits begin to accrue 8 8

Activated Meters Lifecycle Meter/Network Installed § Network installed with serial diversificati on § Endpoints Activated Meters Lifecycle Meter/Network Installed § Network installed with serial diversificati on § Endpoints installed with serial diversificati on SM Enabled SM Read QA / Anchor Billed Meters Eligible For Activation Completed Routes § Updates to § Meters § Last manual § Customer § A billing become meter read accounts “complete” system searched in on a SM route is an SM system § Visual route are manual § Customer inspection part of a meter account § Billing to QA SM pool of reading changed system installs meters route with to “SM performs eligible for zero meters § Customer enabled” validation activation billed on § Can create § Electric manually a meters take collected completed longer to anchor route with search in reads limited than gas number of meters § Service meters plan (Excludable § Customer transition s, UTCs, account from other changes to manual meters out “SM read” meter of scope) reading via either route to SM “closed routes” benefits functionality or manual Virtual Route String Benefits Realizations § Consists of § Committed to manual the CPUC for meter benefits reading associated with routes with activated zero meters, by (i. e. writing monthly completed checks utilizing routes) SM balancing account ($1. 77 § One each electric completed meter, $1. 04 route for each gas each serial meter) § Captured in § Release meter reports readers § Meters are activated 9 9

Meter Routes Progress 10 10 Meter Routes Progress 10 10

Benefits Realization For Meter Reading ► Meter reading benefits account for the bulk for Benefits Realization For Meter Reading ► Meter reading benefits account for the bulk for program benefits - 53% of Smart. Meter operational (i. e. non demand response) benefits; 46% of total benefits ► Benefits are booked in a balancing account as soon as the meter is “activated” – PG&E cuts a check to the balancing account ► Meter reading benefits can only be realized once a meters on a virtual route string are activated or transferred to a different route ► Virtual route string = routes with different serials ► Meters are activated only after they are: installed, readable, billed, part of a completed virtual route string ► PG&E fine tunes installation activity to complete virtual route strings as soon as possible 11 11

In The Future, The Smartmeter Program Could Enable The Following Potential Capabilities Customers PG&E In The Future, The Smartmeter Program Could Enable The Following Potential Capabilities Customers PG&E CPUC/State q Real time energy usage data to premise from meter q Direct load control (air q Capacitor bank controls conditioner, water heater, pool q Transformer load monitoring pump, etc. ) q Meter health monitoring q CPP and other demand q Preventive line maintenance response programs and rates data (momentary) q Targeted regional/area TOU q Identification of facility programs performance or customer usage q Smart thermostat control anomalies (programmable communicating q System load forecasting and thermostat – PCT) settlement q Distribution planning q Enhanced outage data q Distribution voltage management q Energy load research q Gas system planning program flexibility q Pre-pay metering q Gas distribution maintenance (e. g. cathodic protection q Distribution fault detectors monitoring) q Energy resource planning q Building automation q Home energy/bill management tools and systems q Smart thermostat (programmable communicating thermostat – PCT) q Appliance control and monitoring q In-home displays q Data for ISO system control q Load control programs q Demand response programs 12 12