smartmetertm steering committee update march 2011 · 2017-03-24 · steering committee march 2011...

SmartMeterTM

Steering Committee Update – March 2011

2 Steering Committee March 2011 Report

Agenda

► Monthly Updates

► Release Status Update

► Deployment Status Update

► Schedule Update

► Deployment Update

► Budget Status – Expenditures by Workstream

► Budget Status – Benefits

► Issues / Risks Summary

► Program Metrics

► Appendix

► Project Deployment Plan Progress

► Contingency Reconciliation

► SmartMeterTM Acronyms


Release Status Update

Overall Actions/Status

EAC Funded Budget* ITD Scope Schedule Resources Issues Risks

IT Releases, February 2011

Release I non-NEMS - Deploy

Release J TLM – Build/Deploy

Release J Outage – Plan/Analyze

Release K – Plan/Analyze

Release I - Migrate NEM and other ABS-billed

accounts from ABS to CC&B

Release J TLM - Integrate usage data into TLM

(Transformer Load Management) reporting to provide

actual customer peak load data

Release J Outage - Automate the outage detection

process to identify outages using SmartMeterTM data in

addition to customer calls.

Release K - Transition customers to interval billing to

support SmartMeterTM initiatives

Release I

▪ Non-NEMs Schedule assessing current ABS and CC&B rate components.

▪ The final Non-NEMs release will occur after completion of CC&B upgrade.

Release J TLM

▪ Transformer Load Management deployment date will move out to 04/22/11 due to incremental additional

change requests.

Release J Outage

• Outage plan/analyze has completed. Project forecast reviews are underway.

Release K

▪ Release K Phase 2 requirements definition is underway..

*Funded Budget represents the amount of funding that has been approved through the "gated" funding

process. Projects that are noted as "Plan/Analyze" or "Analyze" are only partially funded through those

initial phases. Upon completion of the Analyze phase, the release team will prepare a request to authorize

the remaining amount required to complete the Release.


Release Status Update (continued)

Application Upgrades – Upgrade Meter Data Management System (MDMS) and electric ‘head-end’ system.

Performance & Scalability - Ensure operation at necessary performance and scalability levels

HAN Enablement - Deployment of In Home Devices (IHD) to SMB & residential customers over the (AMI) network

Application Upgrades ▪ Successful deployment on 01/28. ▪ Electric ‘head-end’ system upgrade targeted for 4/1/2011.

Performance & Scalability ▪ Final MDMS Scale test is underway. ▪ Data Warehouse hardware improvement work is underway. Currently planning and creating initial

forecast for work completion. HAN Enablement ▪ Project dependency of SmartEnergy 2.0 standards will result in a renewed work effort in 2Q 2011.

Overall ▪ IT is working to realign all remaining IT work with remaining IT budget

Overall Actions/Status

EAC Funded Budget* ITD Scope Schedule Resources Issues Risks

IT Release, February 2011

Application Upgrades - Deploy

Performance & Scalability - Execute

HAN Enablement - Plan

*Funded Budget represents the amount of funding that has been approved through the "gated" funding

process. Projects that are noted as "Plan/Analyze" or "Analyze" are only partially funded through those

initial phases. Upon completion of the Analyze phase, the release team will prepare a request to authorize

the remaining amount required to complete the Release.


Deployment Status Update

Endpoints ▪ Increased rate of UTCs versus planned

Electric Network ▪ Supplemental network installation to support transition of meters to

Operations.

Gas Network ▪ Remediation of gas module transition issues.

Endpoints

▪ Executing urban customer access, non-standard installation and customer

outreach processes

▪ In progress

▪ In progress

Actions/Status Challenges

EAC 2011 Forecast

(2011 EAC / CPI)

Scope Schedule Resources Issues Risks

Deployment: February, 2011

Endpoints (2011 YTD)

Gas Network (2011 YTD)

Electric Network (2011 YTD)


11M Meters Scalability

Legend

Office Closures (ITD)

Alpha I Pilot

Schedule Update 2010

Jul Sep Oct Nov Dec Feb Jan May Aug Apr

Jun

Benefits

Apr Jun May Mar IT Release Deployment

Release H

Field Delivery

Remaining Engineering Solutions for MLPP Scenarios

3.0M Meter/Module Installations, 2010

Release I

Approved Milestone (delay)

Release J

Plan/Analyze complete

MLPP Cost/Benefit Analysis

Initial Network Deployed

350 Positions Captured

6 Phase-I Office

Closures, cumulative 2011 Office Closures

2011

Meter Reading Reductions (ITD) 450 Positions Captured

550 Positions Captured

Meter Power Status Check (MPSC)

- Call Center and IVR

Remote Connect

Disconnect 2

Q3 Deploy

Check Point-

Enhanced Outage Notification (EON)

Restoration (OR) / Transformer Loading

Management (TLM)

2 Phase 1 Office

Closures Complete, 2010

TLM deploy TLM Plan

TLM Analyze

OR Deploy

SE2.0 finalized

ABS non-NEMS

Deploy

ABS/CC&B Synchronization Reports

SM Operations Center SMOC Phase 1.0 Deploy

As of 2/31/11

EON

Forecasted Milestone (delay)

Milestone Met

Baseline Milestone

Forecasted Milestone (early)

Oct Sep Aug Jul Nov Dec

NEMS Migration Phase I

2.0M Meter/Module Installations, 2011

Milestone TBD

Release O

Performance & Scalability

HAN Alpha I & II Alpha II complete

HAN Enablement

Q2 Deploy

‘Head-end’ system upgrade (electric)

Release K Rel K Phase 1 Analyze

Rel K Phase 2 Analyze

HAN restart


As of March 11, 2011 Deployment Update

Through

Friday,

3/11

2011 Install Rate vs. Plan - Weekly Meter Totals

0

10,000

20,000

30,000

40,000

50,000

60,000

70,000

80,000

7-J

an

21-J

an

4-F

eb

18-F

eb

4-M

ar

18-M

ar

1-A

pr

15-A

pr

29-A

pr

13-M

ay

27-M

ay

10-J

un

24-J

un

8-J

ul

22-J

ul

Week Ending (Friday) Dates

We

ek

ly I

ns

talls

.0M

.4M

.8M

1.2M

1.6M

2.0M

Weekly installs

2011 Cumulative Installs

2011 Target

2011 Weekly target

2011 target (Rev. 14 prelim) : 2.0MTotal SM Inception to

date meters in

service: 7,736,089


2011 Budget Status – Expenditures by Workstream

Year-to-Date Variance Explanations:

Favorable YTD capital variance ($7.5M) due to timing; includes favorable variances due to: 1) fewer meter/module installations of $4.8M (#5), 2) less IT spending of $1.2M

(#11), and 3) other miscellaneous favorable variances ($1.5M).

Favorable YTD expense variance ($5.9M) due to timing associated with: 1) underruns in Customer of $5.9M (#16) and four other workstreams totaling $1.0M (#13, #15,

#24 and #25), partially offset by additional early meter retirements of -$1.0M (#23)

# Work Stream Budget Actual Variance Budget Actual Variance #

Capital (000s)

1 PMO $293 $220 $74 $617 $520 $97 $3,833 $46,849 1

2 SM OPERATIONS $0 $5 ($5) $0 $45 ($45) $0 $11,350 2

4 SM FIELD DELIVERY - EXECUTION NETWORK $407 $254 $153 $811 $738 $74 $4,436 $28,992 4

5 SM FIELD DELIVERY EXECUTION ENDPOINTS $8,778 $5,188 $3,589 $15,194 $10,428 $4,765 $106,706 $254,742 5

6 SM FIELD DELIVERY OFFICE $1,244 $1,007 $237 $2,550 $2,232 $318 $10,738 $40,921 6

7 SM SOLUTIONS OFFICE $800 $386 $414 $1,889 $1,319 $570 $6,773 $11,269 7

8 SM SOLUTIONS - ENGINEERING $645 $261 $384 $1,414 $626 $788 $3,000 $11,445 8

9 SM SOLUTIONS - G&E METERING SERVICES $6,435 ($853) $7,288 $10,900 $11,206 ($307) $62,241 $921,194 9

10 Field Delivery / Solutions Total: $18,308 $6,244 $12,064 $32,758 $26,550 $6,208 $193,894 $1,268,564 10

11 IT (Including Technology Monitoring) Total: $2,951 $1,796 $1,156 $5,317 $4,110 $1,207 $27,038 $348,646 11

12 Capital Total: $21,553 $8,265 $13,288 $38,693 $31,225 $7,467 $224,765 $1,675,409 12

Expense (000s)

13 PMO $362 $92 $270 $708 $367 $342 $3,138 $25,183 13

14 SM OPERATIONS $368 $533 ($165) $713 $1,446 ($734) $2,730 $57,073 14

15 SM CHANGE MANAGEMENT $483 $189 $294 $959 $767 $192 $5,032 $13,345 15

16 CUSTOMER $5,443 $1,404 $4,039 $8,746 $2,894 $5,852 $36,766 $71,561 16

0

17 SM FIELD DELIVERY - EXECUTION NETWORK $67 $0 $67 $133 $0 $133 $800 $0 17

18 SM FIELD DELIVERY - EXECUTION ENDPOINTS $0 $1 ($1) $0 ($0) $0 $2,370 $103 18

19 SM FIELD DELIVERY OFFICE $329 ($16) $345 $592 $28 $565 $0 $15,169 19

21 SM SOLUTIONS OFFICE $334 $80 $255 $1,392 $897 $495 $2,283 $2,637 21

22 SM SOLUTIONS - ENGINEERING $31 $3 $28 $55 $12 $44 $127 $1,573 22

23 SM SOLUTIONS - G&E METERING SERVICES $2,024 $5,057 ($3,033) $4,048 $5,057 ($1,008) $6,571 $53,525 23

24 Field Delivery / Solutions Total: $2,786 $5,124 ($2,339) $6,221 $5,993 $229 $12,151 $73,006 24

25 IT (Including Technology Monitoring) Total: $319 ($38) $357 $500 $484 $16 $5,946 $131,329 25

26 Expense Total: $9,761 $7,304 $2,457 $17,846 $11,951 $5,895 $65,763 $371,497 26

27 Capital + Expense Total: $31,314 $15,569 $15,745 $56,539 $43,176 $13,363 $290,528 $2,046,906 27

Year-to-Date - FebruaryInception to

Date Spend

Current Month - February2011 Annual

Budget


2011 Budget Status – Benefits

2007 2008 2009 2010 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec ITD Actual#

1 Activated Meter Benefits: 111$ 4,705$ 26,055$ 56,313$ 6,181$ 6,334$ 6,485$ 6,698$ 6,996$ 7,313$ 7,720$ 8,116$ 8,558$ 9,007$ 9,436$ 10,093$ 99,698$ 1

2 Mainframe License Benefits: 1,250$ 5,000$ 5,000$ 5,000$ 417$ 417$ 417$ 417$ 417$ 417$ 417$ 417$ 417$ 417$ 417$ 417$ 17,083$ 2

3 Total: 1,361$ 9,705$ 31,055$ 61,313$ 6,598$ 6,751$ 6,902$ 7,115$ 7,412$ 7,730$ 8,137$ 8,533$ 8,975$ 9,424$ 9,853$ 10,510$ 116,782$ 3

4 2011 Cumulative Actual + Forecast: 6,598$ 13,349$ 20,250$ 27,365$ 34,778$ 42,507$ 50,644$ 59,177$ 68,151$ 77,575$ 87,428$ 97,938$ 4

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

Budgeted Benefits:

5 Monthly 3,914$ 3,914$ 4,047$ 4,186$ 4,278$ 4,350$ 4,432$ 4,507$ 4,593$ 4,683$ 4,763$ 4,850$ 5

6 Cumulative 3,914$ 7,829$ 11,875$ 16,061$ 20,339$ 24,690$ 29,121$ 33,629$ 38,222$ 42,904$ 47,667$ 52,518$ 6

Actual / Current Forecast:

7 Monthly 2,193$ 2,314$ 2,371$ 2,454$ 2,481$ 2,513$ 2,567$ 2,614$ 2,671$ 2,723$ 2,767$ 2,871$ 7

8 Cumulative 2,193$ 4,507$ 6,878$ 9,332$ 11,814$ 14,326$ 16,893$ 19,507$ 22,177$ 24,900$ 27,668$ 30,539$ 8

9 YTD Variance (1,722)$ (3,321)$ (4,997)$ (6,728)$ (8,526)$ (10,363)$ (12,229)$ (14,122)$ (16,044)$ (18,004)$ (20,000)$ (21,979)$ 9

*

**

SmartMeter Balancing Account (SBA) Credits *

#

($ in thousands)

2011 SmartMeter Balancing Account (SBA) actual and forecast credits assumes the continuation of the $1.95 electric / $1.04 gas activated meter-month savings and $5 million per year mainframe

license savings.

2011 benefits, budget versus actual and forecast, do not include meter reading costs and benefits which are being recorded in the Meter Reading Memorandum Account beginning on January 1,

2011.

Preliminary ForecastActual

2011 Benefits, Budget vs. Actual and Forecast **

($ in thousands)


Issues Summary

Target Resolution

Date

Issues Impact Status Summary

3/15/2011

Volume of deployed

untransitioned meters

to SM Read status

higher than expected

under 2010 base plan

Increased costs and negative

customer impact

Significant business process enhancements have been implemented and

have contributed to a 33% reduction in untransitioned meters. Finalizing

transition targets consistent with 2011 deployment goals (Revision 14,

Deployment Schedule).

Ongoing

Increasing number of

installations affected by

access refusals

Increased costs, increase in

unable to complete (UTC) back-

log, customer change

management

Working plan to engage customers across multiple communication

channels to enhance customer understanding of SmartMeter journey and

benefits.


Risks Summary

# Created

On P I Score

Prev.

Score Risks Impact Status Summary

Assoc.

Issue

1 5/15/2009 3 3 9 25 Non-standard Installations may

impact deployment cost and

schedule

Key drivers: Need customer

access to reach meter, meter

with space limitations and

customer overbuilds

Schedule and additional

costs

Cost impact estimate included within approved reforecast

Estimate-at-Complete. Installations and resource planning

being adjusted to mitigate schedule impacts. Customer

outreach strategies being incorporated into field pilots and

deployment strategies prior to starting full scale deployment

to minimize customer impact

2 3/22/2010 4 4 16 16 Vendor SmartMeter products

cannot be delivered to meet the

deployment schedule.

Key drivers: Remaining vendor

development activities and

resources to complete

solutions, insufficient lead time

for procurement due to design

changes/schedule decisions.

Deployment slow/stand

down, resource planning

ability, and additional costs

Vendor solutions for non-standard deployment under

development, testing and review. Management of vendor

delivery timelines subject to ongoing joint project and vendor

leadership review. Focus on remaining deployment

dependencies being used to validate integration of vendor

product deliveries.

Finalization of network design/equipment mix to complete

network deployment in process with vendors.

3 4/4/2008 3 5 15 15 Business processes enabled by

new technology may not

perform as intended.

Key driver: Increased data

volume and validation,

underlying business processes.

Billing errors, customer

complaints, inability to meet

endpoint deployment goals.

Continuing to monitor technology performance and

identifying mitigations to resolve any identified technology

performance issues. Meter transition process checks

updated to include new integrated standards with Vendor for

validating Network design, meter connectivity and read

performance. Planning for Full –Deployment/Interval Billing

via functionality deployments and additional process

capability initiatives through 2011 underway.


Program Metrics

Feb '11 Variance Analysis

Metric Key Performance Indicator Actual Target Var Actual Target Var Actual Target Var Forecast Target Var

P1SM Earnings Contribution ($M -

estimated)5.7$ 5.7$ 0.0% 5.8$ 5.7$ 1.8% 11.5 11.4 0.9% 70.0$ 66.2$ 5.7%

P2 OSHA Recordable Rate (YTD) - 0.37 - 0.42 - 0.51

P3 MVI Recordable Rate (YTD) - 0.95 3.56 0.98 ` 0.98 0.98 1 MVI reported in February

C1Customers enrolled in SmartRate

(net)24,043 (track only) 23,803 (track only)

C2# of CPUC escalated Customer

Complaints55 (track only) 84 139.0 (track only)

C10Customer Complaint Rate

(escalated to CPUC)0.035% (track only) 0.060% (track only) 0.047% (track only)

D1Meters/Modules Installed -

Electric & Gas157,291 127,028 23.8% 139,423 120,783 15.4% 296,714 287,460 3.2% 2,000,000 2,000,000 0.0%

D2 Gas Network - DCUs Installed 20 27 -25.9% 8 46 -82.6% 28 73 -61.6% 617 617 0.0% Fewer Network installations initiated than planned; Network

units at completion under review

D3 Electric Network - Nodes Installed 253 160 58.1% 194 445 -56.4% 447 605 -26.1% 4,417 4,417 0.0% Fewer Network installations initiated than planned; Network


D5 UTC Rate 6.3% 5.0% 25.7% 4.5% 6.0% -25.0% 5.5% 6.0% -8.3% 5.5% 6.0% -8.3%

D7 UTCs open beyond 90 days 145,673 (track only) 150,696 (track only)

D8 CPI - Endpoints $31.41 $44.46 -29.4% $39.48 $44.17 -10.6% $35.20 $44.17 -20.3% $44.17 $44.17 0.0%

D12 CPI Gas Network $773 $2,222 -65.2% $9,375 $1,505 522.9% 3,286.0 1,505 118.3% $1,505 $1,505 0.0% Fewer Network installations initiated than planned; Network


D13 CPI Electric Network $1,883 $2,130 -11.6% $1,526 $1,371 11.3% $1,707 $1,371 24.5% $1,371 $1,371 0.0%Increase in complex Network installations, location alternatives

in progress

D14Total Weeks of Inventory on Hand

- Electric Meters19 6 216.0% 16 8 100.0%

D15Total Weeks of Inventory on Hand

- Gas Modules18 6 205.8% 19 8 137.5%

O4 Transition Aging - Average Days 143 (track only) 118 (track only) 128 (track only)

O5 SM Billing accuracy % (SA) 99.88% 99.88% 0.0% 99.88% 99.88% 0.0% 99.88% 99.88% 0.0% 99.88% 99.88% 0.0%

O6 SM Billing timeliness % (SA) 99.82% 99.79% 0.0% 99.87% 99.79% 0.1% 99.85% 99.79% 0.1% 99.79% 99.79% 0.0%

O7SM % Bills not estimated

(BSEGs)99.90% 99.90% 0.00% 99.86% 99.90% -0.04% 99.88% 99.90% 0.0% 99.90% 99.90% 0.0% Analysis in progress

B2Meters Activated - Electric & Gas

(end of month)62,940 (track only) 87,197 (track only) 150,137 (track only)

B3Remote Disconnect & Reconnect

Transactions26,500 (track only) 25,597 (track only) 52,097 (track only)

B5 ITD Meter Reading HC reductions 470 (track only) 487 (track only)

Jan '11 - Month Results Month Results 2011 Year End ForecastYTD


Appendix

► Combined Plan / Target / Actual Progress

► Contingency Reconciliation

► SmartMeter™ Acronyms


Project Deployment Plan Progress

#s as of 02/28/11

Combined Gas and Electric Plan, Target, and Actuals

(Cumulative)

0

1,000

2,000

3,000

4,000

5,000

6,000

7,000

8,000

9,000

10,000

11,000

EOY

2007

Q108 Q208 Q308 EOY

2008

Q109 Q209 Q309 EOY

2009

Q110 Q210 Q310 EOY

2010

Q111 Q211 Q311 EOY

2011

Q112 Q212 EOY

2012

TargetBus Case PlanActual

# in Thousands


Contingency Reconciliation

SmartMeter Contingency Reconciliation $000s

Business Case Approved Contingency 177,753

Total Project Decsision Requests Approved and Adopted by Steering Committee 177,753

Remaining Contingency -

Approved Project Decision Requests, by Approval Date

2007 106,329$

2008 $32,240

2009 $20,313

2010 $18,871

$177,753


SmartMeterTM Acronyms

Acronym Definition Acronym Definition

ABS Advanced Billing System MARA My Account Re-Architecture

AFCI Arc Fault Circuit Interrupter MDMS Meter Data Management System

AMI Advanced Metering Infrastructure MLPP Meter Location Problem Project

AP Access Point MPSC Meter Power Status Check

Apps Applications MV-90 Multi Vendor - 90

ASM Automated Storage Management MVI Motor Vehicle Incidents

BDG Business Development Group NEMS Net Energy Metering Services

CC&B Customer Care and Billing NIC Network Interface Card

CEDSA Centralized Electric Distribution System Assets OIR Order Instituting Rulemaking

CoE Center of Excellence OIS Outage Information System

CPI Cost Per Install OMT Outage Management Tools

CPUC California Public Utilities Commission Ops Operations

DART Distribution Asset Reconciliation Tool OSHA Occupational Safety and Health Administration

DC Data Center PCR Project Change Request

DCU Data Collector Unit PCT Programmable Communicating Thermostat

DR Disaster Recovery PDP Peak Day Pricing

DRA Division of Ratepayer Advocates PDR Project Decision Request

DSCI Distribution Control Systems, Inc. PE Perfomance Engineering Company

EA Ecologic Analytics PMO Project Management Office

EAC Estimate at Completion PTR Peak Time Rebate

ED Energy Division QBR Quarterly Business Review

EMR Electric Meter Reader RCDC2 Remote Disconnect Phase 2

EMT Electric Meter Technician Rev. Revision

EOM End-of-Month RF Radio Frequency

EON Emergency Outage Notification RFA Request For Authorization

EOY End Of Year RV Restoration Validation

FA Functional Area SBA SmartMeter Balancing Accounts

FD Field Delivery SM SmartMeter

GE General Electric Co. SM Apps SmartMeter Applications

GFI Ground Fault Interrupter SMU SmartMeter Upgrade

HAN Home Area Network SR Service Request

HC Head Count TBD To Be Determined

IHD In-Home Devices TechArch Technical Architechture

ISTS Information Systems and Technology Services TIC Technology Innovation Center

IT Information Technology TLM Transformer Load Management

ITD Inception To Date TOU Time Of Use

IVR Interactive Voice Response UIQ Utility IQ - SSN software

KC Knowledge Center UTC Unable To Complete (meter installation)

KVAR Kilo-Volts-Amps Reactive YTD Year-To-Date

LOB Line of Business

SmartMeter Acronyms

smartmetertm steering committee update march 2011 · 2017-03-24 · steering committee march 2011...

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