Post on 14-Mar-2020
SmartMeterTM
Steering Committee Update - January 2011
2Steering Committee Report January 2011
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
3Steering Committee Report January 2011
Release Status Update
Release I - Migrate NEMs and ABS Billed Accounts from ABS to CC&B.
Release J - Enable quicker outage notification & allow query of meter status.
Release K - Transition customers to interval billing to support SmartMeterTM initiatives.
Release O - Process improvement efforts in support of SmartMeter.
Release I
▪ Non-NEMS component is still on target for Business usage in March, 2011.
▪ Some functionality from the internal December deployment has been pushed to
the January deployment. This will not impact the March go-live.
Release J
▪ Transformer Loading Management (TLM) is in the Build stage. Completed
review of the test model. Test execution is scheduled to begin second half of
January.
▪ Outage Identification is in the Plan/Analyze stage.
Release K
▪ Working on estimates for Design, Build, Test and Deploy activities for Phase 1
service requests.
▪ Working on the scope of Phase 2 which focuses on process redesign. Target is
end of January to define scope.
Release O▪ Completed all Service Requests that Release O is budgeted to deliver. Closing
the project.
▪ Compiled PDM (PG&E Delivery Methodology) deliverables for loading into
EDMS (Electronic Document Management System).
Overall Actions/Status
*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.
EAC Funded Budget* ITD Scope Schedule Resources Issues Risks
IT Releases (ITD)
Release I - Build/Deploy
Release J - Plan/Analyze
Release K – Plan
Release O - Build/Deploy
4Steering Committee Report January 2011
Release Status Update (continued)
Application Upgrades – Upgrade Meter Data Management System (MDMS)
Performance & Scalability - Ensure operation at necessary performance and scalability levels
HAN Alpha I & II - Pilot activities for customer-side messaging via HAN module
HAN Enablement - Deployment of In Home Devices (IHD) to SMB & residential customers over the (AMI) network
Overall▪ Multiple releases being worked on in parallel. Impacted elements include PTR,
PDP, MARA, NEMS, and Release K (interval billing).
Application Upgrades▪ CC&B and Senior Management need to review the new proposed Go Live Date
and weigh any risks to the CC&B upgrade. Decision is expected first week of January 2011.
▪ Additional funding was approved to complete the project.
Performance & Scalability▪ Focus is on scale test of MDMS with Head-end system (electric). It is
scheduled to complete in January 2011 depending on the availability of application environments.
HAN Alpha I & II▪ Project is complete and closed on 12/31/2010. Project scope was satisfied and
delivered on time and within budget.
HAN Enablement▪ Foundation work is planned for January 2011 as the Technology Innovation
Center (TIC) is working to finalize the plan.
Overall
▪ The Planning team continues to work on a SmartMeter™ Closure Plan intended
to communicate and ensure final scope with business stakeholders.
Overall Actions/Status
*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.
EAC Funded Budget* ITD Scope Schedule Resources Issues Risks
IT Releases (ITD)
Application Upgrades - Execution
Performance & Scalability - Test
HAN Alpha I & II - Build
HAN Enablement - Plan
2010 Other Capital Projects
(IT PMO, 09 carryover, SM Apps, DC)
2010 Operating Expenses (CC&B, Stabilization)
5Steering Committee Report January 2011
Deployment Status Update
Budget
(Budget / CPI)
2010 Forecast
(2010 EAC / CPI)
Scope Schedule Resources Issues Risks
Deployment: (ITD)
Deployment: YTD - December, 2010
Endpoints (2010 YTD)
Gas Network (2010 YTD)
Electric Network (2010 YTD)
Endpoints
▪ Revised endpoint deployment plan that accounts for the implementation of
enhanced Customer and Community Outreach strategies will require changes to
resource assumptions and allocations
▪ Non-standard installations
Electric Network
▪ Remote area electric backhaul network
Endpoints
▪ Revising resource plan to match endpoint schedule, targeted completion mid-
January, 2011
▪ Development of non-standard deployment solutions and strategies progressing
▪ Defining urban customer access, non-standard installation and customer outreach
processes
Electric Network
▪ Pilot test for a satellite-based backhaul completed December, 2010 and
production solution availability expected in February, 2011
Actions/StatusChallenges
6Steering Committee Report January 2011
Schedule Update
2010
Jul Sep Oct Nov Dec FebJanMay Aug Apr Jun
As of 12/31/10
2010
Benefits
Apr JunMayMarIT Release Deployment
Release H
Release O
Field Delivery
Remaining Engineering Solutions for MLPP Scenarios
3.0M Meter/Module Installations, 2010
Baseline Milestone
Milestone Met
Forecasted Milestone (early)
Forecasted Milestone (delay)
Approved Milestone (delay)
Le
gen
d
Release I Selected ABS migration to CC&B
Release J
Performance & Scalability
HAN Alpha I & II
Alpha II complete
HAN Enablement Plan/Analyze complete
MLPP Cost/Benefit Analysis
Initial Network Deployed
350 Positions Captured
4 Phase-1 Office Closures
Additional Office Closures
2011
Meter Reading Reductions (ITD)450 Positions Captured
550 Positions Captured
Office Closures (2010)
Meter Power Status Check (MPSC) - Call Center and IVR
NEMS migration to CC&B (Q3, 2011)
Remote Connect
Disconnect 2 - TBD
Q3 DeployQ2 Deploy
UIQ 4.2 5M Silo Testing
Check Point- Enhanced Outage Notification (EON) Replacement / Transformer Loading Management (TLM)
9.7M Meters Scalability
Alpha I Pilot complete
2 Phase 1 Office
Closures Complete
EON On HoldTLM Plan complete
TLM Analyze complete
7Steering Committee Report January 2011
2010 Install Rate vs. Plan - Weekly Meter Totals
0
10,000
20,000
30,000
40,000
50,000
60,000
70,000
80,000
90,000
100,000
8-J
an
22-J
an
5-F
eb
19-F
eb
5-M
ar
19-M
ar
2-A
pr
16-A
pr
30-A
pr
14-M
ay
28-M
ay
11-J
un
25-J
un
9-J
ul
23-J
ul
6-A
ug
20-A
ug
3-S
ep
17-S
ep
1-O
ct
15-O
ct
29-O
ct
12-N
ov
26-N
ov
10-D
ec
24-D
ec
Week Ending (Friday) Dates
We
ek
ly I
ns
talls
.0M
.4M
.8M
1.2M
1.6M
2.0M
2.4M
2.8M
3.2M
2010 target (Rev. 13 prelim) : 3.0M
2010 Baseline Plan: 2.7MTotal SM Inception to
date meters in
service: 7,474,163
As of December 31, 2010 Deployment Update
Through
Friday,
12/31
2010 Baseline Plan, Cumulative
2010 Target, Cumulative
2010 Actuals, Cumulative
2010 Target, Weekly
2010 Actuals, Weekly
12/31/10 Actuals Target Variance
Rev. 13
Prelim. 3,096,327 3,000,000 96,327
8Steering Committee Report January 2011
2010 Budget Status – Expenditures by Workstream
Year-to-Date Variance Explanations:
Unfavorable year-to-date capital variance versus plan of $5.7 million (1%) primarily driven by:
1) fewer PG&E endpoint installation costs than planned ($37.0 million – Line #4)
2) more than offset by fewer early retirements of certain meters and modules than planned ($46.30 million – Line #3)
Favorable year-to-date expense variance of $5.4 million (4%) due to:
1) fewer early retirements of certain meters and modules than planned ($9.0 million and $5.5 million – Lines #16 and #18) and less HAN-related spending (Line #21)
2) offset by greater than planned spending requirements for PMO, SM Operation, Customer and Change Management (Lines #12, #13, #14, and #15)
# Workstream Plan Actuals Variance Plan Actuals Variance % Var. #
Capital (000s)
1 PMO 356$ 673$ (317)$ 4,267$ 7,186$ (2,919)$ -68% 46,329$ 1
2 SM Operations 288$ 277$ 11$ 3,455$ 3,158$ 297$ 9% 11,305$ 2
3 FD- Strategic Relationships 17,504$ 28,730$ (11,226)$ 340,057$ 386,358$ (46,301)$ -14% 1,088,373$ 3
4 FD Endpoint Installation 6,428$ 2,089$ 4,339$ 66,888$ 29,868$ 37,020$ 55% 74,231$ 4
5 Field Delivery Office 2,738$ 1,037$ 1,701$ 25,295$ 28,851$ (3,556)$ -14% 51,155$ 5
6 FD - Network Install 118$ 1,122$ (1,004)$ 4,192$ 6,652$ (2,460)$ -59% 28,254$ 6
7 Deployment Subtotal: 26,788$ 32,978$ (6,190)$ 436,433$ 451,729$ (15,297)$ -4% 1,242,014$ 7
8 Business Process 546$ (966)$ 1,512$ 10,924$ 54$ 10,870$ 100% 14,394$ 8
9 IT/CC&B 2,155$ 4,112$ (1,957)$ 47,951$ 46,648$ 1,303$ 3% 328,407$ 9
10 Technology Monitoring -$ -$ -$ -$ 3$ (3)$ 1,735$ 10
11 Capital Total: 30,132$ 37,073$ (6,940)$ 503,030$ 508,778$ (5,748)$ -1% 1,644,185$ 11
Expense (000s)
12 PMO 143$ 1,283$ (1,140)$ 1,715$ 7,741$ (6,026)$ -351% 24,816$ 12
13 SM Operations 1,729$ 2,678$ (949)$ 20,158$ 25,363$ (5,205)$ -26% 55,627$ 13
14 Customer 2,059$ 4,010$ (1,951)$ 28,877$ 36,735$ (7,859)$ -27% 68,667$ 14
15 Change Mgt Customer Impact 691$ 223$ 467$ 8,287$ 8,998$ (711)$ -9% 12,578$ 15
16 FD- Strategic Relationships 1,416$ 420$ 996$ 14,635$ 5,642$ 8,993$ 61% 49,484$ 16
17 FD Endpoint Installation -$ (25)$ 25$ 4$ 106$ (103)$ -2894% 746$ 17
18 Field Delivery Office 776$ 410$ 367$ 7,984$ 2,464$ 5,520$ 69% 16,782$ 18
19 Deployment Subtotal: 2,193$ 805$ 1,387$ 22,623$ 8,212$ 14,411$ 64% 67,012$ 19
20 Business Process -$ 103$ (103)$ -$ 307$ (307)$ 307$ 20
21 IT/CC&B 3,502$ 814$ 2,689$ 36,106$ 25,440$ 10,666$ 30% 109,248$ 21
22 Technology Monitoring 121$ 192$ (71)$ 1,841$ 1,432$ 409$ 22% 21,290$ 22
23 Expense Total: 10,437$ 10,108$ 330$ 119,607$ 114,230$ 5,377$ 4% 359,545$ 23
2,003,730$ 24
Current Month - December Year to Date - DecemberInception to
Date Spending
9Steering Committee Report January 2011
2010 Budget Status – Benefits
2007 2008 2009 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec ITD Actual#
1 Activated Meter Benefits: 111$ 4,705$ 26,055$ 3,851$ 3,999$ 4,034$ 4,158$ 4,232$ 4,357$ 4,548$ 4,857$ 5,186$ 5,468$ 5,669$ 5,953$ 87,183$ 1
2 Mainframe License Benefits: 1,250$ 5,000$ 5,000$ 417$ 417$ 417$ 417$ 417$ 417$ 417$ 417$ 417$ 417$ 417$ 417$ 16,250$ 2
3 Total: 1,361$ 9,705$ 31,055$ 4,268$ 4,416$ 4,451$ 4,575$ 4,648$ 4,774$ 4,964$ 5,273$ 5,603$ 5,885$ 6,086$ 6,370$ 103,433$ 3
4 2010 Cumulative Actual + Forecast: 4,268$ 8,684$ 13,135$ 17,710$ 22,358$ 27,132$ 32,096$ 37,369$ 42,972$ 48,857$ 54,943$ 61,313$ 4
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Budgeted LOB Benefits:
5 Monthly 5,403$ 5,800$ 6,275$ 6,681$ 7,057$ 2,528$ 7,909$ 7,835$ 7,798$ 4,775$ 5,706$ 3,245$ 5
6 Cumulative 5,403$ 11,203$ 17,477$ 24,158$ 31,215$ 33,744$ 41,653$ 49,488$ 57,286$ 62,061$ 67,767$ 71,012$ 6
Actual / Current Forecast:
7 Monthly 4,448$ 4,756$ 5,040$ 5,156$ 5,242$ 5,533$ 5,568$ 5,921$ 6,253$ 6,719$ 7,124$ 7,259$ 7
8 Cumulative 4,448$ 9,204$ 14,244$ 19,400$ 24,642$ 30,174$ 35,742$ 41,664$ 47,916$ 54,635$ 61,759$ 69,018$ 8
9 YTD Variance (955)$ (1,999)$ (3,233)$ (4,758)$ (6,574)$ (3,569)$ (5,910)$ (7,824)$ (9,370)$ (7,426)$ (6,008)$ (1,994)$ 9
SmartMeter Balancing Account (SBA) Credits
Actual
#
2010 Line of Business (LOB) Expense Reductions, Budget vs. Actual and Current Forecast
($ in thousands)
($ in thousands)
10Steering Committee Report January 2011
Issues Summary
Target Resolution
Date
Issues Impact Status Summary
1/31/2011
Volume of deployed un-
transitioned 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 the percent of un-transitioned
meters against the number installed. Finalizing transition targets consistent
with 2011 deployment goals.
2/15/2011
Outreach strategies need
to be further refined for
customer specific
concerns
Increased costs, customer
change management
Enhanced customer outreach approaches in process of completion within
the larger deployment implementations - including San Francisco
deployment and Kern replacements.
2/28/2011
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.
11Steering Committee Report January 2011
Risks Summary
#Created
OnP I Score
Prev.
ScoreRisks Impact Status Summary
Assoc.
Issue
1 5/15/2009 5 5 25 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 estimated and integrated into the installations
and resource planning models. Deployment durations being
adjusted to mitigate the 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 12 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.
Vendor delivered two critical hardware components, the
MPACK external meter antenna, and the satellite backhaul
Access Point in Dec 2010.
4 6/25/2008 3 4 12 12 Project costs may exceed
approved CPUC authorized
amount at completion (including
contingency)
Costs at completion exceed
CPUC approved amount
Detailed review of work stream forecasts complete.
Executive review of completed analysis scheduled to
complete in early 2011.
12Steering Committee Report January 2011
Program MetricsVariance Analysis
Metric Key Performance Indicator Actual Target Var Actual Target Var Actual Target Var Forecast Target Var
P1SM Earnings Contribution ($M -
estimated)5.74$ 5.90$ -2.8% 56.07$ 55.41$ 1.2% 62.28$ 61.48$ 1.3%
P2 OSHA Recordables (SmartMeter) - - - - 1.0 1.0 1.0 1.0 One OSHA in Feb '10, YTD actuals rate = 0.56
P3 MVI Recordables (SmartMeter) - - - - 2.0 3.0 2.0 3.0
C1Customers enrolled in SmartRate
(net)24,466 (track only) 24,242 (track only) 24,242 (track only) 24,242 (track only)
C10Customer Complaint Rate (escalated
to CPUC)0.031% (track only) 0.028% (track only) 0.053% (track only)
D1Meters Installed - Electric & Gas
(Rev. 13 prelim)169,782 188,688 -10.0% 199,505 162,587 22.7% 3,096,327 3,000,000 3.2% 3,096,327 3,000,000 3.2%
2010 target revised in mid-December to reflect impact of enhanced
outreach activities.
D2 DCUs Installed 119 51 133.3% 18 - 1,045 981 6.5% 1,045 981 6.5%
D3Electric Network - Nodes Installed
(including MV90)742 434 71.0% 380 138 175.4% 4,682 4,294 9.0% 4,682 4,294 9.0%
D5 UTC Rate 8.2% 4.5% -82.2% 7.9% 4.5% -75.5% 6.4% 4.5% -41.9% 6.4% 4.5% -41.9% Increase in Access issues (see issues).
D7 UTCs open beyond 90 days 118,293 (track only) 134,896 (track only) 134,896 (track only)
D8CPI - Endpoints (direct labor & other
costs in 2010)*$35.78 $39.39 9.2% $32.01 $39.39 18.7% $31.02 $39.39 21.2% $31.02 $39.39 21.2%
D12CPI Gas Network (direct labor & other
costs in 2010)*$1,229 $1,604 23.4% $11,631 $1,604 -625.1% $1,763 $1,604 -9.9% $1,763 $1,604 -9.9% Year end accrual for Network Acquisition Rights
D13CPI Electric Network (direct labor &
other costs in 2010)*$634 $1,011 37.3% $2,403 $1,011 -137.7% $1,193 $1,011 -18.0% $1,011 $1,011 0.0% Year end accrual for install costs & misc material purchases
D14Total Weeks of Inventory on Hand -
Electric Meters18 6 199.7% 22 6 273.2% 22 6 273.2% 22 6 273.2%
D15Total Weeks of Inventory on Hand -
Gas Meters23 6 290.3% 20 6 231.4% 20 6 231.4% 20 6 231.4%
O4 Transition Aging - Average Days 118.2 (track only) 118.9 (track only) 107.5 (track only)
O5 SM Billing accuracy % (SA) 99.89% 99.70% 0.2% 99.90% 99.70% 0.2% 99.88% 99.70% 0.2% 99.88% 99.88% 0.0%
O6 SM Billing timeliness % (SA) 99.87% 99.60% 0.3% 99.86% 99.60% 0.3% 99.85% 99.60% 0.3% 99.85% 99.85% 0.0%
O7 SM % Bills not estimated (BSEGs) 99.94% 99.70% 0.2% 99.94% 99.70% 0.2% 99.90% 99.70% 0.2% 99.70% 99.70% 0.0%
B2Meters Activated - Electric & Gas
(end of month)198,530 (track only) 167,120 (track only) 1,503,775 (track only)
B3Count of All Remote Disconnects &
Reconnects25,628 (track only) 24,321 (track only) 230,542 (track only) 230,542 (track only)
B5 ITD Meter Reading HC reductions 452 (track only) 461 (track only) 461 (track only) 461 (track only)
2010 Year End ForecastYTDNov '10 - Month Results Dec '10 - Month Results
13Steering Committee Report January 2011
Appendix
► Combined Plan / Target / Actual Progress
► Contingency Reconciliation
► SmartMeter™ Acronyms
14Steering Committee Report January 2011
Project Deployment Plan Progress
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
Plan Target Actual# in Thousands
15Steering Committee Report January 2011
Contingency Reconciliation
SmartMeter Contingency Reconciliation $000s
1. Business Case Approved Contingency $177,753
Total PDRs Adopted by Steering Committee $2,856
Subtotal Adopted PDR's $2,856
Approved Date 2. Approved Project Decision Request (PDRs) - Pending Contingency Drawdown
2007 2007 PDR Total $103,473
2008 2008 PDR Total $32,240
2009 2009 PDR Total $20,313
7/23/2010 Change Management interim funding $8,871
7/23/2010 SmartMeter Operations interim funding $10,000
Subtotal PDRs $174,897
Total Approved PDRs $177,753
16Steering Committee Report January 2011
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