SmartMeterTM
Steering Committee Update – April/May 2012
©2011 Pacific Gas and Electric Company. All rights reserved.
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
Steering Committee May 2012 Report
2
Release Status Update
EAC
Funded Budget
ITD
Scope
Schedule
Resources
Issues
Risks
IT Releases: April 30, 2012
Release 1
Release 2
Release 3
Challenges
Actions/Status
Overall
Overall
▪ IT has executed against the SmartMeter plan. HAN enablement and Peak
Time Rebate roadmaps are in progress.
▪ Development for all in-scope functionality completed as of 3/30/12
▪ Project stabilization work complete for all components except MV90 and NEMs.
Steering Committee May 2012 Report
3
Deployment Status Update
EAC
2012 Forecast
Scope
Schedule
Resources
Issues
Risks
(2012 EOY / CPI)
Deployment: April 30, 2012
Endpoints (2012 YTD)
Gas Network (2012 YTD)
Electric Network (2012 YTD)
Challenges
Actions/Status
Endpoints
Endpoints
▪ Mass deployment nearly complete. Remaining meter installs in
less concentrated geographic areas.
▪ Field Deployment team addressing less common meter types, customized
solutions and final installations in areas containing meters left to exchange.
▪ Resources focused on opt-out requests during the months of February
through April
▪ Increased number of ‘Unable-To-Complete’ meters due to non-standard
meter installations in heavy urban areas (SF) and access refusals related
to Customer Choice.
▪ Continuing to complete requests for opt-outs in a timely manner while
addressing remaining SmartMeter™ installations and UTCs.
▪ Term Sheet developed with installation contractor to finalize 2012-2013
schedule for deployment of remaining meters while recognizing
complexity of less common meter types.
▪ Development of NEMS-configured meter pilot underway
▪ Development of pilot for Transformer-Rated meter forms is scheduled for
mid-June.
Electric Network
Electric Network
▪ Initial design scope of electric network now complete.
▪ Whether additional electric network is necessary is subject to ongoing
review, particularly in light of customers opting-out of SmartMeter™
Program.
▪ Tracking opt-outs to assess impacts on network.
▪ Working with technology supplier and internal stakeholders to address
network coverage in ‘hard-to-reach’ areas.
Steering Committee May 2012 Report
4
Schedule Update
As of 4/30/12
2012
Jan
Feb
Apr
Mar

IT Release Deployment
May
Jun
Jul
Aug
Sep
Oct
Nov
Dec
2013
Jan
Feb
Mar
All in-scope functionality completed
SM Operations Center
Field Delivery
9.0M Meters/Modules in service


Begin SmartMeter Opt-Out Program
Begin NEMS pilot
Begin NEMS deployment
Begin Transformer Rated Pilot
Release additional work per 2012 – 2013 Deployment Plan
Benefits
Meter Reading Reductions (ITD)
Legend
Baseline Milestone
Forecasted Milestone (early)
 594 Positions Captured
 Milestone Met
Milestone TBD
Forecasted Milestone (delay)
Approved Milestone (delay)
Steering Committee May 2012 Report
5
As of June 1, 2012
Deployment Update
Steering Committee May 2012 Report
6
2012 Budget Status – Expenditures by Workstream
Current Month - April
#
Work Stream
Budget
Actual
Year to Date - April
Variance
Budget
Actual
Variance
2012
Annual
Budget *
Inception to
Date Actual
#
A. Capital (000s)
1
BUSINESS OPERATIONS (PMO)
2
SM OPERATIONS
$56
$10
$46
$953
$745
$208
$1,060
$50,048
1
$0
$0
$0
$0
$0
$0
$0
$11,310
3
2
SM FIELD DELIVERY
$4,258
$1,075
$3,183
$19,702
$17,248
$2,454
$57,202
$418,598
3
4
SM SOLUTIONS
$2,873
($902)
$3,775
$4,075
$1,526
$2,548
$21,970
$974,604
4
5
IT
$162
$168
($6)
$6,206
$4,739
$1,467
$10,656
$374,365
5
$7,349
$350
$6,999
$30,936
$24,259
$6,677
$90,888
$1,828,926
6
$120
$11
$109
$825
$19
$806
$1,955
$26,359
7
$0
$0
$0
$0
$0
$0
$0
$56,594
8
$50
$114
($64)
$150
$124
$26
$150
$15,008
9
$1,897
$568
$1,329
$2,658
$1,566
$1,093
$13,960
$98,566
10
$23
$2
$21
$140
$3
$137
$302
$17,996
11
$0
$7
($7)
$0
$28
($28)
$0
$68,017
12
$215
$115
$100
$1,310
$769
$541
$5,363
$133,893
13
$2,305
$817
$1,488
$5,083
$2,509
$2,574
$21,730
$416,433
14
$176
$21
$155
$1,778
$764
$1,014
$3,016
$76,407
15
$0
$0
$0
$0
$0
$0
$0
$67,904
16
$50
$114
$150
$124
$26
$150
$15,008
17
6
Capital Total:
B. Expense (000s)
7
BUSINESS OPERATIONS (PMO)
8
SM OPERATIONS
9
SM CHANGE MANAGEMENT
10
CUSTOMER
11
SM FIELD DELIVERY
12
SM SOLUTIONS
13
IT
14
Expense Total:
C. Total: Capital + Expense (000s)
15
BUSINESS OPERATIONS (PMO)
16
SM OPERATIONS
17
SM CHANGE MANAGEMENT
18
CUSTOMER
$1,897
$568
$1,329
$2,658
$1,566
$1,093
$13,960
$98,566
18
19
SM FIELD DELIVERY
$4,281
$1,077
$3,204
$19,843
$17,252
$2,591
$57,503
$436,594
19
20
SM SOLUTIONS
$2,873
$3,768
$4,075
$1,554
$2,520
$21,970
$1,042,622
20
21
IT
22
Capital + Expense Total:
($896)
($64)
$377
$283
$94
$7,516
$5,508
$2,007
$16,019
$508,258
21
$9,654
$1,167
$8,487
$36,019
$26,768
$9,251
$112,618
$2,245,359
22
Year-to-Date Variance Explanations:
Favorable YTD capital variance ($6.7M) primarily due to a misunderstanding during a staffing change resulting in goods receipts not being entered (#3), fewer electric
meter purchases (#4), and a delayed timing of the initial HAN roll-out (#5).
Favorable YTD expense variance ($2.6M) primarily due to lower spending than planned in Business Operations/PMO (#7) and Customer (#10).
* 2012 capital and expense budgets currently in the process of
revision to align with the revised 2012 – 2013 deployment schedule
Steering Committee May 2012 Report
7
2012 Budget Status – Benefits
SmartMeter Balancing Account (SBA) Credits *
Actual
($ in thousands)
2007
2008
2009
2010
2011
Remaining Budget
Jan
Feb
Mar
Apr
May
Jun
Jul
Aug
Sep
Oct
Nov
Dec
ITD Actual
#
$ 117,744
1
$
21,250
2
$ 138,994
3
#
1
111
$ 4,705
$ 26,055
$ 56,313
$ 20,269
$ 2,479 $ 2,587 $ 2,599 $ 2,626 $ 2,473 $
2
Mainframe License Benefits: $ 1,250
$ 5,000
$ 5,000
$ 5,000
$ 5,000
$
3
Total: $ 1,361
$ 9,705
$ 31,055
$ 61,313
$ 25,269
$ 2,479 $ 2,587 $ 2,599 $ 2,626 $ 2,473
$ 2,515 $
2,557
$ 2,600
$
$ 2,479 $ 5,066 $ 7,665 $ 10,291 $ 12,764
$ 15,279 $ 17,836
$ 20,437
$ 23,081 $
4
Activated Meter Benefits: $
2012 Cumulative Actual + Forecast:
-
$
-
$
-
$
-
$
-
$
2,515 $
-
2,557 $
$
-
$
2,600 $
-
2,644 $
$
-
2,689 $
$
2,644 $
-
2,734 $
$
2,689 $
-
2,780
$
-
2,734 $
2,780
25,770 $ 28,504 $
31,284
Oct
Dec
4
2012 Benefits, Budget vs. Actual and Forecast **
($ in thousands)
Jan
Feb
Mar
Apr
May
Jun
Jul
Aug
Sep
Nov
Budgeted Benefits:
5
Monthly
6
Cumulative
$ 2,373 $ 2,412 $ 2,392 $ 2,432 $ 2,473 $
2,515 $
2,557 $
2,600 $
2,644 $
$ 2,373 $ 4,785 $ 7,177 $ 9,609 $ 12,082 $ 14,597 $ 17,154 $ 19,755 $ 22,399 $
2,734 $
2,780
5
25,088 $ 27,822 $
2,689 $
30,602
6
2,734 $
2,780
7
31,584 $ 34,318 $
37,098
8
6,497
9
Actual / Current Forecast:
7
Monthly
8
Cumulative
9
YTD Variance
$ 3,724 $ 4,244 $ 4,019 $ 4,118 $ 2,473 $
2,515 $
2,557 $
2,600 $
2,644 $
$ 3,724 $ 7,968 $ 11,987 $ 16,106 $ 18,579 $ 21,094 $ 23,651 $ 26,251 $ 28,895 $
$ 1,351 $ 3,183 $ 4,811 $ 6,497 $ 6,497 $
6,497 $
6,497 $
6,497 $
6,497 $
2,689 $
6,497 $
6,497 $
* 2011 and 2012 SmartMeter Balancing Account (SBA) actuals and forecasts consistent with the GRC Settlement of $0.92 electric / $0.02 gas activated meter-month savings and the
discontinuation of mainframe license savings already captured in the 2008 base year results
** 2012 benefits, budget versus actual and forecast, do not include meter reading costs and benefits which are being recorded in the Meter Reading Memorandum Account beginning on January 1, 2011.
Steering Committee May 2012 Report
8
Issues Summary
Target Resolution
Date
Ongoing
Issue
Increasing number
of installations
affected by access
refusals and desire
for customer choice
program.
Impact
Increased costs, increase in
unable to complete (UTC)
back-log, customer change
management.
Status Summary
Communicating with customers about the new SmartMeter
Opt-Out Program to facilitate customer elections.
Steering Committee May 2012 Report
9
Risks Summary
#
Created On
I
P
Score
Prev.
Score
1
9/30/2011
5
4
20
20
Risk
Impact
Increased forecast deployment
costs and external resources
requirement
Increased installation costs
and contract resources
required to complete
remaining installations
effectively and timely
Pursuing identified opportunities to increase installation
efficiency within ongoing operations and adherence to
scope.
Deployment delays,
resource planning and
increased costs.
Pursuing resolution of network coverage in ‘hard-to-reach’
areas with technology supplier, including potential alternate
network solutions.
Key drivers: Delays in
deployment, resource
availability and installation
complexity
2
9/1/2011
5
3
15
15
Network deployment and
performance in ‘hard-to-reach’
areas can not be completed
successfully.
Status Summary
Assoc.
Issue
Key drivers: Network
performance in ‘hard-to-reach’
areas and availability of
alternate solutions.
Steering Committee May 2012 Report
10
Program Metrics
Month Results
Target Var
March '12
Actual
Metric Key Performance Indicator
Month Results
Target
Var
April '12
Actual
Actual
YTD
Target
Var
23.3
23.3
-0.1%
2012 Year End Forecast
Actual
Target Var
P1
SM Earnings Contribution ($M estimated)
P2
OSHA Recordable Rate (YTD)
-
0.51
-
0.51
-
0.51
P3
MVI Recordable Rate (YTD)
-
0.98
-
0.98
-
0.98
C1
Customers enrolled in
SmartRate (net)
21,845
(track only)
21,731
(track only)
C2
# of CPUC escalated Customer
Complaints
8
(track only)
7
(track only)
C10
Customer Complaint Rate
(escalated to CPUC)
0.033% (track only)
D1
Meters/Modules Installed Electric & Gas
24,529
24,000
2.2%
19,808
19,000
4.3%
127,065
127,000
0.1%
400,000
400,000
0.0%
D5
UTC Rate
26.6%
15.0%
77%
15.0%
15.0%
0.1%
19.2%
15.0%
28%
15.0%
15.0%
0.0%
D7
UTCs open beyond 90 days
223,661
(track only)
226,842
(track only)
D8
CPI - Endpoints
$150.11
D14
Total Weeks of Inventory on
Hand - Electric Meters
10
6
57.5%
11
6
73.9%
D15
Total Weeks of Inventory on
Hand - Gas Modules
9
6
42.7%
8
6
27.1%
O4
Transition Aging - Average Days
188
(track only)
319
(track only)
O5
SM Billing accuracy % (SA)
99.95%
99.88%
0.1%
99.95%
99.88%
0.1%
99.95%
99.88%
0.1%
99.88%
99.88%
0.0%
O6
SM Billing timeliness % (SA)
99.97%
99.81%
0.2%
99.97%
99.81%
0.2%
99.97%
99.80%
0.2%
99.79%
99.79%
0.0%
O7
SM % Bills not estimated
(BSEGs)
99.95%
99.90%
0.1%
99.95%
99.90%
0.1%
99.95%
99.90%
0.1%
99.90%
99.90%
0.0%
B2
Meters Activated - Electric &
Gas (end of month)
61,525
(track only)
54,683
(track only)
$
5.8 $
5.8
-0.5%
$
5.8 $
5.8
0.0%
24
0.035% (track only)
$
71.2
$
70.8
Variance Analysis
0.6%
(track only)
0.019% (track only)
$111.24
CPI target under review in conjunction with
revised deployment plan
$128.45
168
524,416
See Deployment Status Update on page 4
(track only)
(track only)
152
850,412
(track only)
(track only)
Steering Committee May 2012 Report
11
Project Deployment Plan Progress
Combined Gas and Electric Plan, Target, and Actuals
(Cumulative)
11,000
10,000
9,000
8,000
7,000
6,000
5,000
4,000
3,000
2,000
1,000
0
EOY Q108 Q208 Q308 EOY Q109 Q209 Q309 EOY Q110 Q210 Q310 EOY
2007
2008
2009
2010
# in Thousands
Q111 Q211 Q311 EOY Q112 Q212 Q312 EOY
2011
2012
Q113 Q213
Target
Bus Case Plan
Actual
Steering Committee May 2012 Report
12
Contingency Reconciliation
Steering Committee May 2012 Report
13
SmartMeterTM Acronyms
SmartMeter Acronyms
Acronym
ABS
AFCI
AMI
AP
Apps
ASM
BDG
CC&B
CEDSA
CoE
CPI
CPUC
DART
DC
DCU
DR
DRA
DSCI
EA
EAC
ED
EMR
EMT
EOM
EON
EOY
FA
FD
GE
GFI
HAN
HC
IHD
ISTS
IT
ITD
IVR
KC
KVAR
LOB
Definition
Advanced Billing System
Arc Fault Circuit Interrupter
Advanced Metering Infrastructure
Access Point
Applications
Automated Storage Management
Business Development Group
Customer Care and Billing
Centralized Electric Distribution System Assets
Center of Excellence
Cost Per Install
California Public Utilities Commission
Distribution Asset Reconciliation Tool
Data Center
Data Collector Unit
Disaster Recovery
Division of Ratepayer Advocates
Distribution Control Systems, Inc.
Ecologic Analytics
Estimate at Completion
Energy Division
Electric Meter Reader
Electric Meter Technician
End-of-Month
Emergency Outage Notification
End Of Year
Functional Area
Field Delivery
General Electric Co.
Ground Fault Interrupter
Home Area Network
Head Count
In-Home Devices
Information Systems and Technology Services
Information Technology
Inception To Date
Interactive Voice Response
Knowledge Center
Kilo-Volts-Amps Reactive
Line of Business
Acronym
MARA
MDMS
MLPP
MPSC
MV-90
MVI
NEMS
NIC
OIR
OIS
OMT
Ops
OSHA
PCR
PCT
PDP
PDR
PE
PMO
PTR
QBR
RCDC2
Rev.
RF
RFA
RV
SBA
SM
SM Apps
SMU
SR
TBD
TechArch
TIC
TLM
TOU
UIQ
UTC
YTD
Definition
My Account Re-Architecture
Meter Data Management System
Meter Location Problem Project
Meter Power Status Check
Multi Vendor - 90
Motor Vehicle Incidents
Net Energy Metering Services
Network Interface Card
Order Instituting Rulemaking
Outage Information System
Outage Management Tools
Operations
Occupational Safety and Health Administration
Project Change Request
Programmable Communicating Thermostat
Peak Day Pricing
Project Decision Request
Perfomance Engineering Company
Project Management Office
Peak Time Rebate
Quarterly Business Review
Remote Disconnect Phase 2
Revision
Radio Frequency
Request For Authorization
Restoration Validation
SmartMeter Balancing Accounts
SmartMeter
SmartMeter Applications
SmartMeter Upgrade
Service Request
To Be Determined
Technical Architechture
Technology Innovation Center
Transformer Load Management
Time Of Use
Utility IQ - SSN software
Unable To Complete (meter installation)
Year-To-Date
Steering Committee May 2012 Report
14