Transcript AMR Advanced Applications – Taking it a Step Beyond David Glenwright AMR Operations & Strategies NARUC July 15, 2007

AMR Advanced Applications
– Taking it a Step Beyond
David Glenwright
AMR Operations & Strategies
NARUC
July 15, 2007
Topics
 Background
 AMR at PECO
 Advanced Applications
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Outage Management
Theft Detection
Engineering Studies
Other Opportunities
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Exelon / PECO Background
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Subsidiary of Exelon Corp (NYSE: EXC)
Serving southeastern Pa. for over 100 years
Electric and Gas Utility
2,400 sq. mi. service territory
Philadelphia and the four surrounding counties
Population of approx. 4 million people
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Customer Profile
Service Area
Philadelphia & Southeastern PA
2,400 sq. mile service area
Customers
Electric = 1.7 million
Gas = 500 thousand
Automated Meters
2.2 million meters on Cellnet Fixed Network
3,000 Large C&I customers on MV- 90 & Metretek
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Scope of AMR at PECO
 PECO’s AMR installation project lasted from 1999 to 2003
 A Cellnet Fixed Network solution was selected.
• 99% of meters are read by the network
• Others are drive-by and MV-90 dial-up
 During the project, meters were activated at a max rate of 143,500 per
month.
 Installation was performed by PECO, Cellnet, and VSI.
 Cellnet manages the network, performs meter maintenance and
provide data to PECO.
 All meters are read daily. Additional features include on-demand
reads, and event processing.
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Cellnet AMR Network Structure
Exelon
Applications
National
Operations Center (NOC)
System
Controller
Cell Master (CM)
MicroCell
Controller (MCC)
Wide Area
Network
Endpoint devices
w/CellNet Radio
Local Area
Network
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AMR network components
2.2 M Meters
~1.6 M Res. Electric
~455 K Res. Gas
~135 K Com. Electric
~42K Com. Gas
91 Cell Masters
8,318 MicroCell
Controllers
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Business Benefits of AMR
Customer Interface
Operational / System Reliability
Minimize inconvenience to customers who
have difficult to read meters
Reduce number of estimated bills
Improve ability to answer questions on 1st
call
Provide more energy usage info
Improve customer satisfaction
Improve read rate and accuracy
Reduce CAIDI by identifying, assessing
and responding to outages more efficiently
Improve productivity of field forces
Reduce customer call volumes
Reduce safety incidences
•Increase asset utilization
•Improve ability to design electric
distribution network
•Identify precursors to reliability event
Financial Management
Improve the meter to cash cycle
Continuous service - controls
Increase revenue
 Improve power factor measurement
Reduce lost revenue from theft
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Outage Management
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Outage Example
TRF-2
CALL-3
CALL-8
CALL-9
CALL-1
CALL-4
Event Time: 11:49:00
00:00:00
11:27:00
11:31:00
11:35:00
11:38:00
11:43:00
TRF-1
CALL-5
CALL-6
CALL-7
CALL-2
FUSE
Customers Affected: 086
000
001
002
003
004
005
006
018
019
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Outage Example w/AMR
CALL-3
CALL-1
LG-1
CALL-4
TRF-2
Event Time: 11:34:00
00:00:00
11:27:00
11:30:00
11:31:00
CALL-2
TRF-1
LG-3
LG-2
FUSE
Customers Affected: 086
000
001
002
003
012
013
014
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PECO’s Outage Management Process
AMR Initiated Event
SCADA
AMR
Last Gasp
Call Center
AMR Initiated Event
Outage
Record
OMS
Dispatch
AMR
PowerUp
IVR
PECO
Contacts
Customer
Customer Initiated Calls
AMR Ping
Advanced
Assessment
Tools
Automatic
Processing
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“Summer Slam” - July 18, 2006
A severe band of thunderstorms caused nearly 400,000 power outages.
Determined to be the worst summer storm ever experienced by PECO.
 1,200+ single customer outage calls were cancelled without crew dispatch due to
meter pings that indicated power-on.
 750+ single customer outage calls were escalated into primary events via pings to
neighboring customer’s meters. This ensured a properly skilled crew was dispatched
the first time.
 The pinging and restoration verification tools were used to confirm active jobs were
valid prior to crew dispatch. Feedback from the field crews indicated that they
felt like they were working more effectively because they had very few
assignments that were “OK on arrival”.
 Conservative estimates indicate that AMR has helped save in excess of $200,000 in
avoided labor costs during this storm.
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AMR Outage Management Summary
 Improved outage management performance
 Quicker response due to last gasp
 More efficient use of field crews due to pinging (automated &
manual)
 Validate power restoration times using daily reports
 Reduced CAIDI by 5.5 minutes in 2005
Single Outages Cancelled
Outages Escalated
2004
5,450
1,100
2005
6,184
2,418
2006
11,584
4,532
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Theft Detection
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Revenue Assurance
 Theft detected during initial AMR installation
 Initial focus of using various meter tamper flags to detect
potential theft of service proved ineffective
 Cellnet & PECO developed more advanced tools looking at
irregular usage patterns combined with tamper flags
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Repeated outages
Unexplained usage
Customer Load Profile / Irregular Load Shape
Repetitive Flags
 Analysis is used to direct Revenue Protection crews to suspect
areas
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Revenue Assurance Reports
No Weekend Usage
Outage & Reverse Rotation
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Revenue Assurance Reports
Irregular Usage
No Read-Window Usage
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Examples of Customer Bills
117%
After Corrections
96.4%
After Corrections
128%
After Corrections
DATE
07/25
06/24
05/24
04/25
03/24
USAGE
8720
6667
4911
2646
2716
DAY
31
31
29
32
30
DAU
281.2
215.0
169.3
82.6
90.5
REVENUE
901.74
777.96
544.37
349.86
366.87
DATE
08/12
07/14
06/14
05/13
04/13
USAGE
1652
1412
981
575
335
DAY
29
30
32
30
30
DAU
56.9
47.0
30.6
19.1
11.1
REVENUE
241.34
205.68
141.62
79.89
48.69
DATE
08/17
07/18
06/16
05/17
04/15
USAGE
1391
1314
1026
678
373
DAY
30
32
30
32
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DAU
46.3
41.0
34.2
21.1
12.8
REVENUE
202.55
191.11
148.31
93.27
53.63
Prior to Corrections
Prior to Corrections
Prior to Corrections
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Engineering Studies
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Load Management
 The goal is to use AMR data to get a better understanding of
how the distribution system is operating.
 Visibility into individual distribution transformer and cable
loading is created
 The models are based on combination of actual customer
usage, billing data, SCADA-based substation information and
weather data.
 4 circuits in a dense, urban environment were modeled with
the Itron Distribution Asset Analysis Software
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Load Management Pilot
 PECO, Itron & Microsoft collaborated to conduct a
demonstration of the DAA application
 4 circuits in a dense, urban environment were modeled
• 7,500 customers
• 269 transformers
 Data Sources
• SCADA – 20 points input
• Daily and ½ hourly meter data
 Several enhancements were required to correctly model
the circuits:
• Virtual nodes to model Secondary Mains
• Interposing, Step-Down Transformers
• 2-Phase, Scott Connected Transformers
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Transformer Utilization
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Meter to Transformer Rollup
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Transformer Profile
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Preliminary DAA Results
 DAA predicted overloads on 2 of the 5 transformers that
failed in summer ’06 on one of the demonstration circuits
• 1 transformer failed just after midnight, customers experienced a 4
hour interruption
 DAA provided secondary main loading data that was
previously unavailable
• Heavily loaded mains are now under analysis
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Interval Data Pilot
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SpringGard
Old City
Chinatown
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Outage Prediction
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Outage Prediction
 AMR Last-Gasp and Power-Up Messages
• 750,000 Last-Gasps Annually, 5% associated with
actual outages
• 6,000,000+ Power-Up Annually
 Why? What do these messages mean?
 Precursors
• Demonstrated to give advance notice
• Need to develop means to interpret these messages
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High Density of Power-Up Messages
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Outage Vs Power-Up Messages
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Orphan Meter Analysis
 Orphan meters are read by the AMR Network, but there is
no corresponding customer location information
• Affected customers may receive estimated bills
• New meter sets may go unbilled – lost revenue
 Analysis Process:
• Map AMR network elements that are ‘hearing’ orphan meters
• Overlay known meter locations vs. tax parcel & vacancy data
• Identify occupied tax parcels that do not have meters that are
within the range of the network device
 Results are used to direct field area investigations
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Orphan Meter Analysis
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Smart Grid
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Urban Utilinet Trial
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Sample Manhole Installation
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PECO Utilinet Pilot
Demonstrate that the following devices can operate
simultaneous via a single smart network:
 Distribution Automation
• Reclosers (Monitoring & Control)
• Unit Substations (Monitoring & Control)
• Faulted Circuit Indicators
 Meter Reading
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Current Meter Reading Functions
Remote Disconnect/Reconnect Meters
Interval Data/Demand Response
Voltage Sensing
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Jenkintown Area
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Closing Thought
There continues to be a wealth of
opportunities to extract real business value
from AMI, well beyond what is being
delivered today.
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Contact Information
David Glenwright
Manager, AMR Operations & Strategies
Email: [email protected]
Phone: 215-841-6174
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