AMI smart meters installed and operational | Quantity* | Cost |
---|---|---|
Total | 0 | $118,400,057 |
Residential | 766,966 | |
Commercial | 17,287 | |
Industrial | 0 |
AMI smart meter features operational | Feature enabled | # of meters with feature |
---|---|---|
Interval reads | Yes | 784,253 |
Remote connection/disconnection | Yes | 784,253 |
Outage detection/reporting | Yes | 784,253 |
Tamper detection | Yes | 784,253 |
AMI communication networks and data systems | Description | Cost |
---|---|---|
Backhaul communications description | PECO’s AMI Network is comprised of a meter communications network and a backhaul network. The purpose of the backhaul network is to transmit data from the data collection devices in the meter communications network back to PECO’s business systems. PECO’s AMI backhaul network is a SONET fiber network combined with WiMAX wireless and microwave technologies. The wireless network segments link PECO’s remote data collectors, Tower Gateway Base stations, to PECO’s SONET fiber network. | $49,330,241 |
Meter communications network | PECO’s AMI Network is comprised of a meter communications network and a backhaul network. The purpose of the meter communications network is to provide a communications path from the smart meters and other endpoint devices, such as reclosers, to a data collection device that bundles data for delivery to PECO’s smart meter and/or distribution automation database(s) via the backhaul network. PECO’s meter communications network is provided by Tower Gateway Basestations that communicate with the endpoints over a licensed frequency in the 900MHz portion of the radio spectrum. | |
Head end server | Headend system controls communications with meters via the data collection devices (TGBs), monitors the health of the network, stores meter reading information temporarily before transport to a meter data management system and processes meter/network event information. | $93,823,165 |
Meter data analysis system | Not deployed or operational | |
Other IT systems and applications | N/A |
Web portal deployed and operational | Quantity* | Description |
---|---|---|
Customers with access to web portal | 784,253 | |
Customers enrolled in web portal | 238,988 | Same as system. |
Customer systems installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Communication networks and home area networks | N/A | N/A | N/A |
In home displays | 196 | The ENVI In-home Display Device is a dedicated display device designed to deliver energy consumption information in real time to a residential customer. A wireless signal is sent every six seconds from a transmitter communicating with the electricity meter to the display. This enables the customer to view energy consumption easily, showing changes in power consumption when different electrical appliances are used. | $56,149 |
Energy management device | 60 | VPower System - web-based system that optimizes the controllable resources at a location and sends controlling signals to a customer system(s) (Building Automation System or BAS, controllable devices, etc.) | N/A |
Direct load control devices | 60 | Additional load meters, devices that can be cycled or controlled by a utility or third party. | $768,912 |
Programmable communicating thermostats | 0 | $0 | |
Smart appliances | 0 | $0 |
Customer system communication networks | Description |
---|---|
Network characteristics within customer premise | N/A |
Pricing program | Customers with access | Customers enrolled | Description |
---|---|---|---|
Flat Rate | 773,184 | 492,234 | Same as system. |
Net Metering | 773,184 | 1,636 | Same as system. |
Distributed energy resources | Quantity* | Capacity | Description | Cost |
---|---|---|---|---|
Distributed generation | 0 | 0 kW | $0 | |
Energy storage | 0 | 0 kW | $0 | |
Plug in electric vehicle charging points | 3 | 9 kW | $51,754 | |
Distributed energy resource interface | N/A | N/A | Additional load meters, devices that can be cycled or controlled by a utility or third party. | $0 |
Electric distribution system | % | Description |
---|---|---|
Portion of distribution system with SCADA due to SGIG/SGD program | 0% | PECO is unable to measure the Portion of system with SCADA at the project level. |
Portion of distribution system with DA due to SGIG/SGD program | 0% | PECO is unable to measure the portion of system with DA at the project level. |
DA devices installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Automated feeder switches | 100 | Automated Feeder Switches (Reclosers), Automated Capacitors, Smart Relays and Controller Upgrades. | $8,177,977 |
Automated capacitors | 63 | $4,123,912 | |
Automated regulators | 0 | $0 | |
Feeder monitors | 0 | $0 | |
Remote fault indicators | 0 | $0 | |
Transformer monitors (line) | 0 | $2,753,027 | |
Smart relays | 221 | ||
Fault current limiter | 0 | $0 | |
Other devices | 399 | $54,328,635 |
SCADA and DA communications network | Cost |
---|---|
Communications equipment and SCADA | $790,565 |
Distribution management systems integration | Integrated | Description |
---|---|---|
AMI | No | "The Distribution Management System (DMS) is a collection of applications designed to monitor and control the distribution network to improve operational efficiency and reliability resulting in a ""self-healing network""." |
Outage management system | Yes | "Outage events are created in the Outage Management System upon receipt of a ""power fail"" message from the AMI meter." |
Distributed energy resource interface | No | |
Other | No | N/A |
Distribution automation features / functionality | Function enabled | Description |
---|---|---|
Fault location, isolation and service restoration (FLISR) | No | |
Voltage optimization | No | Not deployed or operational. |
Feeder peak load management | No | Not deployed or operational. |
Microgrids | No | |
Other functions | No | N/A |
* In some circumstances, costs are incurred before devices are installed resulting in a reported cost where the quantity is zero.
* All dollar figures are the total cost, which is the sum of the federal investment and cost share of the recipient (the recipient cost share must be at least 50% of the total overall project cost).
** In some cases the number of entities reporting is greater than the total number of projects funded by the Recovery Act because some projects have multiple sub-projects that report data. View list of sub-projects.