Recipient information | Input |
---|---|
Total number of customers served by utility / utilities supporting the project | 1,237,703 |
Total number of residential customers served by utility / utilities supporting the project | 1,113,712 |
Total number of commercial customers served by utility / utilities supporting the project | 123,991 |
Total number of industrial customers served by utility / utilities supporting the project | 0 |
Total number of AMI smart meters installed and operational prior to the SGIG/SGD program | 0 |
AMI smart meters installed and operational | Quantity* | Cost |
---|---|---|
Total | 0 | $129,191,052 |
Residential | 533,691 | |
Commercial | 0 | |
Industrial | 0 |
AMI smart meter features operational | Feature enabled | # of meters with feature |
---|---|---|
Interval reads | Yes | 575,081 |
Remote connection/disconnection | Yes | 533,691 |
Outage detection/reporting | No | 0 |
Tamper detection | Yes | 575,081 |
AMI communication networks and data systems | Description | Cost |
---|---|---|
Backhaul communications description | Verizon is the backhaul vendor | $7,952,231 |
Meter communications network | One thousand, one hundred and thirty-four total network devices have been installed through Q4 2013. Meter deployment began in April 2012 with 575,081 electric meters installed at customer locations through Q4 2013. | |
Head end server | AMI Head-End System environments implemented. | $56,578,906 |
Meter data analysis system | Project successfully went live on 10/7/12. 319,802 customers have access to the SEM tools, 893,457 paper Home Energy Reports were sent to customers, and 41,452 email reports sent to customers as of Nov 30th. | |
Other IT systems and applications |
Web portal deployed and operational | Quantity* | Description |
---|---|---|
Customers with access to web portal | 448,630 | |
Customers enrolled in web portal | 197,838 | The Smart Energy Manager platform was deployed to customers in Q4 of 2012. The project went live on 10/8/12 and customers will gain access as meters are certified. The program will provide energy data/analytics, e-mailed reports, SMS/IVR high bill-alerts, and paper home energy reports. |
Customer systems installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Communication networks and home area networks | N/A | N/A | |
In home displays | 0 | $0 | |
Energy management device | 0 | N/A | |
Direct load control devices | 202,906 | There are 1,300 total direct load control devices installed through the end of this quarter. | $80,764,456 |
Programmable communicating thermostats | 144,482 | 1,143 programmable communicating thermostats were installed this quarter. | $43,438,918 |
Smart appliances | 0 | $0 |
Customer system communication networks | Description |
---|---|
Network characteristics within customer premise |
Pricing program | Customers with access | Customers enrolled | Description |
---|---|---|---|
Flat rate with Peak Time Rebates | 291,397 | 291,397 | Customers with flat Electric Supply rates will be able to earn Peak Time Rebates (PTRs) during certain time periods of the year. The PTRs will be calculated off of a customer-specific baseline usage and rewarded as a line-item credit on the customer's bill. |
Net Metering | 0 | 0 | Customers installing a qualified solar, wind or biomass electrical generating facility will be able to request Net Energy Metering, for which BGE will bill them the difference between the energy supplied by the Company and the electricity generated by the customer-generator during the applicable billing month. |
Time of Use rate with Peak Time Rebates | 23,402 | 23,402 | Customers with Time-of-Use Electric Supply rates will be able to earn Peak Time Rebates (PTRs) during certain time periods of the year. The PTRs will be calculated off of a customer-specific baseline usage and rewarded as a line-item credit on the customer's bill. |
Recipient information | Input |
---|---|
Total number of customers served by utility / utilities supporting the project | 1,237,703 |
Total number of residential customers served by utility / utilities supporting the project | 1,113,712 |
Total number of commercial customers served by utility / utilities supporting the project | 123,991 |
Total number of industrial customers served by utility / utilities supporting the project | 0 |
Total number of distribution circuits within utility service territory | 1,581 |
Total number of distribution substations | 227 |
Portion of distribution system with SCADA prior to SGIG/SGD program | 0 |
Portion of distribution system with distribution automation (DA) prior to SGIG/SGD program | 0 |
Electric distribution system | % | Description |
---|---|---|
Portion of distribution system with SCADA due to SGIG/SGD program | 0% | |
Portion of distribution system with DA due to SGIG/SGD program | 0% |
DA devices installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Automated feeder switches | 0 | None | $0 |
Automated capacitors | 0 | $0 | |
Automated regulators | 0 | $0 | |
Feeder monitors | 0 | $0 | |
Remote fault indicators | 0 | $0 | |
Transformer monitors (line) | 0 | $0 | |
Smart relays | 0 | ||
Fault current limiter | 0 | $0 | |
Other devices | 0 | $0 |
SCADA and DA communications network | Cost |
---|---|
Communications equipment and SCADA | $0 |
Distribution management systems integration | Integrated | Description |
---|---|---|
AMI | No | Distribution Management System. Currently, there is an Energy Control System that serves both Transmission and some Distribution substations. There is a Distribution Automation System that serves some Distribution substations and approximately half of the distribution feeders. Both the ECS and the DA system are an input device status to the Outage Management System. BGE will assess integration with the AMI system at a later date. |
Outage management system | No | Outage Management System integration is planned for Q2 of 2014 outside the build period for the Smart Grid Investment Grant. |
Distributed energy resource interface | No | |
Other | No |
Distribution automation features / functionality | Function enabled | Description |
---|---|---|
Fault location, isolation and service restoration (FLISR) | No | |
Voltage optimization | No | |
Feeder peak load management | No | |
Microgrids | No | |
Other functions | No |
* 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.