Indianapolis Power & Light Company
Recipient information |
Input |
||||
Total number of customers served by utility / utilities supporting the project |
467,833 |
||||
Total number of residential customers served by utility / utilities supporting the project |
416,500 |
||||
Total number of commercial customers served by utility / utilities supporting the project |
46,708 |
||||
Total number of industrial customers served by utility / utilities supporting the project |
4,625 |
||||
Total number of AMI smart meters installed and operational prior to the SGIG/SGD program |
|||||
AMI smart meters installed and operational |
Quantity* |
Cost |
|||
Total |
10,275 |
$3,618,226 |
|||
Residential |
3,817 |
||||
Commercial |
6,408 |
||||
Industrial |
50 |
||||
AMI smart meter features operational |
Feature enabled |
# of meters with feature |
|||
Interval reads |
Yes |
10,275 |
|||
Remote connection/disconnection |
No |
0 |
|||
Outage detection/reporting |
No |
0 |
|||
Tamper detection |
Yes |
10,275 |
|||
AMI communication networks and data systems |
Description |
Cost |
|||
Backhaul communications description |
$9,878,392 |
||||
Meter communications network |
None. |
||||
Head end server |
$0 |
||||
Meter data analysis system |
|||||
Other IT systems and applications |
|||||
Web portal deployed and operational |
Quantity* |
Description |
|||
Customers with access to web portal |
470,000 |
||||
Customers enrolled in web portal |
2,684 |
||||
Customer systems installed and operational |
Quantity* |
Description |
Cost |
||
Communication networks and home area networks |
N/A |
No longer in scope. |
N/A |
||
In home displays |
0 |
No longer in scope. |
$0 |
||
Energy management device |
N/A |
||||
Direct load control devices |
0 |
Not in scope. |
$0 |
||
Programmable communicating thermostats |
0 |
No longer in scope. |
$0 |
||
Smart appliances |
|||||
Customer system communication networks |
Description |
||||
Network characteristics within customer premise |
No longer in scope. |
||||
| Pricing program | Customers with access |
Customers enrolled |
Description |
||
| Electric Vehicle Tariff TOU | 465,000 | 98 | |||
Distributed energy resources |
Quantity* |
Capacity |
Description |
Cost |
|
Distributed generation |
kW |
||||
Energy storage |
kW |
||||
Plug in electric vehicle charging points |
kW |
||||
Distributed energy resource interface |
N/A |
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.
Recipient information |
Input |
||||
Total number of customers served by utility / utilities supporting the project |
467,833 |
||||
Total number of residential customers served by utility / utilities supporting the project |
416,500 |
||||
Total number of commercial customers served by utility / utilities supporting the project |
46,708 |
||||
Total number of industrial customers served by utility / utilities supporting the project |
4,625 |
||||
Total number of distribution circuits within utility service territory |
400 |
||||
Total number of distribution substations |
88 |
||||
Portion of distribution system with SCADA prior to SGIG/SGD program |
|||||
Portion of distribution system with distribution automation (DA) prior to SGIG/SGD program |
|||||
Electric distribution system |
% |
Description |
|||
Portion of distribution system with SCADA due to SGIG/SGD program |
0.00% |
The project does not include SCADA deployment. |
|||
Portion of distribution system with DA due to SGIG/SGD program |
26.00% |
||||
DA devices installed and operational |
Quantity* |
Description |
Cost |
||
Automated feeder switches |
184 |
$15,158,850 |
|||
Automated capacitors |
1,308 |
$5,931,260 |
|||
Automated regulators |
69 |
||||
Feeder monitors |
|
||||
Remote fault indicators |
0 |
||||
Transformer monitors (line) |
14 |
$771,965 |
|||
Smart relays |
538 |
||||
Fault current limiter |
|
||||
Other devices |
63 |
$555,360 |
|||
SCADA and DA communications network |
Cost |
||||
Communications equipment and SCADA |
$3,379,838 |
||||
Distribution management systems integration |
Integrated |
Description |
|||
AMI |
|||||
Outage management system |
No |
AMR and AMI data will be integrated with IPL's existing OMS through the MDMS. Planning has begun. |
|||
Distributed energy resource interface |
|
||||
Other |
|||||
Distribution automation features / functionality |
Function enabled |
Description |
|||
Fault location, isolation and service restoration (FLISR) |
No |
Not planned in the project. |
|||
Voltage optimization |
No |
Not planned in the project. |
|||
Feeder peak load management |
No |
Not planned in the project. |
|||
Microgrids |
|||||
Other functions |
|||||
* 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.
