Lafayette Consolidated Government
Recipient information |
Input |
||||
Total number of customers served by utility / utilities supporting the project |
62,403 |
||||
Total number of residential customers served by utility / utilities supporting the project |
51,550 |
||||
Total number of commercial customers served by utility / utilities supporting the project |
10,853 |
||||
Total number of industrial customers served by utility / utilities supporting the project |
|||||
Total number of AMI smart meters installed and operational prior to the SGIG/SGD program |
|||||
AMI smart meters installed and operational |
Quantity* |
Cost |
|||
Total |
61,037 |
$20,813,310 |
|||
Residential |
55,637 |
||||
Commercial |
5,400 |
||||
Industrial |
|||||
AMI smart meter features operational |
Feature enabled |
# of meters with feature |
|||
Interval reads |
Yes |
61,037 |
|||
Remote connection/disconnection |
No |
0 |
|||
Outage detection/reporting |
No |
0 |
|||
Tamper detection |
Yes |
61,037 |
|||
AMI communication networks and data systems |
Description |
Cost |
|||
Backhaul communications description |
$454,020 |
||||
Meter communications network |
|||||
Head end server |
System will provide data storage, querying, command and control functionality. |
$1,870,074 |
|||
Meter data analysis system |
|||||
Other IT systems and applications |
|||||
Web portal deployed and operational |
Quantity* |
Description |
|||
Customers with access to web portal |
0 |
||||
Customers enrolled in web portal |
0 |
||||
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 |
N/A |
||||
Direct load control devices |
0 |
$0 |
|||
Programmable communicating thermostats |
|
|
|||
Smart appliances |
|||||
Customer system communication networks |
Description |
||||
Network characteristics within customer premise |
|||||
| Pricing program | Customers with access |
Customers enrolled |
Description |
||
| Net Metering | 61,037 | 56 | |||
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 |
62,403 |
||||
Total number of residential customers served by utility / utilities supporting the project |
51,550 |
||||
Total number of commercial customers served by utility / utilities supporting the project |
10,853 |
||||
Total number of industrial customers served by utility / utilities supporting the project |
|||||
Total number of distribution circuits within utility service territory |
80 |
||||
Total number of distribution substations |
14 |
||||
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 |
9.80% |
||||
Portion of distribution system with DA due to SGIG/SGD program |
0.00% |
||||
DA devices installed and operational |
Quantity* |
Description |
Cost |
||
Automated feeder switches |
|
Existing capacitor banks will be upgraded with communications and remote actuators on all feeders. |
|||
Automated capacitors |
0 |
$0 |
|||
Automated regulators |
|
||||
Feeder monitors |
|
$0 |
|||
Remote fault indicators |
0 |
||||
Transformer monitors (line) |
|
||||
Smart relays |
|
||||
Fault current limiter |
|
||||
Other devices |
|
||||
SCADA and DA communications network |
Cost |
||||
Communications equipment and SCADA |
$0 |
||||
Distribution management systems integration |
Integrated |
Description |
|||
AMI |
|||||
Outage management system |
System will be integrated with MDMS, AMI and CIS. |
||||
Distributed energy resource interface |
|
||||
Other |
|||||
Distribution automation features / functionality |
Function enabled |
Description |
|||
Fault location, isolation and service restoration (FLISR) |
No |
||||
Voltage optimization |
No |
Features will be deployed once all assets are installed and tested 2nd quarter 2013. |
|||
Feeder peak load management |
|||||
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.
Recipient information |
Input |
||
Total miles of transmission line |
|||
Total number of transmission substations |
3 |
||
Number of PMUs installed and operational before SGIG program |
|||
Number of PDCs installed and operational before SGIG program |
|||
Electric transmission system |
Portion |
Description |
|
Portion of transmission system covered by phasor measurement systems |
5.00% |
||
Phasor measurement systems |
Quantity* |
Description |
Cost |
PMUs |
31 |
N/A LUS does not operate any facilities above the 230kV level. |
|
Phasor data concentrators |
3 |
Will allow for reliable data collection of the grid’s dynamic behavior in near-real time. |
|
Communications network |
Systems will primarily be stand alone systems to minimize NERC CIP requirements. |
$0 |
|
Other transmission assets |
Quantity* |
Description |
Cost |
Dynamic Capability Rating System (DCRS) |
|||
Other transmission assets |
34 |
$974,343 |
|
Other transmission assets |
$0 |
||
Other transmission assets |
|
$0 |
|
Advanced transmission applications operational |
Operational |
Description |
Cost |
Angle/frequency monitoring |
Yes |
$516,090 |
|
Post-mortem analysis (including compliance monitoring) |
Yes |
||
Voltage stability monitoring |
|
||
Thermal overload monitoring |
No |
||
Improved state estimation |
|
||
Steady-state model benchmarking |
|
||
DG/IPP applications |
|||
Power system restoration |
|
||
* 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.
