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 | 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 | $12,602,334 |
Residential | 59,403 | |
Commercial | 5,731 | |
Industrial | 0 |
AMI smart meter features operational | Feature enabled | # of meters with feature |
---|---|---|
Interval reads | Yes | 65,134 |
Remote connection/disconnection | Yes | 65,134 |
Outage detection/reporting | No | 0 |
Tamper detection | No | 0 |
AMI communication networks and data systems | Description | Cost |
---|---|---|
Backhaul communications description | LUS's Fiber to the Home will provide the backhaul of all meter information. This system will be the integral part between the meters in the field and the AMI and MDMS system. | $454,218 |
Meter communications network | This system will use a RF mesh or tower LAN, Zigbee for customer interface network to the Home Area Networks. Zigbee has not been selected as the primary HAN communications; however, it is a highly probable selection. | |
Head end server | System will provide data storage, querying, command and control functionality. | $1,738,194 |
Meter data analysis system | System will be included in MDMS and will provide information on customer usage history including high and low usages, theft and any other meter occurrences. | |
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 | LUS will provide a web portal that will be available for all customers receiving AMI meters. Customers will receive information to better manage their energy usage. |
Customer systems installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Communication networks and home area networks | N/A | While LUS expects compatibility with the AMI and anticipates some customers to eventually purchase smart appliances and other in home devices, we do not intend to deploy any of these products as part of this project or expect to know when customers purchase them. | N/A |
In home displays | 0 | System provides historical, current, and month-to date energy usage, prices and peak event notification. | $0 |
Energy management device | 0 | N/A | |
Direct load control devices | 0 | System will consist of installing and monitoring Central Air Conditioning (CAC) DLC to mitigate power loading concerns during peaking hours throughout the year. | $0 |
Programmable communicating thermostats | 0 | $0 | |
Smart appliances | 0 | $0 |
Customer system communication networks | Description |
---|---|
Network characteristics within customer premise | While LUS expects compatibility with the AMI and anticipates some customers to eventually purchase smart appliances and other in home devices, we do not intend to deploy any of these products as part of this project or expect to know when customers purchase them. |
Pricing program | Customers with access | Customers enrolled | Description |
---|---|---|---|
Net Metering | 64,319 | 103 | In our MBRP, LUS did not propose a net metering rate. Currently, we use the net kWhs to bill our customers, carrying over any net excess generation on their part. |
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 | 0 |
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 | 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 | 9.80% | Currently, LUS only monitors the distribution feeders at the electrical substation. Data collection through installation records and/or system software registration log files. |
Portion of distribution system with DA due to SGIG/SGD program | 35.00% | DA coverage is only for 3-Phase main line circuits. DA for this project will only include the installation of Automated Capacitors and Fault Indicators. After completion, LUS will have monitoring capabilities at various points on the feeder through the deployment of automated capacitors and fault indicators. |
DA devices installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Automated feeder switches | 0 | Existing capacitor banks will be upgraded with communications and remote actuators on all feeders. | $0 |
Automated capacitors | 47 | $1,230,380 | |
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 | $40,353 |
Distribution management systems integration | Integrated | Description |
---|---|---|
AMI | No | |
Outage management system | No | System will be integrated with MDMS, AMI and CIS. |
Distributed energy resource interface | No | |
Other | No |
Distribution automation features / functionality | Function enabled | Description |
---|---|---|
Fault location, isolation and service restoration (FLISR) | No | This portion has been delayed because of the deployment of the AMI project and the inability to evaluate the Fault Indicators compatible with our AMI system. We are pursuing our options with our AMI vendor and deployment has been delayed until 3rd quarter 2014. |
Voltage optimization | No | Features will be deployed once all assets are installed and tested 3rd quarter 2014. |
Feeder peak load management | No | |
Microgrids | No | |
Other functions | No |
Recipient information | Input |
---|---|
Total miles of transmission line | 0 |
Total number of transmission substations | 3 |
Number of PMUs installed and operational before SGIG program | 0 |
Number of PDCs installed and operational before SGIG program | 0 |
Electric transmission system | Portion | Description |
---|---|---|
Portion of transmission system covered by phasor measurement systems | 7.00% |
Phasor measurement systems | Quantity* | Description | Cost |
---|---|---|---|
PMUs | 31 | N/A LUS does not operate any facilities above the 230kV level. | $0 |
Phasor data concentrators | 3 | Will allow for reliable data collection of the grid’s dynamic behavior in near-real time. | $0 |
Communications network | Systems will primarily be stand alone systems to minimize NERC CIP requirements. | $38,190 |
Other transmission assets | Quantity* | Description | Cost |
---|---|---|---|
Dynamic Capability Rating System (DCRS) - Transmission Lines | None | $0 | |
Other transmission assets | $0 | ||
Other transmission assets | 0 | $0 | |
Other transmission assets | 0 | $0 |
Angle/frequency monitoring | Operational | Description | Cost |
---|---|---|---|
Angle/frequency monitoring | Yes | $1,186,730 | |
Post-mortem analysis (including compliance monitoring) | Yes | ||
Voltage stability monitoring | No | ||
Thermal overload monitoring | No | ||
Improved state estimation | No | ||
Steady-state model benchmarking | No | ||
DG/IPP applications | No | ||
Power system restoration | 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.