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 | 0 |
AMI smart meters installed and operational | Quantity* | Cost |
---|---|---|
Total | 0 | $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 | Yes | 10,275 |
Outage detection/reporting | No | 0 |
Tamper detection | Yes | 10,275 |
AMI communication networks and data systems | Description | Cost |
---|---|---|
Backhaul communications description | 100% complete - IPL is installing Silver Spring Networks AMI 900 MHz mesh backhaul system with 240 meter data collectors (named relays) 47 distribution device data collectors (named e-bridges) and 36 access points to provide IP connections. | $12,448,655 |
Meter communications network | None. | |
Head end server | Silver Spring Networks AMI software system known as Utility IQ is installed to collect meter data and send it to the Meter Data Management System. The current version of UIQ is v 4.2.18. | $0 |
Meter data analysis system | ||
Other IT systems and applications | The existing Landis + Gyr Automated Meter Reading (AMR) system is integrated to CIS/Billing. AMR data is integrated with the MDMS. |
Web portal deployed and operational | Quantity* | Description |
---|---|---|
Customers with access to web portal | 470,000 | |
Customers enrolled in web portal | 8,899 | Website transformation is complete. IPL added an energy dashboard for customers to clearly see program offerings with participation information and links to enroll. In addition, the ability to report an outage on-line was added, on-line payment options are simpler, and new mobile applications were created for these tools. |
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 | 0 | N/A | |
Direct load control devices | 0 | Not in scope. | $0 |
Programmable communicating thermostats | 0 | No longer in scope. | $0 |
Smart appliances | 0 | $0 |
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 | EVX tariff is in place. This is a time based rate for a pilot program. There are three periods for summer and two periods for non-summer months. Summer- For all Peak kWh 12.150¢ per kWh For all Mid-Peak kWh 5.507¢ per kWh, For all Off-Peak kWh 2.331¢ per kWh. Non-summer: For all Peak kWh 6.910¢ per kWh For all Off-Peak kWh 2.764¢ per kWh. |
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 | 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% | The project does not include SCADA deployment. |
Portion of distribution system with DA due to SGIG/SGD program | 27.00% | All of the planned distribution automation devices have been installed which include a mid-point and tie point recloser per feeder. |
DA devices installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Automated feeder switches | 184 | Reclosers act as circuit breakers to isolate faults on a circuit, feeder relays provide system protection at substation level devices, capacitor controls automate voltage management efforts and network protectors isolate downtown underground network faults. DA - CBD Fault Indicators - Central Business District (CBD) fault indicators have been ordered but have not been installed yet. Expenses for engineering have been incurred. Transformer Monitors - equipment has been purchased. To date, three have been installed. Communication connections are underway. | $16,362,598 |
Automated capacitors | 1,308 | $5,931,260 | |
Automated regulators | 76 | $0 | |
Feeder monitors | 0 | $0 | |
Remote fault indicators | 3 | $0 | |
Transformer monitors (line) | 17 | $893,081 | |
Smart relays | 618 | ||
Fault current limiter | 0 | $0 | |
Other devices | 102 | $1,217,597 |
SCADA and DA communications network | Cost |
---|---|
Communications equipment and SCADA | $4,279,822 |
Distribution management systems integration | Integrated | Description |
---|---|---|
AMI | No | |
Outage management system | No | AMI data is expected to be integrated with IPL's existing OMS provided by CGI in 2014 or beyond. dSCADA and MDMS integration challenges caused this to be delayed. |
Distributed energy resource interface | No | |
Other | No | The existing Landis + Gyr Automated Meter Reading (AMR) system is integrated to CIS/Billing. AMR data is integrated with the MDMS. |
Distribution automation features / functionality | Function enabled | Description |
---|---|---|
Fault location, isolation and service restoration (FLISR) | No | IPL uses feeder relays and reclosers to identify and isolate faults. Switching may be completed remotely but requires manual intervention to restore sections of circuits. |
Voltage optimization | No | IPL is using remote load tap changer controls at substation transformers and distribution capacitor bank controls to slightly reduce system voltage and therefore peak demand during a limited number of hours per year when conditions warrant it. AMI meters are used to verify voltages at customer service points are still within standard limits. |
Feeder peak load management | No | Not planned in the project. |
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.