AMI smart meters installed and operational | Quantity* | Cost |
---|---|---|
Total | 0 | $4,325,812 |
Residential | 12,192 | |
Commercial | 1,225 | |
Industrial | 0 |
AMI smart meter features operational | Feature enabled | # of meters with feature |
---|---|---|
Interval reads | Yes | 13,417 |
Remote connection/disconnection | Yes | 13,417 |
Outage detection/reporting | Yes | 13,417 |
Tamper detection | Yes | 13,417 |
AMI communication networks and data systems | Description | Cost |
---|---|---|
Backhaul communications description | Hybrid of Fiber and Wireless Raven radio with network carrier | $229,438 |
Meter communications network | Landis+Gyr Gridstream RF 900MHz - Collectors and Routers | |
Head end server | Landis+Gyr Command Center | $4,495,652 |
Meter data analysis system | The project AMI was incorporated into the existing AMR – MDA interfaces. AMI daily register reads and 15-min interval reads are loaded into MDA (DataRaker) on a daily basis. | |
Other IT systems and applications | Data Mining and Analysis Tool (DataRaker) covered by the MDA |
Web portal deployed and operational | Quantity* | Description |
---|---|---|
Customers with access to web portal | 12,036 | |
Customers enrolled in web portal | 2,109 | Tendril Energize Web Portal |
Customer systems installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Communication networks and home area networks | N/A | Zigbee SEP 1.0 | N/A |
In home displays | 620 | Tendril InSight | $299,363 |
Energy management device | 0 | N/A | N/A |
Direct load control devices | 132 | Tendril Volt | $173,739 |
Programmable communicating thermostats | 115 | Tendril Setpoint | $698,075 |
Smart appliances | 0 | N/A | $0 |
Customer system communication networks | Description |
---|---|
Network characteristics within customer premise | Zigbee SEP 1.0 |
Pricing program | Customers with access | Customers enrolled | Description |
---|---|---|---|
Time of Use Rate | 12,192 | 127 | A new residential TOU rate is being piloted as part of this project to augment the evaluation of customer information systems and control devices. |
Distributed energy resources | Quantity* | Capacity | Description | Cost |
---|---|---|---|---|
Distributed generation | 7 | 138 kW | $0 | |
Energy storage | 1 | 1,000 kW | $7,725,233 | |
Plug in electric vehicle charging points | 10 | 133 kW | $125,431 | |
Distributed energy resource interface | N/A | N/A | Tendril Volt | $4,547,936 |
Electric distribution system | % | Description |
---|---|---|
Portion of distribution system with SCADA due to SGIG/SGD program | 100.00% | Distribution SCADA has been deployed to all field devices in the project area. |
Portion of distribution system with DA due to SGIG/SGD program | 100.00% | DA capabilities are installed on all project circuits. |
DA devices installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Automated feeder switches | 20 | There is a mix of communicating and automated capacitors, faulted circuit indicators, and reclosers across the project area. | $1,317,198 |
Automated capacitors | 29 | $139,042 | |
Automated regulators | 0 | $0 | |
Feeder monitors | 0 | $49,742 | |
Remote fault indicators | 96 | $0 | |
Transformer monitors (line) | 0 | $2,378,429 | |
Smart relays | 63 | ||
Fault current limiter | 0 | $0 | |
Other devices | 0 | $0 |
SCADA and DA communications network | Cost |
---|---|
Communications equipment and SCADA | $1,845,043 |
Distribution management systems integration | Integrated | Description |
---|---|---|
AMI | Yes | DMS is integrated with multiple project and legacy systems including AMI, DERM, OMS, and energy storage. |
Outage management system | Yes | AMI is integrated with enterprise OMS. An additional project OMS (redundant) will also be implemented in conjunction with a DMS. The project AMI was incorporated into the existing AMR to enterprise OMS interfaces including meter outage alerts and meter “ping” functionality to verify power restoration. |
Distributed energy resource interface | No | All DG installed is non-dispatchable utility-owned PV that is being metered separately. All project EV chargers are installed behind customer meters. Most interfaces currently limited to measuring data. EV chargers may be remotely deactivated to curtail load. |
Other | No | Data Mining and Analysis Tool (DataRaker) covered by the MDA |
Distribution automation features / functionality | Function enabled | Description |
---|---|---|
Fault location, isolation and service restoration (FLISR) | No | As part of the project, the DMS enables FLISR across project circuits. This will reduce outages and outage response time, and improve overall system performance. |
Voltage optimization | Yes | As part of the project, the DMS enables voltage optimization across project circuits. This will improve power factor as well as enable voltage conservation. |
Feeder peak load management | No | As part of the project, the DMS enables dynamic feeder load transfer across project circuits. This will reduce outages on project feeders, reduce stress on critical assets, and improve maintenance. |
Microgrids | No | N/A |
Other functions | No | 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.