Electric distribution system | % | Description |
---|---|---|
Portion of distribution system with SCADA due to SGIG/SGD program | 100.00% | There are approximately 124 connected RTUs and substation gateways. These installations include all of the District’s substations, all District switching stations, BPA delivery points, generation sites, key communications sites and a few distribution feeder installations. All District distribution substations have SCADA installed. Percentage of Distribution Substation with SCADA: 100% |
Portion of distribution system with DA due to SGIG/SGD program | 2.30% | The 90 square mile DA pilot area is complete. |
DA devices installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Automated feeder switches | 6 | The 90 square mile has equipped with automated feeder switches, automated regulators, feeder monitors, and remote fault indicators. | $868,223 |
Automated capacitors | 0 | $0 | |
Automated regulators | 13 | $868,223 | |
Feeder monitors | 45 | $868,223 | |
Remote fault indicators | 45 | $0 | |
Transformer monitors (line) | 0 | $11,292,165 | |
Smart relays | 382 | ||
Fault current limiter | 0 | $0 | |
Other devices | 0 | $0 |
SCADA and DA communications network | Cost |
---|---|
Communications equipment and SCADA | $4,433,853 |
Distribution management systems integration | Integrated | Description |
---|---|---|
AMI | No | |
Outage management system | No | |
Distributed energy resource interface | No | |
Other | No |
Distribution automation features / functionality | Function enabled | Description |
---|---|---|
Fault location, isolation and service restoration (FLISR) | Yes | All DA applications for Project area are operational and Phase II of the DMS (the actionable operation aspect) is currently being utilized in parallel with our manual system. Impact Metric reporting will document the benefits realized. |
Voltage optimization | Yes | All DA applications for Project area are operational and Phase II of the DMS (the actionable operation aspect) is currently being utilized in parallel with our manual system. Impact Metric reporting will document the benefits realized. |
Feeder peak load management | Yes | No automated feeder peak load management functionality was All DA applications for Project area are operational and Phase II of the DMS (the actionable operation aspect) is currently being utilized in parallel with our manual system. Impact Metric reporting will document the benefits realized. |
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.