Recipient information | Input |
---|---|
Total number of customers served by utility / utilities supporting the project | 1,138,112 |
Total number of residential customers served by utility / utilities supporting the project | 985,885 |
Total number of commercial customers served by utility / utilities supporting the project | 148,356 |
Total number of industrial customers served by utility / utilities supporting the project | 3,871 |
Total number of distribution circuits within utility service territory | 1,960 |
Total number of distribution substations | 194 |
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 | 81.62% | NSTAR will report this metric as the percent of feeders in the project and in NSTAR's system with SCADA. |
Portion of distribution system with DA due to SGIG/SGD program | 0% | "This metric will track and report the project and system percentages for the number of circuits with Mode 3 capabilities, since only circuits enhanced with ""Mode 3"" capabilities as part of the Self-Healing effort will be capable of performing auto-restoration without human intervention." |
DA devices installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Automated feeder switches | 360 | This includes ASUs, VFIs, RTUs, Reclosers and PME-9 switches. These device installations can be remotely controlled through two-way communication radios, which allows dispatchers to switch main line circuits and restore the greatest number of customers possible. | $14,269,782 |
Automated capacitors | 109 | $1,273,746 | |
Automated regulators | 0 | $0 | |
Feeder monitors | 360 | $0 | |
Remote fault indicators | 360 | $0 | |
Transformer monitors (line) | 0 | $0 | |
Smart relays | 0 | ||
Fault current limiter | 0 | $0 | |
Other devices | 100 | $321,006 |
SCADA and DA communications network | Cost |
---|---|
Communications equipment and SCADA | $4,259,232 |
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 | The automated feeder switches are expected to enable and improve FLISR capabilities. The Company has a total of nearly 1950 distribution class active circuits. Approximately 1500 of these circuits are SCADA controlled meaning that the feed breaker or recloser is monitored and controlled by SCADA. In addition, approximately 680 of the distribution circuits have radio controlled switching devices that monitor loads and provide fault indications. |
Voltage optimization | Yes | The dispatchable capacitor bank aspect of the project is expected to allow further optimization of distribution characteristics such as reductions in line losses and reactive power. The Company has installed 92 capacitor controls on 69 circuits in the Southern portion of the service terrritory. This consists of either replacing the entire fixed bank with a pager controlled bank or retrofitting the existing bank with a switch that enables it to be pager controlled. This allows the capacitor banks to be dispatched on a daily basis rather than switched in or out of service four times a year. |
Feeder peak load management | Yes | Feeder load will be managed by transferring load to adjacent feeders in cases where a feeder is experiencing an overload condition. This management will not be automated and will require manual intervention vs. an automatic algorithim. |
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.