AMI smart meters installed and operational | Quantity* | Cost |
---|---|---|
Total | 0 | $0 |
Residential | 0 | |
Commercial | 0 | |
Industrial | 0 |
AMI smart meter features operational | Feature enabled | # of meters with feature |
---|---|---|
Interval reads | No | 0 |
Remote connection/disconnection | No | 0 |
Outage detection/reporting | No | 0 |
Tamper detection | No | 0 |
AMI communication networks and data systems | Description | Cost |
---|---|---|
Backhaul communications description | Since NSTAR only expects to deploy a small number of AMI meters as part of this project, NSTAR is not replacing or upgrading its back?end metering systems as part of this project. | $0 |
Meter communications network | Since NSTAR only expects to deploy a small number of AMI meters as part of this project, NSTAR is not replacing or upgrading its back?end metering systems as part of this project. | |
Head end server | Since NSTAR only expects to deploy a small number of AMI meters as part of this project, NSTAR is not replacing or upgrading its back?end metering systems as part of this project. | $0 |
Meter data analysis system | Since NSTAR only expects to deploy a small number of AMI meters as part of this project, NSTAR is not replacing or upgrading its back?end metering systems as part of this project. | |
Other IT systems and applications | Meters will not be integrated with NSTAR’s system in this way. |
Distributed energy resources | Quantity* | Capacity | Description | Cost |
---|---|---|---|---|
Distributed generation | 0 | 0 kW | $0 | |
Energy storage | 0 | 0 kW | $0 | |
Plug in electric vehicle charging points | 0 | 0 kW | $0 | |
Distributed energy resource interface | N/A | N/A | $0 |
Electric distribution system | % | Description |
---|---|---|
Portion of distribution system with SCADA due to SGIG/SGD program | 0% | Not Applicable |
Portion of distribution system with DA due to SGIG/SGD program | 0% | Not Applicable |
DA devices installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Automated feeder switches | 0 | Not Applicable | $0 |
Automated capacitors | 0 | $0 | |
Automated regulators | 0 | $0 | |
Feeder monitors | 436 | $7,339,217 | |
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 | $0 |
Distribution management systems integration | Integrated | Description |
---|---|---|
AMI | No | Meters will not be integrated with NSTAR’s system in this way. |
Outage management system | No | Meters will not be integrated with NSTAR’s system in this way. |
Distributed energy resource interface | No | NSTAR does not currently own or plan to own any DG. All DG on the system is customer?owned. Thus, NSTAR will track and report this metric at the system level, but not the project level. |
Other | No | Meters will not be integrated with NSTAR’s system in this way. |
Distribution automation features / functionality | Function enabled | Description |
---|---|---|
Fault location, isolation and service restoration (FLISR) | No | Not Applicable |
Voltage optimization | No | Not Applicable |
Feeder peak load management | No | Not Applicable |
Microgrids | No | Not Applicable |
Other functions | No | Not Applicable |
* 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.