Data reported by:
Northern Virginia Electric Cooperative
| Recipient information | Input |
|---|---|
| Total number of customers served by utility / utilities supporting the project | 143,196 |
| Total number of residential customers served by utility / utilities supporting the project | 132,508 |
| Total number of commercial customers served by utility / utilities supporting the project | 10,688 |
| Total number of industrial customers served by utility / utilities supporting the project | 0 |
| Total number of distribution circuits within utility service territory | 235 |
| Total number of distribution substations | 53 |
| Portion of distribution system with SCADA prior to SGIG/SGD program | 100 |
| Portion of distribution system with distribution automation (DA) prior to SGIG/SGD program | 28 |
| Electric distribution system | % | Description |
|---|---|---|
| Portion of distribution system with SCADA due to SGIG/SGD program | 0% | |
| Portion of distribution system with DA due to SGIG/SGD program | 100.00% | Represented by the percentage of the 29 substations (37 under the revised project scope) that are automated under the SGIG program: substation server, voltage regulator controls, form 6 controls, transformer gas monitors, battery bank monitors, digital recloser controls, ethernet switches. |
| DA devices installed and operational | Quantity* | Description | Cost |
|---|---|---|---|
| Automated feeder switches | 14 | Voltage regulator controls, form 6 controls, transformer gas monitors, battery bank monitors, digital recloser controls, ethernet switches, smart reclosers (triple-single), switched capacitor banks, motor-operated air break switches. | $371,454 |
| Automated capacitors | 164 | $2,010,702 | |
| Automated regulators | 340 | $1,054,000 | |
| Feeder monitors | 0 | $0 | |
| Remote fault indicators | 0 | $0 | |
| Transformer monitors (line) | 56 | $1,288,000 | |
| Smart relays | 25 | ||
| Fault current limiter | 0 | $0 | |
| Other devices | 169 | $2,085,146 |
| SCADA and DA communications network | Cost |
|---|---|
| Communications equipment and SCADA | $1,144,944 |
| 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) | No | |
| Voltage optimization | Yes | NOVEC is installing automated voltage regulator controls that offer complete remote access functionality and extensive DNP operational and non-operational data that will reduce monthly inspection times and vehicle trips to make setting changes. |
| Feeder peak load management | Yes | The automated regulator controls offer the ability to set the exact allowable voltage reduction per phase of a circuit based on the engineering model calculation to maximize the peak demand reduction and yet maintaining proper voltage to the consumers. |
| 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.
