Data reported by:
EPB
EPB (Smart Grid Project)
| Recipient information | Input |
|---|---|
| Total number of customers served by utility / utilities supporting the project | 172,079 |
| Total number of residential customers served by utility / utilities supporting the project | 149,147 |
| Total number of commercial customers served by utility / utilities supporting the project | 19,460 |
| Total number of industrial customers served by utility / utilities supporting the project | 3,472 |
| Total number of AMI smart meters installed and operational prior to the SGIG/SGD program | 0 |
| AMI smart meters installed and operational | Quantity* | Cost |
|---|---|---|
| Total | 175,116 | $41,861,000 |
| Residential | 152,450 | |
| Commercial | 22,584 | |
| Industrial | 82 |
| AMI smart meter features operational | Feature enabled | # of meters with feature |
|---|---|---|
| Interval reads | Yes | 175,116 |
| Remote connection/disconnection | No | 0 |
| Outage detection/reporting | Yes | 175,116 |
| Tamper detection | No | 0 |
| AMI communication networks and data systems | Description | Cost |
|---|---|---|
| Backhaul communications description | The backhaul network for the AMI system is a fiber optic network. Approximately 33%-50% of the meters will be directly connected to the fiber optic network through an ethernet connection to the ONT on the side of the house. | $36,978,920 |
| Meter communications network | Meter communication between meters occurs through an unlicensed 900MHz radio spectrum system. | |
| Head end server | Interactive system which will take a high volume of data from the smart meters in near real-time, quickly analyze this data for multiple applications, and then initiate appropriate actions through integration to other systems. The headend system is comprised of 4 HP G7 servers with 1 HP storage disk array. The system is capable of supporting all meter endpoints with 15 minute intervals and data storage for 3 months. | $7,188,000 |
| Meter data analysis system | ||
| Other IT systems and applications |
| Web portal deployed and operational | Quantity* | Description |
|---|---|---|
| Customers with access to web portal | 174,336 | |
| Customers enrolled in web portal | 139,478 | We have enabled our customer web portal to provide customers with access to their AMI interval data. As a result of our fiber communications, we are able to provide customer consumption data within 15 minutes of when the electricity is used. This feature provides more immediate feedback to customers of how their behavior impacts their electricity consumption. |
| Customer systems installed and operational | Quantity* | Description | Cost |
|---|---|---|---|
| Communication networks and home area networks | N/A | We have evaluated several products, but have not found any products that add significant value for our customers and as a result, have not installed any HAN equipment in customer homes. | N/A |
| In home displays | 0 | We have not installed any in-home displays at this time. We are currently evaluating options available at this time. | $0 |
| Energy management device | 0 | We have evaluated several products, but have not found any products that add significant value for our customers and as a result, have not installed any Energy Management Systems. | N/A |
| Direct load control devices | 0 | We have not installed any of the direct load control devices for the pilot. We pursued multiple options to provide a water heater direct load control program for our customers and to date have not identified a cost-effective incentive that is attractive to our customers. | $0 |
| Programmable communicating thermostats | 0 | We have not installed any of the direct load control devices for the pilot. We are investigating several different options for providing a thermostat that can be utilized to reduce EPB's peak demand. | $0 |
| Smart appliances | $0 |
| Customer system communication networks | Description |
|---|---|
| Network characteristics within customer premise | We have evaluated several products, but have not found any products that add significant value for our customers and as a result, have not installed any HAN equipment in customer homes. |
| Pricing program | Customers with access | Customers enrolled | Description |
|---|---|---|---|
| Time of Use Rate | 5,000 | 130 | This rate is currently available to residential customers. Although this rate will not be marketed to residential customers until the completion of the demand response program to control water heaters. This is an all energy rate and consists of a peak and off peak period for each month. There is about a 2.25 to 1 peak to off peak differential for the residential TOU rate. This rate has taken the place of the existing TOU rate for residential customers that is available on a system level. This rate is also available for small commercial customers and is structured similarly to the residential rate. |
| Recipient information | Input |
|---|---|
| Total number of customers served by utility / utilities supporting the project | 172,079 |
| Total number of residential customers served by utility / utilities supporting the project | 149,147 |
| Total number of commercial customers served by utility / utilities supporting the project | 19,460 |
| Total number of industrial customers served by utility / utilities supporting the project | 3,472 |
| Total number of distribution circuits within utility service territory | 309 |
| Total number of distribution substations | 117 |
| 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 | 100.00% | All 46 kv breakers and 12 kv breakers are monitored and controlled by the new SCADA system. In addition, all of the automated switches that are installed are monitored and controlled by the SCADA system. |
| Portion of distribution system with DA due to SGIG/SGD program | 100.00% | The scope of the project was to automate the fault isolation and service restoration function for all EPB's 46 kV and 12 kV circuits, not including EPB's downtown network or all-underground circuits. |
| DA devices installed and operational | Quantity* | Description | Cost |
|---|---|---|---|
| Automated feeder switches | 1,294 | 46kv: Motor operated switches were installed on the 46kv system to provide the fault isolation and service restoration functionality. 12kv: Pulse-closing reclosers were installed on the 12kv system to provide the fault isolation and service restoration functionality. | $48,426,000 |
| Automated capacitors | 0 | $0 | |
| Automated regulators | 0 | $0 | |
| Feeder monitors | 0 | $0 | |
| 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 | $1,488,000 |
| Distribution management systems integration | Integrated | Description |
|---|---|---|
| AMI | No | We implemented our DMS in October of 2013. We are planning to complete the interface from AMI in the first half of 2014. This will include integration from the AMI meters to provide customer voltage data to ensure that customers are receiving proper voltage. |
| Outage management system | No | The integration with OMS was implemented in August of 2013. This includes the outage notification from each AMI meter into the OMS and includes the ability to verify service restoration after any repairs are completed. |
| Distributed energy resource interface | No | |
| Other | No |
| Distribution automation features / functionality | Function enabled | Description |
|---|---|---|
| Fault location, isolation and service restoration (FLISR) | Yes | EPB's Smart Grid included the purchase and installation of automation software to perform the fault location, isolation and service restoration function. 46kv: EPB is using a centralized automation platform (provided by SEL). 12kv: EPB is using peer-to-peer communication and control (provided by S&C Electric). |
| Voltage optimization | No | EPB's SCADA replacement includes functionality to monitor voltage at telemetered points and issue controls to regulators to adjust for any that are outside of specified limits. |
| Feeder peak load management | Yes | EPB's SCADA replacement includes alarms to identify when feeder loading thresholds have been exceeded. |
| 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.
