Recipient information | Input |
---|---|
Total number of customers served by utility / utilities supporting the project | 7,133 |
Total number of residential customers served by utility / utilities supporting the project | 6,110 |
Total number of commercial customers served by utility / utilities supporting the project | 921 |
Total number of industrial customers served by utility / utilities supporting the project | 102 |
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 | 0 | $1,199,650 |
Residential | 6,318 | |
Commercial | 1,054 | |
Industrial | 102 |
AMI smart meter features operational | Feature enabled | # of meters with feature |
---|---|---|
Interval reads | Yes | 7,474 |
Remote connection/disconnection | Yes | 2,754 |
Outage detection/reporting | Yes | 7,474 |
Tamper detection | Yes | 7,474 |
AMI communication networks and data systems | Description | Cost |
---|---|---|
Backhaul communications description | Auburn will use their Fiber to the Home network to backhaul data from IP collectors deployed throughout the system. Network is 100% with full IP collector deployment completed in final build out zone in January 2015. | $144,704 |
Meter communications network | 900 MHz meter to meter | |
Head end server | Network server (HP) with a Linux operating system and Oracle database | $344,458 |
Meter data analysis system | Training completed on the AMI system and SCADA OMS system for the Auburn Customer representatives. This will allow them to assist customers with outage, power quality and consumption questions as they call and as the AMI deployment continues and more meters are continually added. Web portal access for all customers in place. | |
Other IT systems and applications | None |
Web portal deployed and operational | Quantity* | Description |
---|---|---|
Customers with access to web portal | 7,474 | |
Customers enrolled in web portal | 3,684 | MDM web portal is active for all electric customers. Usage information able to drill from monthly to daily to hourly to 15 minute interval. history and comparison data also available down to the daily interval. |
Customer systems installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Communication networks and home area networks | N/A | N/A | |
In home displays | 0 | $0 | |
Energy management device | 0 | N/A | |
Direct load control devices | 0 | $0 | |
Programmable communicating thermostats | 0 | $0 | |
Smart appliances | 0 | $0 |
Customer system communication networks | Description |
---|---|
Network characteristics within customer premise |
Pricing program | Customers with access | Customers enrolled | Description |
---|---|---|---|
Time of Use Rate | 2 | 1 | Auburn's largest industrial customer (MTA) is currently enrolled and using the TOU rate option listed in Rate code 45. By taking advantage of this option they have been able to see a savings on their wholesale power rate of 10.67% compared to the other rate code 45 customer that is not using the TOU option. |
Recipient information | Input |
---|---|
Total number of customers served by utility / utilities supporting the project | 7,133 |
Total number of residential customers served by utility / utilities supporting the project | 6,110 |
Total number of commercial customers served by utility / utilities supporting the project | 921 |
Total number of industrial customers served by utility / utilities supporting the project | 102 |
Total number of distribution circuits within utility service territory | 18 |
Total number of distribution substations | 6 |
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 substation and monitoring points integrated and operational in SCADA. |
Portion of distribution system with DA due to SGIG/SGD program | 20.00% | 5 substations relays have been upgraded to allow for automatic transfer trip from one source to another if a 138kV source is lost or a portion of the 69kV loop is lost. Data from the Capacitor banks also integrated into the DA data to show voltage levels and source location. |
DA devices installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Automated feeder switches | 5 | 10 capacitor banks with automatic controls have been installed and operational on the system. They are reporting voltage conditions back through SCADA with control functions added to each feeder in SCADA. SEL relays have been added to all substation feeders to detect fault locations and type in term from the substation. future plans will include associating the outage info from the AMI system. Additional end points integrated as AMI meters have been deployed and associated. Three automated switches installed along with 2 nodes at the substations at the end of the feeder with switches. Email alerts sent to line crews when voltage levels out of range and when operation other than normal state occurs. | $316,022 |
Automated capacitors | 10 | $284,964 | |
Automated regulators | 0 | $0 | |
Feeder monitors | 0 | $0 | |
Remote fault indicators | 0 | $0 | |
Transformer monitors (line) | 0 | $606,658 | |
Smart relays | 22 | ||
Fault current limiter | 0 | $0 | |
Other devices | 2 | $196,474 |
SCADA and DA communications network | Cost |
---|---|
Communications equipment and SCADA | $633,708 |
Distribution management systems integration | Integrated | Description |
---|---|---|
AMI | Yes | Distribution Management system for Auburn is Called UMS SCADA (Utility Management Sentinel). This system enables the utility staff to integrate existing SCADA functions with end point data from AMI and device information from switches and cap banks. System is fully operation in automatic mode as of December 9, 2013. |
Outage management system | Yes | AMI data has been integrated with the SCADA OMS screens to show meter and IP collector status. Reports are active to superintendant, line supervisor, and on call manager when an outage is detected. Additional email and text alerts go out with # of customers in outage and feeder # of outage location. |
Distributed energy resource interface | No | |
Other | No | None |
Distribution automation features / functionality | Function enabled | Description |
---|---|---|
Fault location, isolation and service restoration (FLISR) | Yes | 45 feeder relays use fault location to inform SCADA on fault location and switching of load from one source to another to reduce the number of customers in outage. |
Voltage optimization | Yes | Cap banks starting to go on-line and report data back to SCADA. Full optimization will not happen until AMI is complete and integrated into system on December 9, 2013. |
Feeder peak load management | Yes | Viewed in SCADA at this time, Control is turned off as training and screen configurations are taking place. Training complete and all functions fully operational and in AUTO mode. |
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.