Recipient information | Input |
---|---|
Total number of customers served by utility / utilities supporting the project | 684,531 |
Total number of residential customers served by utility / utilities supporting the project | 596,852 |
Total number of commercial customers served by utility / utilities supporting the project | 82,836 |
Total number of industrial customers served by utility / utilities supporting the project | 4,843 |
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 | $8,596,241 |
Residential | 43,475 | |
Commercial | 4,406 | |
Industrial | 18 |
AMI smart meter features operational | Feature enabled | # of meters with feature |
---|---|---|
Interval reads | Yes | 47,899 |
Remote connection/disconnection | Yes | 46,109 |
Outage detection/reporting | Yes | 47,899 |
Tamper detection | Yes | 47,899 |
AMI communication networks and data systems | Description | Cost |
---|---|---|
Backhaul communications description | Westar will use the public wireless cellular infrastructure to provide WAN access to the AMI meters. Westar has contracted with a third party provider of cellular access to provide a Virtual Private Network(VPN). The data collection points will have non?routable IP addresses within the VPN. The VPN provides a secure tunnel for the transport of meter data to Westar. | $0 |
Meter communications network | The EnergyAxis system architecture was designed with distributed intelligence and distributed responsibility to provide fault tolerance from the meter through the EAMS. Intelligent self-healing, self-improving mesh network algorithms optimize network performance—or raise an alert. Two-way communication to the meters supports verification checks. | |
Head end server | The EnergyAxis head-end is a software system maintained within Westar's data center. The system manages the data collection of interval data from the AMI meters. The system also provides application programming interfaces for integration with other Westar systems. The user interface is web based. The application provides dashboards for the daily administration of the AMI system by providing event and alarm counts like tamper and outage as well as daily performance of meter read schedules. | $28,890,755 |
Meter data analysis system | The MDM system will be the hub for storing, validating, and reporting meter reads and event information received from the AMI. The MDM will be the interface between most back office systems and the AMI. The MDM will provide processing and analytics support to billing, customer service, outage management, customer engagement, load research, and other functions. | |
Other IT systems and applications |
Web portal deployed and operational | Quantity* | Description |
---|---|---|
Customers with access to web portal | 47,899 | |
Customers enrolled in web portal | 20,187 | The initial release of the Energy Engage web portal is being prepared for release mid-May 2011. The initial release will be to the residential customers in the SmartStar pilot neighborhood program. |
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 | 1,000 | 9 | Participation in the Time of Use (TOU) Pilot program is limited to 1,000 residential customers only. The program is designed to encourage participating residential customers to shift consumption from higher-cost time periods to lower-cost time periods. TOU charges are: Customer Charge of $9.00, Winter Peak $ 0.079816/kWh, Winter Off-peak $ 0.049358/kWh, Summer Peak $ 0.135387/kWh, Intermediate-peak $ 0.090277/kWh, Summer Off-peak $ 0.055635/kWh. Winter Peak hours are 10:00 AM to 8:00 PM. Winter Off-peak hours are weekends, holidays, all other hours. Summer Peak hours are 1:00 PM to 8:00 PM. Summer Intermediate-peak hours are 10:00 AM to 1:00 PM. Summer Off-peak hours are weekends, holidays, all other hours. |
Recipient information | Input |
---|---|
Total number of customers served by utility / utilities supporting the project | 684,531 |
Total number of residential customers served by utility / utilities supporting the project | 596,852 |
Total number of commercial customers served by utility / utilities supporting the project | 82,836 |
Total number of industrial customers served by utility / utilities supporting the project | 4,843 |
Total number of distribution circuits within utility service territory | 1,338 |
Total number of distribution substations | 716 |
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% | No new SCADA device implementations are planned for the project. |
Portion of distribution system with DA due to SGIG/SGD program | 1.00% | Mid?circuit reclosers will have two?way communication with Westar's corporate network. The public cellular communication network will be utilized. The data provided by the reclosers will be combined information provided by Westar's existing EMS/SCADA systems to make decisions about distribution system operation. |
DA devices installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Automated feeder switches | 31 | Westar will deploy mid?circuit reclosers that will have two?way communication with Westar's corporate network. The public cellular communication network will be utilized. The data provided by the reclosers will be combined information provided by Westar's existing EMS/SCADA systems to make decisions about distribution system operation. Westar plans to deploy fault indicators that will communicate through the public cellular network. The fault indicators will be used to monitor faults in the distribution network. The data provided by the fault indicators will be combined information provided by Westar's existing EMS/SCADA systems and outage management system to make decisions about distribution system restoration activities. Westar plans to deploy capacitor controls that will have two?way communication with Westar's corporate network. The public cellular communication network will be utilized. The capacitor controls will allow for remotely monitoring various control parameters (status, voltages, temperatures, etc.). The data provided by the capacitors will be combined information provided by Westar's existing EMS/SCADA systems to make decisions about distribution system operation. | $1,399,707 |
Automated capacitors | 6 | $60,744 | |
Automated regulators | 0 | $0 | |
Feeder monitors | 0 | $69,039 | |
Remote fault indicators | 27 | $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 | |
Outage management system | No | A vendor for the smart grid ready Outage Management System has been selected, and contract negotiations are ongoing. Work on defining system configuration requirements is scheduled to begin in July 2011. |
Distributed energy resource interface | No | |
Other | No |
Distribution automation features / functionality | Function enabled | Description |
---|---|---|
Fault location, isolation and service restoration (FLISR) | No | Features will be employed once all assets are installed and tested; still working on the testing |
Voltage optimization | No | At this time no plans have been made to do voltage optimization. |
Feeder peak load management | No | |
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.