Recipient information | Input |
---|---|
Total number of customers served by utility / utilities supporting the project | 57,200 |
Total number of residential customers served by utility / utilities supporting the project | 50,687 |
Total number of commercial customers served by utility / utilities supporting the project | 4,885 |
Total number of industrial customers served by utility / utilities supporting the project | 1,628 |
Total number of AMI smart meters installed and operational prior to the SGIG/SGD program | 200 |
AMI smart meters installed and operational | Quantity* | Cost |
---|---|---|
Total | 200 | $10,080,824 |
Residential | 54,042 | |
Commercial | 4,866 | |
Industrial | 22 |
AMI smart meter features operational | Feature enabled | # of meters with feature |
---|---|---|
Interval reads | Yes | 58,930 |
Remote connection/disconnection | Yes | 54,042 |
Outage detection/reporting | Yes | 58,663 |
Tamper detection | Yes | 58,663 |
AMI communication networks and data systems | Description | Cost |
---|---|---|
Backhaul communications description | $363,624 | |
Meter communications network | A dedicated Meter Communications Network is in process of optimization. Naperville’s vendor for this portion of the project, Elster – US, has completed the initial installation and testing with the assistance and oversight of Naperville staff. With the successful completion of basic functionality testing in Pilot 1, Naperville moved forward with, and completed Pilot 2 testing. In 2011, Pilot 2 included testing and configuration of all hardware components, software systems, and business processes associated with the Naperville Smart Grid Initiative. UPA, an Elster subcontractor, completed installation of most of the needed Communication Devices (wireless router units and Gatekeeper Collector Locations installed around the City as part of Pilot 2. As of December 2012, the initial build-out has been completed and all production meters are installed, some clean up of missed meter installations is ongoing. Optimization of the network is currently in progress. The network is in a production/maintenance state at this time. | |
Head end server | Elster's Energy Axis Management System, EA_MS, will serve as the interface between the AMI network and utility enterprise applications in Naperville. EA_MS enables automation of billing, revenue protection, outage management, customer service, asset management, workflow management, distribution automation, demand response and load management. The functionality of this Headend System for the Naperville AMI has undergone substantial testing and has successfully passed the majority of test procedures. This system is currently in full production. | $2,107,122 |
Meter data analysis system | This system has not been procured at this time | |
Other IT systems and applications | The creation, implementation and integration of the Enterprise Service Bus and AMI are complete. There are some items that have not had all testing completed mostly HAN related items. Once these items have successfully passed testing, the AMI and Enterprise Service Bus can be considered to be fully integrated and tested for production. |
Web portal deployed and operational | Quantity* | Description |
---|---|---|
Customers with access to web portal | 0 | |
Customers enrolled in web portal | 0 | Calico Energy has been contracted by the City of Naperville to provide a customer and utility ePoral which will allow the residents and employees of the City to view network load information. After many attempts to obtain working software, the City has determined that Calico was not able to meet contract requirements, and the City of Naperville is currently reviewing options for the acquisition of an alternate ePortal system through a new vendor including the public release of a new Request for Information. Therefore System go-live has been postponed. |
Customer systems installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Communication networks and home area networks | N/A | Limited HAN device testing began in Q4 2012 has been put on hold pending a decision on a new ePortal. Devices from Ecobee, Emerson and Schneider have begen tested for compatibility with existing Naperville equipment and systems. While no HAN devices have been permanently deployed at this time a very small field deployment of PCT devices remains to facilitate testing. | 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 | Limited HAN device testing began in Q4 2012 has been put on hold pending a decision on a new ePortal. Devices from Ecobee, Emerson and Schneider have begen tested for compatibility with existing Naperville equipment and systems. While no HAN devices have been permanently deployed at this time a very small field deployment of PCT devices remains to facilitate testing. |
Pricing program | Customers with access | Customers enrolled | Description |
---|---|---|---|
Time of Use Rate | 20 | 0 | Effective May 1, 2014 the Naperville City Council approved a pilot program that now makes TOU rates available to the City’s 20 highest use electric customers. |
Time of Use rate with Critical Peak Pricing | 20 | 0 | Effective May 1, 2014 the Naperville City Council approved a pilot program that now makes TOU rates available to the City’s 20 highest use electric customers |
Flat Rate | 57,877 | 57,874 | Flat rate pricing is the primary rate utilized by customers of the City of Naperville. Under this tariff, the customer pays a flat rate for energy no matter what external conditions may exist. Throughout the NSGI, the flat rate tariff is expected to remain to be the primary rate structure that customer’s choose. |
Net Metering | 57,877 | 3 | Net metering is a program in place and available to the customers of the City of Naperville. This program allows for a customer who has the ability to generate their own electricity to do so, and then sell any excess electricity back to the City of Naperville. The customer is then billed the difference of what they purchased versus what they sold, or the net of their electricity consumption. |
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 |
Recipient information | Input |
---|---|
Total number of customers served by utility / utilities supporting the project | 57,200 |
Total number of residential customers served by utility / utilities supporting the project | 50,687 |
Total number of commercial customers served by utility / utilities supporting the project | 4,885 |
Total number of industrial customers served by utility / utilities supporting the project | 1,628 |
Total number of distribution circuits within utility service territory | 117 |
Total number of distribution substations | 16 |
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 | 0% | |
Portion of distribution system with DA due to SGIG/SGD program | 3.90% | Seven automated feeder switches were installed as a part of NSGI project, making 7.30% of system DA switches. |
DA devices installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Automated feeder switches | 7 | Naperville utilizes S&C Electric Company’s Distribution Automation equipment. The type of equipment utilized for Naperville’s Smart Grid Initiative are the remote supervisory PME-9 pad mount switchgear ( S&C Remote Supervisory, 2-way Pad-Mounted Gear, 14.4 kV, 600 A, Control). The City of Naperville uses Distribution Automation equipment to perform circuit switching through automatic control switches. In the event of a fault on a circuit, the Distribution Automation procedure is to isolate the faulted section of that circuit and switch power to the remaining section. The Distribution Automation equipment utilized for the Smart Grid Initiative provides automatic reconfiguration for six feeders. | $487,732 |
Automated capacitors | 0 | $0 | |
Automated regulators | 0 | $0 | |
Feeder monitors | 0 | $0 | |
Remote fault indicators | 0 | $0 | |
Transformer monitors (line) | 0 | $154,962 | |
Smart relays | 12 | ||
Fault current limiter | 0 | $0 | |
Other devices | 0 | $0 |
SCADA and DA communications network | Cost |
---|---|
Communications equipment and SCADA | $66,760 |
Distribution management systems integration | Integrated | Description |
---|---|---|
AMI | No | |
Outage management system | No | |
Distributed energy resource interface | No | Protection of the dedicated feeders into the distributed generation sites is generally accomplished through phase and ground time overcurrent elements. The settings on each of the relays are coordinated between the customer and NAP to ensure that proper operation occurs. Each customer is unique so the communication methods and relay settings are designed with these factors in min |
Other | No | The creation, implementation and integration of the Enterprise Service Bus and AMI are complete. There are some items that have not had all testing completed mostly HAN related items. Once these items have successfully passed testing, the AMI and Enterprise Service Bus can be considered to be fully integrated and tested for production. |
Distribution automation features / functionality | Function enabled | Description |
---|---|---|
Fault location, isolation and service restoration (FLISR) | Yes | FLISR is currently utilized by NAP and will continue to be refined as DA and other monitoring devices come online |
Voltage optimization | No | |
Feeder peak load management | No | |
Microgrids | No | |
Other functions | Yes | In extreme cases, the operators and engineers of NAP will manually override the distribution automation equipment and reconfigure the distribution system themselves. Typically manual overrides are performed when load balancing needs to occur or as a result of a major outage. |
* 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.