Recipient information | Input |
---|---|
Total number of customers served by utility / utilities supporting the project | 23,000 |
Total number of residential customers served by utility / utilities supporting the project | 19,000 |
Total number of commercial customers served by utility / utilities supporting the project | 4,000 |
Total number of industrial customers served by utility / utilities supporting the project | 0 |
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 | $4,190,400 |
Residential | 14,428 | |
Commercial | 2,255 | |
Industrial | 0 |
AMI smart meter features operational | Feature enabled | # of meters with feature |
---|---|---|
Interval reads | Yes | 16,683 |
Remote connection/disconnection | Yes | 14,559 |
Outage detection/reporting | Yes | 16,683 |
Tamper detection | Yes | 16,683 |
AMI communication networks and data systems | Description | Cost |
---|---|---|
Backhaul communications description | Five Silver Spring Networks (SSN) Access Points are installed to receive AMI data over an unlicensed 900 MHz radio mesh network from AMI meters and Relays and Backhaul the AMI data over an approximately 15 mile expansion of the City owned fiber optic network. The fiber optic network will achieve greater bandwidth to also Backhaul Distribution Automation (DA) and other electric system operational data with greater reliability, higher bandwidth, and lower latency in delivering the AMI and DA data to the appropriate utility operating system. | $379,857 |
Meter communications network | Thirty-five SSN Relays are installed to provide two way communications with 23,000 AMI meters over an unlicensed 900 MHz radio mesh network to 5 SSN Access Points where the AMI data will be delivered to the Headend System over the Backhaul Network described above. | |
Head end server | SSN Utility IQ Headend System is planned and will include the following features: -Two-way communications to Smart Meters, Load Control Switches, PCTs, and IHDs. - Supports remote meter connect/disconnect - Programmable daily, hourly, and 15 minute data intervals - On-demand reads - Web based user interface - Interfacing capabilities to CIS, OMS and GIS - Tamper and theft detection - Power Quality Alerts (voltage, blink counts, hot socket alarm) - Prepay functionality | $6,973,264 |
Meter data analysis system | ||
Other IT systems and applications | Enterprise Service Bus provided by General Electric (GE) Software Services Infrastructure (SSI.) The ESB is installed and operational enabling the interoperability of the business and operational systems to deliver, receive, and share data with other systems. |
Web portal deployed and operational | Quantity* | Description |
---|---|---|
Customers with access to web portal | 14,428 | |
Customers enrolled in web portal | 20 | "The Customer Web Portal is planned to enable customers to access interval consumption and cost information, compare consumption over various time intervals (hourly, daily, monthly, etc.) Also available on the Web Portal will be educational information, energy and cost savings tips, information about available alternative rate schedules.... and more. The Customer Web Portal to be developed by GE. At the end of the project, the web portal was functional and 20 ""friendly"" customers were using it. An educational (instructional) video was produced to explain the portal functionality to customers. Once the initial testing period is over, a customer outreach campaign will be initiated and the video will be utilized. At this point it is expected that numerous customers will take advantage of the portal." |
Customer systems installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Communication networks and home area networks | N/A | N/A | |
In home displays | 0 | In-Home Displays will not be installed. PCT's will be installed instead. The PCT program is in pilot mode for the next 6 months. If the program shows that a viable benefit will be obtained by going into production (adding more PCT' customers), then the program will be funded using additional COL funds. | $0 |
Energy management device | 0 | Energy Management System funding has been shifted to PCTs. No Energy Management system installations are planned for the project. | N/A |
Direct load control devices | 0 | No longer part of this project. If installed, they will be after the project's completion. | $0 |
Programmable communicating thermostats | 0 | After testing Energate and Carrier Comfort Choice PCT devices, Leesburg has selected Carrier PCTs for mass deployment. These units continue to undergo study in the test environment. | $19,797 |
Smart appliances | 0 | $0 |
Customer system communication networks | Description |
---|---|
Network characteristics within customer premise |
Pricing program | Customers with access | Customers enrolled | Description |
---|---|---|---|
Flat Rate | 16,683 | 16,678 | This is an existing rate structure, the billing rate is static across all hours of energy use within the billing period. |
Flat rate with Peak Time Rebates | 300 | 5 | 1. This is an existing rate available to commercial customers with the ability to curtail energy by 100 kW or more during the utility's Coincident Peak Hour. Customers receive a rebate equal to 50% of that month's wholesale Demand Rate ($/kW) for each kW reduced. 2. A Flat Rate with Peak Time Rebate for customers with less than 100kW has been developed. Scheduled to be approved by the City Commission Q4 2012 and available to customers Q1 2013. |
Net Metering | 16,683 | 10 | Net metering is available to customers with renewable generation installed behind the meter. Customer receives full retail value for self-generated energy used and avoided energy cost is rebated for energy delivered to the grid. |
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 | No longer part of this project. If installed, they will be after the project's completion. | $34,064 |
Recipient information | Input |
---|---|
Total number of customers served by utility / utilities supporting the project | 23,000 |
Total number of residential customers served by utility / utilities supporting the project | 19,000 |
Total number of commercial customers served by utility / utilities supporting the project | 4,000 |
Total number of industrial customers served by utility / utilities supporting the project | 0 |
Total number of distribution circuits within utility service territory | 25 |
Total number of distribution substations | 5 |
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% | The existing SCADA system monitors and controls substation transformers, breakers between the transformers and the 13kV operating bus and circuit breakers in all five utility substations. Additional monitoring and control is planned for DA equipment installed on the worst performing distribution circuits. |
Portion of distribution system with DA due to SGIG/SGD program | 16.30% | 50% of the planned devices are installed. |
DA devices installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Automated feeder switches | 6 | DA devices installed included automated/communicating reclosers and capacitor banks. There are 20 capacitor banks and 11 reclosers were installed on the system. | $508,684 |
Automated capacitors | 20 | $193,437 | |
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 | 15 | $2,058,529 |
SCADA and DA communications network | Cost |
---|---|
Communications equipment and SCADA | $67,304 |
Distribution management systems integration | Integrated | Description |
---|---|---|
AMI | No | The Distribution Management System (DMS) Scope of Work is currently being developed. Integration to the ESB will be provided by QEI. The DMS will enable greater operational efficiency through Volt/VAR management to reduce distribution system losses, monitor line and distribution transformer loading, and provide more accurate information on which to base switching decisions. This feature was eliminated from the project but will be implemented separately at a later date. |
Outage management system | No | The planned Outage Management System (OMS) will be provided by Telvent and will be integrated with other systems through the ESB. The OMS will integrate AMI outage and power quality data into the OMS and will enable more accurate outage information to define the protective device that operated and enable more accurate information to restoration crews. Benefits will include more accurate reliability indices and identify where maintenance, vegetation management, and system renewal and replacement resources can be best allocated. |
Distributed energy resource interface | No | "Traditional ""break before make"" switch gear associated with emergency generators located at 8 critical municipal facilities was replaced with advanced switch gear with remote monitoring and control capable of operating the generators in parallel with the utility grid. One new emergency generator was installed at a City water tank and equipped with advanced switch gear and remote monitoring and control capable of operating the generators in parallel with the utility grid. The monitoring and control is enabled through an enhancement to the existing QEI SCADA software. Communication to the generator and throwover equipment is Modbus over the City owned fiber optic network. The utility has total control of Genset and throwover equipment functions including among others, start, stop, initiate parallel operation, ramp power increase and decrease, and more. All genset monitoring functions are remotely communicated to SCADA along with alarms including high temperature, low battery, low fuel, etc." |
Other | No | Enterprise Service Bus provided by General Electric (GE) Software Services Infrastructure (SSI.) The ESB is installed and operational enabling the interoperability of the business and operational systems to deliver, receive, and share data with other systems. |
Distribution automation features / functionality | Function enabled | Description |
---|---|---|
Fault location, isolation and service restoration (FLISR) | Yes | Fault Location, Isolation and Service Restoration (FLISR) is complete for Circuits serving the business zone in the vicinity of the Leesburg Mall. This project is serving 3,700 customers, 16% of Leesburg's 23,000 meters |
Voltage optimization | Yes | The planned installation of communicating capacitor banks and voltage regulators to enable integrated Volt/VAR control and Voltage Optimization on the worst performing distribution circuits will improve operational efficiency and reduce distribution losses. Voltage Optimization is also a component of our Demand Response strategy. DA equipment will have the ability to be locally controlled or controlled via the SCADA system. Completion scheduled for Q3 2013. |
Feeder peak load management | No | |
Microgrids | No | |
Other functions | Yes | No additional DA Applications are planned at this time |
* 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.