Recipient information | Input |
---|---|
Total number of customers served by utility / utilities supporting the project | 4,524,000 |
Total number of residential customers served by utility / utilities supporting the project | 4,010,000 |
Total number of commercial customers served by utility / utilities supporting the project | 505,000 |
Total number of industrial customers served by utility / utilities supporting the project | 9,000 |
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 | $373,231,325 |
Residential | 2,931,873 | |
Commercial | 134,592 | |
Industrial | 1,671 |
AMI smart meter features operational | Feature enabled | # of meters with feature |
---|---|---|
Interval reads | Yes | 3,068,136 |
Remote connection/disconnection | No | 0 |
Outage detection/reporting | Yes | 3,072,318 |
Tamper detection | Yes | 3,072,318 |
AMI communication networks and data systems | Description | Cost |
---|---|---|
Backhaul communications description | Communication devices for the Automated Metering Infrastructure (AMI) include devices called access points and relays. The access points provide connectivity through various public cellular carriers (Sprint EVDO, AT&T HSUPA, and Verizon EVDO) between the smart meters and the head-end application. Relays provide enhanced operations of data transfer through the network. | $8,686,323 |
Meter communications network | Smart meters will collect hourly electricity usage information, as well as power quality information, outage counters, and tampering indicators. The smart meters will transmit the collected data through 900 MHz radios (with encryption) to communication devices at scheduled intervals. | |
Head end server | $55,659,921 | |
Meter data analysis system | ||
Other IT systems and applications |
Web portal deployed and operational | Quantity* | Description |
---|---|---|
Customers with access to web portal | 2,931,873 | |
Customers enrolled in web portal | 2,931,873 | FPL maintains an online customer portal where customers can actively manage their account, including billing/payment items, power-related issues, and viewing their usage on a next day basis, down to the hour. When customers' smart meters are activated for remote billing, we provide them with instructions on how to register for the portal and online access to their energy usage information. |
Customer systems installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Communication networks and home area networks | N/A | The In-Home Technology Pilot Project was completed at the end of the 3rd Quarter 2012. The Home Area Network consisted of a Home Energy Controller and control devices. | N/A |
In home displays | 0 | The In-Home Technology Pilot Project was completed at the end of the 3rd Quarter 2012. In-Home Displays (IHD) provided near-real time energy use and cost feedback. 226 IHD were deployed on the standard residential rate as part of this pilot. Most IHD pilot participants reported high initial engagement with the IHD, reporting that it helped them to understand their energy use, and motivated them to change their energy habits. Most set their IHD to display the near-real time view “how much I’m using right now” in dollars. The initial period of high engagement was followed by a period of high attrition in IHD use. | $710,255 |
Energy management device | 0 | The In-Home Technology Pilot Project was completed at the end of the 3rd Quarter 2012. The Home-Energy Controller (HEC) displayed energy usage and cost information, appliance-level monitoring and/or control, and automated response to price signals. 228 HEC were deployed, 111 stayed on the standard residential rate and 117 participated in the critical peak price pilot rate. Interviews revealed that HEC users found the controller’s simple digital display of the dollar cost of current use more intuitive at a glance than the graphic options. Participants with appliance-level monitoring reported finding the information interesting to know, but difficult to act on. HECs also provided the enhanced ability to schedule the central cooling and heating thermostat through a graphic interface and the presence of this capability resulted in significant increases in thermostat programming. | N/A |
Direct load control devices | 0 | $0 | |
Programmable communicating thermostats | 0 | The In-Home Technology Pilot Project was completed at the end of the 3rd Quarter 2012. The Programmable Communicating Thermostat (PCT) acted as a peripheral device to the home energy controller. 228 PCT were deployed with the Home Energy Controllers. | $0 |
Smart appliances | 0 | The In-Home Technology Pilot Project was completed at the end of the 3rd Quarter 2012. 33 Smart appliances acted as peripherals to a home energy controller. Manufactured by General Electric (GE) appliances included heat-pump water heater, laundry set, refrigerator and dishwasher. • Appliance-level monitoring of energy use by smart refrigerator, dishwasher, washer and dryer • Smart appliances respond to CPP events in ways designed to minimize energy use while also minimizing user inconvenience. Appliances respond automatically in two general ways: 1) delaying start until a lower-cost period, or 2) if appliance is mid-cycle when a high price period occurs, reducing its power requirement without interrupting its task. In most cases appliance responses could be overridden by consumers. • The GE smart appliances used in the FPL pilot featured these manufacturer-specified programmatic responses to CPP events: • Refrigerator: Disable several features, such as QuickFreeze, Quick IceTM, and TurboCoolTM, delay defrost and consumer-safe temperature shifts. • Dishwasher: Delay cycle start and disable the heated dry option. These features can be overridden by the customer. • Clothes washer: Delay cycle start. Power Saver cycle suggested as the default setting if the consumer has overridden delayed cycle start. These features can be overridden by the customer. • Clothes dryer: Delay cycle start. Power Saver cycle is suggested as the default setting if the consumer has overridden delayed cycle Start. If already operating, complete the remaining portion of cycle in Power Saver mode. These features can be overridden by the customer. • GeoSpring Hybrid-electric water heater: Use a 550-watt “eHeat” heat pump mode vs. the 4,500-watt resistance element. Enable a lower water temperature set point (e.g., 100 degrees) to minimize cycling. | $94,257 |
Customer system communication networks | Description |
---|---|
Network characteristics within customer premise | The In-Home Technology Pilot Project was completed at the end of the 3rd Quarter 2012. The Home Area Network consisted of a Home Energy Controller and control devices. |
Pricing program | Customers with access | Customers enrolled | Description |
---|---|---|---|
Flat rate with Critical Peak Pricing | 127 | 118 | FPL has a pilot rate of the Flat with Critical Peak Pricing form, approved by the Florida Public Service Commission (FPSC) for use in the In-Home Technology Pilot. |
Tiered Rate | 337 | 323 | All in-home display and a subset of home energy controller customers will remain on RS-1. |
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 | 4,524,000 |
Total number of residential customers served by utility / utilities supporting the project | 4,010,000 |
Total number of commercial customers served by utility / utilities supporting the project | 505,000 |
Total number of industrial customers served by utility / utilities supporting the project | 9,000 |
Total number of distribution circuits within utility service territory | 3,124 |
Total number of distribution substations | 586 |
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 | 0% |
DA devices installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Automated feeder switches | 285 | Distribution Automation (DA) devices provide reliability benefits through self healing schemes. The Energy Smart Florida (ESF) project will place various DA devices on feeders. | $18,631,748 |
Automated capacitors | 1,403 | $4,004,305 | |
Automated regulators | 1,806 | $0 | |
Feeder monitors | 1,014 | $9,514,013 | |
Remote fault indicators | 3,879 | $0 | |
Transformer monitors (line) | 2,716 | $47,113,820 | |
Smart relays | 1,084 | ||
Fault current limiter | 0 | $0 | |
Other devices | 745 | $0 |
SCADA and DA communications network | Cost |
---|---|
Communications equipment and SCADA | $5,403,402 |
Distribution management systems integration | Integrated | Description |
---|---|---|
AMI | No | |
Outage management system | No | AMI data, has been integrated into our Trouble Call Management System (TCMS/2) and Outage Management System (OMS). The AMI data is being utilized to generate trouble tickets when outages occur and to augment the restoration verification process. |
Distributed energy resource interface | No | The Integration of Distributed Generation Pilot Project was completed at end of 3rd Quarter, 2012. As part of the Integration of Distributed Generation Pilot, an AMI smart meter was used to measure generation at 65 distributed generation locations in Miami-Dade and Broward counties. As of the end of 2012, the total capacity for the 65 projects (system total DG units is 2,124) was 326 kW (system total of 19,060 kW), with a total energy delivered of 108,481 kWh (system total of 5,727,753 kWh). |
Other | No |
Distribution automation features / functionality | Function enabled | Description |
---|---|---|
Fault location, isolation and service restoration (FLISR) | Yes | The typical ESF DA project will include 2 Automated Feeder Switches (AFS) installed on 1 feeder to isolate faults and restore service. The portion of the project with AFS includes 129 feeders. |
Voltage optimization | No | As part of the ESF project, Volt/Var Control functionality will be deployed through the Distribution Management System. Additional functions for voltage optimization will be added as part of future enhancements, utilizing the ESF devices providing additional telemetry points along a feeder. |
Feeder peak load management | No | Aggregation of AMI data will be used to identify overloaded transformers, identify feeder losses, and predict equipment failure. This data will also be used as a feeder balancing tool. |
Microgrids | No | NA |
Other functions | No |
Recipient information | Input |
---|---|
Total miles of transmission line | 0 |
Total number of transmission substations | 98 |
Number of PMUs installed and operational before SGIG program | 0 |
Number of PDCs installed and operational before SGIG program | 0 |
Electric transmission system | Portion | Description |
---|---|---|
Portion of transmission system covered by phasor measurement systems | 100.00% |
Phasor measurement systems | Quantity* | Description | Cost |
---|---|---|---|
PMUs | 45 | Phasor Measurement Units (PMU) will be installed at various transmission substations throughout the system. For PMU's, the ESF project is utilizing SEL-421 relays. PMUs provide Wide Area Situational Awareness (WASA) and are used to help determine the stress points of the transmission system by monitoring phasor quantities. The increased WASA will also help improve diagnostic capabilities to prevent event occurrence and assist the system operators in restoration after events such as hurricanes. | $3,988,866 |
Phasor data concentrators | 13 | There will be two types of Phasor Data Concentrators (PDC), one local PDC (SEL-3373) in a substation to aggregate and time align local incoming PMU data from multiple PMU devices, and a second (Alstom Open PDC) to aggregate and time align incoming PMU data from multiple PDCs. | $0 |
Communications network | $0 |
Other transmission assets | Quantity* | Description | Cost |
---|---|---|---|
Dynamic Capability Rating System (DCRS) - Transmission Lines | None | $0 | |
Other transmission assets | $0 | ||
Other transmission assets | 0 | $0 | |
Other transmission assets | 0 | $0 |
Angle/frequency monitoring | Operational | Description | Cost |
---|---|---|---|
Angle/frequency monitoring | Yes | Angle/Frequency Monitor: The Frequency Monitor application gathers data from three separate Synchrophasors at different points on the Bulk Electric System and enables the Energy Management System to better handle frequency events by initiating any Demand Response action. Post Mortem Analysis: After a system event, the fine data resolution remotely available in the Synchrophasors will enhance the analysis of power system events. This data is stored in a historian archive system until needed for review. Voltage Stability: Synchrophasor data from selected substations is integrated into the EMS and Voltage Stability Analysis tool. The Voltage Stability Analysis tool identifies real-time power system conditions for critical elements within the grid and enables operators to be able to develop preventative and corrective actions. With the enhanced quality of field measurements, the Power/Voltage Curve diagrams are improved and we now have an improved wide-area situational awareness view of the power system. Improved State Estimation: Synchrophasor data enhances the availability, observability and accuracy of the State Estimator solution. | $0 |
Post-mortem analysis (including compliance monitoring) | Yes | ||
Voltage stability monitoring | Yes | ||
Thermal overload monitoring | No | ||
Improved state estimation | Yes | ||
Steady-state model benchmarking | No | ||
DG/IPP applications | No | ||
Power system restoration | 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.