Recipient information | Input |
---|---|
Total number of customers served by utility / utilities supporting the project | 119,685 |
Total number of residential customers served by utility / utilities supporting the project | 94,827 |
Total number of commercial customers served by utility / utilities supporting the project | 24,858 |
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 | $0 |
Residential | 0 | |
Commercial | 0 | |
Industrial | 0 |
AMI smart meter features operational | Feature enabled | # of meters with feature |
---|---|---|
Interval reads | No | 0 |
Remote connection/disconnection | No | 0 |
Outage detection/reporting | No | 0 |
Tamper detection | No | 0 |
AMI communication networks and data systems | Description | Cost |
---|---|---|
Backhaul communications description | $0 | |
Meter communications network | ||
Head end server | $0 | |
Meter data analysis system | ||
Other IT systems and applications |
Web portal deployed and operational | Quantity* | Description |
---|---|---|
Customers with access to web portal | 0 | |
Customers enrolled in web portal | 0 |
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 | It is not likely that there will be an Energy Management Systems (EMS) installed as part of this project, unless a commercial customer is willing to install one on their own in order to participate in the Commercial Demand Response (DR) program. | N/A |
Direct load control devices | 0 | $0 | |
Programmable communicating thermostats | 54 | A small pilot of 54 Honeywell WiFi 9000, 10 Honeywell VisionPro and 4 ecobee Smart Thermostats is underway to evaluate features and operational performance in commercial and residential settings. [NOTE: The equipment and installation cost of the ecobee devices is covered under separate funding not associated with the SGIG award; however, management and evaluation of the devices is part of the SGIG project.] Honeywell's WiFi 9000 is under consideration for inclusion in the Commercial DR program. In Q3 2014, the WiFi 9000 thermostats were integrated onto the Automated DR platform. It's anticipated that the WiFi VisionPro thermostats will be integrated in Q4. | $91,676 |
Smart appliances | 0 | $0 |
Customer system communication networks | Description |
---|---|
Network characteristics within customer premise |
Pricing program | Customers with access | Customers enrolled | Description |
---|---|---|---|
Flat rate with Peak Time Rebates | 1,109 | 17 | This metric is part of the commercial PeakSmart program, but is not technically a "flat rate w/ peak time rebate". In future reports will be reclassified as an "Other" rate option. This rate provides participating customers with a monthly credit of $3/kW based on the amount of electric demand they cut during a Demand Response event. Customers are informed of a pending event 24-hours ahead of time. Frequency and duration of events is limited to minimize disruptions. |
PeakSmart Commercial Rate | 1,089 | 21 | The PeakSmart Commercial Rate provides participating customers with a monthly credit of $3/kW based on the amount of electric demand they are capable of curtailing during a Demand Response event. Customers are informed of a pending event 24-hours ahead of time. Events can be called on weekdays between 7am-7pm, no more than 20 events per year, and no longer than 4 hours per event. |
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 | 119,685 |
Total number of residential customers served by utility / utilities supporting the project | 94,827 |
Total number of commercial customers served by utility / utilities supporting the project | 24,858 |
Total number of industrial customers served by utility / utilities supporting the project | 0 |
Total number of distribution circuits within utility service territory | 138 |
Total number of distribution substations | 18 |
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 | 11.20% | The SCADA system, as a part of the Automated Distribution System, was deployed into 29 of the 257 electric distribution circuits (11.2% of the distribution system) operated by the City of Tallahassee as of April 20, 2014. |
Portion of distribution system with DA due to SGIG/SGD program | 11.20% | This project deployed the Automated Distribution System into 29 of the 257 electric distribution circuits (11.2% of the distribution system) operated by the City of Tallahassee as of April 20, 2014. |
DA devices installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Automated feeder switches | 93 | "AThe DA devices are comprised of automated reclosers and motor operated switches (broadly termed ""automated switches"") together with the associated controls and communication equipment." | $2,953,995 |
Automated capacitors | 0 | $5,420 | |
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 | 93 | $0 |
SCADA and DA communications network | Cost |
---|---|
Communications equipment and SCADA | $2,744,972 |
Distribution management systems integration | Integrated | Description |
---|---|---|
AMI | No | |
Outage management system | No | |
Distributed energy resource interface | No | The project did NOT involve installing utility-owned distributed generation, rather the City originally sought to enroll customer-side back-up generation through the Commercial Automated Demand Response system to provide for additional electric capacity during DR events. However, rules promulgated by the US Environmental Protection Agency this past year effectively eliminated the potential to enroll DG customers because doing so would require their back-up units to comply and be operated as non-emergency (which is costly). Customer that had enrolled dropped out in Q3 2014. |
Other | No |
Distribution automation features / functionality | Function enabled | Description |
---|---|---|
Fault location, isolation and service restoration (FLISR) | Yes | The utilization of automated processes to monitor and control distribution devices via imbedded intelligence coupled with device-to-device communications to identify and isolate faulted sections of a distribution system and restore service to the non-faulted sections of the distribution system. |
Voltage optimization | No | Voltage optimization is a corollary function associated with the ability to monitor and control line regulators on the distribution system utilizing the communications system deployed as a part of the DA system in coordination with the data compiled utilizing the AMI system and forwarded to the System Control Center using the MDMS system (Meter Data Management System). It is unclear at this time the extent to which this element will be developed under this project as it relies heavily on the development of the MDMS project. |
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.