AMI smart meters installed and operational | Quantity* | Cost |
---|---|---|
Total | 0 | $10,005,020 |
Residential | 48,650 | |
Commercial | 850 | |
Industrial | 0 |
AMI smart meter features operational | Feature enabled | # of meters with feature |
---|---|---|
Interval reads | Yes | 49,500 |
Remote connection/disconnection | No | 48,650 |
Outage detection/reporting | No | 49,600 |
Tamper detection | No | 49,600 |
AMI communication networks and data systems | Description | Cost |
---|---|---|
Backhaul communications description | The demonstration project will utilize two approaches to communications. Where physical conditions permit, the project will deploy an RF system which will use the LADWP's fiber network as a backhaul mechanism. This network will function as the wide area network (WAN) to transfer the data from designated substations to the back-office, located at the DWP’s headquarters. RF backhaul is operational. | $295,000 |
Meter communications network | The demonstration project will utilize two approaches to communications. Where physical conditions permit, the project will deploy an RF system. Other locations will use a public cellular technology (point-to-point communication) as the solution. The communication solutions will be the ‘media’ for two-way communication between the meters and the back-office. Cellular technology is operational.The demonstration project will utilize two approaches to communications. Where physical conditions permit, the project will deploy an RF system. Other locations will use a public cellular technology (point-to-point communication) as the solution. The communication solutions will be the ‘media’ for two-way communication between the meters and the back-office. Cellular technology is operational. | |
Head end server | The purpose of the head-end system is to interface the advanced metering infrastructure (AMI) system with the meter data management (MDM) which will be used as part of the back-office. As different metering solutions have been designed with different firmware, various head-end systems will be used to accommodate two-way communication between the meters and the back-office. This is operational. | $330,732 |
Meter data analysis system | The back-office (which includes the Meter Data Management) will be programmed to perform data analysis on the collected metering data. This will include trend analysis, estimation, validation, load forecasting, and comparison between usage in various regions. | |
Other IT systems and applications | N/A |
Web portal deployed and operational | Quantity* | Description |
---|---|---|
Customers with access to web portal | 0 | |
Customers enrolled in web portal | 0 | Web-based interface where customers can view their current usage, receive billing information, compare usage to neighbors, evaluate potential savings by switching rates and adjust energy usage preferences. |
Customer systems installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Communication networks and home area networks | N/A | The HAN/ service gateway deployment will allow customers to set preferences for when and how their on-site equipment uses energy. The software will use these preferences to exert control over smart devices within the home. The software will also respond to Demand Response commands issued by the utility based on customer preferences. | N/A |
In home displays | 0 | N/A | $0 |
Energy management device | 18 | The university participants of the project have Energy Management Systems. As part of the project, these systems will receive and react to Demand Response commands. | N/A |
Direct load control devices | 12 | Where technically possible, the project will have direct control over customer electric vehicles. | $1,594 |
Programmable communicating thermostats | 671 | The project will be providing customers with programmable thermostats which will communicate through the Home Area Network | $491,250 |
Smart appliances | 36 | The project will support the deployment of Smart Appliance at customer homes. These will be controlled using the HAN/service gateway. | $17,822 |
Distributed energy resources | Quantity* | Capacity | Description | Cost |
---|---|---|---|---|
Distributed generation | 0 | 0 kW | N/A | $0 |
Energy storage | 1 | 16 kW | $24,100 | |
Plug in electric vehicle charging points | 1,038 | 7,972 kW | $3,062,884 | |
Distributed energy resource interface | N/A | N/A | Where technically possible, the project will have direct control over customer electric vehicles. | $0 |
Electric distribution system | % | Description |
---|---|---|
Portion of distribution system with SCADA due to SGIG/SGD program | 30.00% | 95% |
Portion of distribution system with DA due to SGIG/SGD program | 75.00% | N/A |
DA devices installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Automated feeder switches | 0 | As part of this project the following deviced will be installed and tested: Distribution transformer monitors (74 pcs) Fault Indicators Remotely controlled 34.5kv switch Remotely controlled cap banks | $0 |
Automated capacitors | 0 | $0 | |
Automated regulators | 0 | $0 | |
Feeder monitors | 24 | $20,840 | |
Remote fault indicators | 0 | $0 | |
Transformer monitors (line) | 68 | $0 | |
Smart relays | 0 | ||
Fault current limiter | 0 | $0 | |
Other devices | 7 | $86,048 |
SCADA and DA communications network | Cost |
---|---|
Communications equipment and SCADA | $0 |
Distribution management systems integration | Integrated | Description |
---|---|---|
AMI | No | N/A |
Outage management system | No | CGI’s PragmaLINE Outage Management System is used to gather information on the power outages in the system and notify appropriate parties to take necessary actions to restore the power. |
Distributed energy resource interface | No | "The project will create a ""garage of the future"" to do a full scale test of the interaction between various technologies and EV’s. These technologies will include, local energy storage, PV generation and wind based generation. This will be operational Q1 2015." |
Other | No | N/A |
Distribution automation features / functionality | Function enabled | Description |
---|---|---|
Fault location, isolation and service restoration (FLISR) | No | N/A |
Voltage optimization | Yes | Using simulation tools we will demonstrate how to coordinate and manage voltage and VAR(reactive power) to minimize VAR while simultaneously maintain and optimize system voltage. The voltage profile along a distribution feeder and the reactive power are maintained by a combination of voltage regulators and switched capacitor banks installed at various locations on the feeder and in the substation. Each voltage regulator has a controller that raises and lowers the voltage regulator tap position in response to local (at the device) voltage and current measurements. Similarly, each capacitor bank has a controller that switches the bank on or off in response to the local measurements. The volt/VAR control application will integrate measurement information from pole-top capacitors, pole-top transformers, voltage regulator, PQ meters, and AMI smart meters to satisfy voltage limit and VAR requirements, and thus improve the distribution system performance. This will be demonstrated by simulations. The simulated system performance after the correction, in terms of improved and optimized voltage and VAR, will also be visually displayed. |
Feeder peak load management | No | N/A |
Microgrids | No | The USC campus microgrid test bed is a smart grid environment with diverse building and people profiles, and provides a controlled setting for conducting experiments and demonstrations. The microgrid has in place its own building automation system (BAS) that allows the facility operators to remotely monitor, control and communicate with individual buildings, and play the role of a utility operator that can make decisions on demand response optimization on the campus. In addition, the campus is a large private customer of DWP that can receive and enact curtailment strategies during demand response period. The demonstration will show how an integrated smart grid infrastructure can accept demand response (DR) control signals from LADWP and perform targeted load curtailment across campus, while considering the curtailment potential available in buildings across campus and the preferences of the facility users. In addition, this will also demonstrate the microgrid acting as a utility operations center in making DR decisions. This building-to-grid (B2G) technology integration and demonstration at USC is designed to take a major step towards having a facility testbed with commercial loads that can provide detailed energy consumption information to the grid for the purpose of facilitating better grid management. |
Other functions | No | N/A |
* 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.