AMI smart meters installed and operational | Quantity* | Cost |
---|---|---|
Total | 0 | $16,819,065 |
Residential | 27,376 | |
Commercial | 2,961 | |
Industrial | 359 |
AMI smart meter features operational | Feature enabled | # of meters with feature |
---|---|---|
Interval reads | Yes | 30,696 |
Remote connection/disconnection | Yes | 13,104 |
Outage detection/reporting | Yes | 14,114 |
Tamper detection | Yes | 9,372 |
AMI communication networks and data systems | Description | Cost |
---|---|---|
Backhaul communications description | Subproject 1: The fiber backhaul network was extended into the subproject’s demonstration site. Multiple take-out points are required for adequate network performance. Subproject 4: A T1 fiber line backhaul to the corporate network is provided by a Telco T1 line. Metro Ethernet was installed at a remote substation, which has allowed efficient retrieval of the meter data from this remote substation. Subproject 5: A Tropos wireless Wide Area Network (WAN), a fiber network, and 85 routers have been installed and operational. Subproject 6: A small black box network multiplexer has been added to the site's substations. These multiplexers integrate the Advanced Metering Infrastructure (AMI) signals into the Supervisory Control And Data Acquisition (SCADA) system. The existing SCADA system is comprised of fiber, phone, and satellite communication. This system acts as a backhaul and carries a signal from SCADA Remote Terminal Units (RTUs) back to the utility. The signal is then split into a SCADA portion and an AMI portion. Subproject 7: Supervisory Control And Data Acquisition (SCADA) communication from the control center at City Hall via fiber optic cable to the substations is 100% installed. Communication from substations to field equipment takes place via Power Line Carrier (PLC) to equipment in the field. Subproject 8: The radio communication network includes five central collection units (CCUs) and 10 repeater units (900-MHz, 8-channel high power ERT). The 5 CCUs and all of the 10 repeater units have already been installed. The meters send data to the repeaters; the repeaters then send data to the CCUs that forward data to the central service location. | $2,524,287 |
Meter communications network | Subproject 1: Advanced metering infrastructure (AMI) meters will use an Itron cell relay with integrated Tropos 7230 radio (ITR) to transition from 900MHz Open Way radio frequency to 802.11 wireless network. Subproject 4: All Turtle Automatic Meter Reading (AMR) meters were replaced with Aclara Two Way Automatic Communication System (TWACS) advanced metering infrastructure (AMI) meters in one of the subproject’s sites with the other site also complete. Utility collecting the data and facilitating the use of Demand Respond Units (DRUs) and In-Home Displays (IHDs). The data is communicated via a power line carrier (PLC) system. Subproject 5: The Elster Energy Access network /radio frequency (RF) mesh network enables approximately 3000 meters to use a FCC unlicensed 902-928 MHz RF spectrum meter communication network. Subproject 6: Power line carrier (PLC) capability has been added to the two substations participating in this subproject. An existing PLC is used for the rest of the subproject system. Subproject 7: A TWACS Power Line Carrier (PLC) communicates directly to the demand response units (DRUs). The PLC also provides two way communication to the meters that provide meter readings and disconnection capability. This network is installed. Subproject 8: Itron ChoiceConnect (ERT-based 900 MHz platform) is the central collection units and includes the five central collection units (CCU). | |
Head end server | Subproject 1: The OpenWay Collection Engine does all of the scheduled and non-scheduled communication to the meters (pulling back data, changing the status of service switches, setting demands, etc.). Subproject 4: Aclara TWACS Network Server (TNS), National Information Solutions Cooperative (NISC) IVUE with Milsoft Outage Management with custom programming, and Spirae’s Bluefin application have been implemented. A secure Virtual Private Network (VPN) connection has been established. Testing has been successful to the DRUs and the IHDs. This is a web based user interface. Subproject 5: Elster Energy Access system is used as a head-end system and has two-way communications with the advanced metering infrastructure (AMI) meters and has 15 minute data interval reads polled every 12 hours. Subproject 7: TWACS Network Server provides the following features: • Two-way communications to smart meters, load control switches. • On-demand reads • Interfacing capabilities to Customer Information System (CIS) (Caselle) software. • Supports remote connect/disconnect. • Programmable daily reads shift 15 interval data. • Tamper and theft detection. Subproject 8: Once data is at the central service location in one of the utility’s sites, it is sent to Itron in Spokane, Washington over secured TCP-IP (internet). This same data is communicated to a vendor (Lockheed Martin) for load predictions needed for the project’s transactive control system. | $1,660,924 |
Meter data analysis system | Subproject 1: Itron Enterprise Edition (IEE) is included in the Open Way advanced metering infrastructure (AMI) solution. Subproject 4: This subproject is using NISC as the Meter Data Management (MDM) vendor. The subproject is currently working with the Advance Metering Infrastructure (AMI) vendor (Aclara) and NISC to correctly format the meter usage file has been loaded into the MDM. Subproject 5: The Meter Data Management System (MDMS) is Primestone MDM in partnership with Elster. The MDMS is operational. Subproject 6: Meter Data Management System (MDMS) installation is complete. MDMS allows project customers to view their hourly energy consumption history online. Subproject 7: The ElectSolve system (installed) includes data from the Meter Data Management System (MDMS) which also includes customer usage information and the following features: • File formatted in Extensible Markup Language (XML) • Send signal from Supervisory Control And Data Acquisition (SCADA) to TWACS Net Server (TNS) to operate demand response units (DRUs) • Data mapping specifications • Provide the ability to send data daily, weekly, and monthly. Subproject 8: Itron’s MV-90 xi software is the latest generation of the industry’s leading system for collecting and processing interval data from complex metering devices. MV-90 xi is a proven multi-vendor system for collecting data from the complex metering devices typically used for large commercial and industrial (C&I) customers. Subproject 11: The Enterprise Energy Management (EEM) 3.7 system is a data management, monitoring, and analysis software. Its purpose is to manage the data flow from the mediators to the data warehouse. Anomalies, accuracies, and imperfections in data will be analyzed via the EEM. This system has been installed. The EEM also has energy analysis features that include consumption reports, outage logs, maintenance recommendations and energy conservation opportunity reports. | |
Other IT systems and applications | n/a |
Web portal deployed and operational | Quantity* | Description |
---|---|---|
Customers with access to web portal | 16,889 | |
Customers enrolled in web portal | 4,522 | Subproject 1: Customer web portals display energy usage from advanced metering infrastructure (AMI) interval readings with a 24-hour delay. Thermostat web portals display energy usage from the AMI meter within 5 minutes. Private group web portals are in use, other installations are complete. Subproject 4: GE’s Nucleus energy manager comes with a software program for personal computers. Using wireless technology, the system gathers estimated energy usage data from the home and enabled appliances, then displays the information to a computer interface. Energy use is displayed in near real-time and historical energy use can be displayed by day, month, and year. This web portal is in production. Subproject 6: Energy usage information from the subproject’s new National Information Solutions Cooperative (NISC) Meter Data Management System (MDMS) is available through the subproject's existing web portal. Subproject 8: Customers are able to view their energy consumption and manage the responses of their load to the transactive control signal via their web portal. Subproject 11: Two residential dormitories have common area display screens deployed in the elevator lobby located on each floor. Residents are encouraged to view their floor’s energy consumption information while waiting for the elevator. The subproject equipped 100 rooms within the same two residential dormitories with EnergyHub’s Home Base devices, which are ZigBee wireless devices that display near real time energy usage to students living in the dormitory rooms. The Home Base devices display usage information from two plug-in style smart outlets and one power strip with six smart outlets located in the rooms. |
Customer systems installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Communication networks and home area networks | N/A | Subproject 1: A customer’s home area network is created by their thermostats being tied to their advanced metering infrastructure (AMI) via a ZigBee Gateway, which is included in the Open Way meter. Subproject 4: GE’s Nucleus energy manager acts as the central nervous system for monitoring in-home electrical usage of the smart appliances. It shows energy usage in kWh and in estimated dollars spent and shows energy usage trends over days, weeks and months-up to 3 years. The in-home smart energy network is directly connected to a PC through an Ethernet connection or through an internet broadband router.: Subproject 6: The current transformer (CT) unit in each customer service panel sends a wireless signal to a network receiver. It gives real-time data to the customers using The Energy Detective (TED) in-home displays. For the Blue Line in-home displays, a reader arm on each meter reads pulses of the meter and sends a wireless signal to the display with the energy usage information. Subproject 8: The Translate device translates the encoder receiver transmitter (ERT) signal from the meter into Zigbee protocol. The Transport device communicates all the energy consumption information to Tendril’s Network Operations Center (NOC). | N/A |
In home displays | 1,466 | Subproject 4: The in-home displays, paired with Advanced Metering Infrastructure (AMI) metering, allows each customer to view and respond to transactive pricing signals. Subproject 5: In-home displays have been installed in 759 customer homes. The displays show current electricity usage, cumulative monthly electricity usage, and current price of electricity. Subproject 6: The Energy Detective (TED) current transformers (CTs) and Blue Line in-home displays have been installed in 404 customer homes. The in-home displays provide its customers with direct feedback about their energy consumption, inducing energy conservation. Subproject 8: In-home displays are installed at 189 customer premises. Subproject 11: Two residential dormitories each have two common area display screens for residents to view their floor’s energy consumption information. The subproject equip 100 rooms within the same two residential dormitories with EnergyHub’s Home Base devices, which are ZigBee wireless devices that display energy usage to students living in the dormitory rooms. The Home Base devices also display usage information from two plug-in style smart outlets and one power strip with six smart outlets located in the rooms. | $409,213 |
Energy management device | 0 | n/a | N/A |
Direct load control devices | 2,099 | Subproject 1: Controls for air handlers for 39 commercial buildings and controls for 9 chillers on the commercial buildings are manually controlled to manage asset loading and response. Installation completed. Subproject 4: Water heater demand response units (DRUs) in 232 customer homes are controlled by the subproject in order to curtail load. One hundred fifteen (115) are water heater DRUs (sent via power line) and 117 are GE DRUs (sent via home energy gateway network) 240 volt switches. Subproject 5: Integrated load control devices on 217 residential water heaters are controlled by the transactive control signal and through subproject signals based on the pricing structure for the customers who participate in this program. Subproject 6: Water heater demand response units (DRUs) have been installed at 404 customer premises. These DRUs, along with 50 existing, are configured to automatically respond to the transactive signal for time-of-use or peak demands. The DRUs are programmed to trip during under-voltage or -frequency events in order to reduce the loading on the subproject’s system. The subproject may also choose to turn the DRUs off during cold load pickups. Subproject 7: Approximately 800 Aclara demand response units (DRUs) are used to disconnect large resistive household loads in order to shed load. Subproject 8: Load control switches disconnect larger (240 V) household loads. Smart outlets disconnect various smaller (110 V) household loads. Nine hundred (900) smart outlets to disconnect various smaller (110 V) household loads. Subproject 9: A total of 445 modules have been installed and tested. All remaining purchased units will be held as spares or for testing. Subproject 11: The subproject deleted lighting system controls from the project scope, due to infeasibility. | $8,274,641 |
Programmable communicating thermostats | 310 | Subproject 1: The thermostats have built-in displays that allow each customer to view their energy usage. The thermostats also come with a mobile phone application allows the customer to view energy consumption. Seventy-five (75) programmable thermostats have been installed. Subproject 5: Integrated load control devices on 41 residential thermostats are controlled by the transactive control signal and subproject signals based on the pricing structure for the customers who participate in this program. Subproject 8: Thermostats control heaters and/or air conditioners. Subproject 11: Direct digital controls (DDC) have been commissioned and are now controlling programmable thermostats for five commercial building Heating, Ventilation, Air Conditioning (HVAC) systems. | $1,169,960 |
Smart appliances | 217 | Subproject 4: Smart washer and dryer sets and smart dishwashers are controlled by the subproject in order to curtail load. Subproject 7: A total of 100 demand response units (DRUs) have been placed on hot water heaters. These DRUs are programmed to shed water heater load when the line voltage drops below the programmed threshold voltage. | $669,502 |
Distributed energy resources | Quantity* | Capacity | Description | Cost |
---|---|---|---|---|
Distributed generation | 3 | 70 kW | Information requested by Warren Wang: Information formatted as Subproject: item; make/model Subproject 1: Two natural gas generators (existing), one diesel generator (existing), and one biotech generator (existing). Subproject 3: One 58 kW Photovoltaic polycrystalline solar panel system (existing); RWE Schott 300 & 290 watt, one 13.5 kW thin film nanotechnology solar panel system (existing); First Solar SMA America, FS-275 modules SB7000US inverters, one 40.5 kW thin film nanotechnology solar panel system (new); First Solar SMA America, FS-275 modules SB7000US inverters. Subproject 6: One 20-kW solar PV system; Creative Energies / Fronius, one 10-kW wind generator (existing), Honeywell 2.5kW / WT6500. Subproject 10: Six diesel generators on GenOnSys (existing). Subproject 11: One 5000kW steam turbine generator (existing); Worthington / 12 Stage, two 2000kW diesel standby generators (existing); Caterpillar / 3516 Cat Engine, two small-scale PV arrays (existing); RWE Schott Solar / ASE-3 | $2,800 |
Energy storage | 2 | 5,085 kW | $7,735,983 | |
Plug in electric vehicle charging points | 0 | 0 kW | $0 | |
Distributed energy resource interface | N/A | N/A | Subproject 1: Controls for air handlers for 39 commercial buildings and controls for 9 chillers on the commercial buildings are manually controlled to manage asset loading and response. Installation completed. Subproject 4: Water heater demand response units (DRUs) in 232 customer homes are controlled by the subproject in order to curtail load. One hundred fifteen (115) are water heater DRUs (sent via power line) and 117 are GE DRUs (sent via home energy gateway network) 240 volt switches. Subproject 5: Integrated load control devices on 217 residential water heaters are controlled by the transactive control signal and through subproject signals based on the pricing structure for the customers who participate in this program. Subproject 6: Water heater demand response units (DRUs) have been installed at 404 customer premises. These DRUs, along with 50 existing, are configured to automatically respond to the transactive signal for time-of-use or peak demands. The DRUs are programmed to trip during under-voltage or -frequency events in order to reduce the loading on the subproject’s system. The subproject may also choose to turn the DRUs off during cold load pickups. Subproject 7: Approximately 800 Aclara demand response units (DRUs) are used to disconnect large resistive household loads in order to shed load. Subproject 8: Load control switches disconnect larger (240 V) household loads. Smart outlets disconnect various smaller (110 V) household loads. Nine hundred (900) smart outlets to disconnect various smaller (110 V) household loads. Subproject 9: A total of 445 modules have been installed and tested. All remaining purchased units will be held as spares or for testing. Subproject 11: The subproject deleted lighting system controls from the project scope, due to infeasibility. | $1,078,045 |
Electric distribution system | % | Description |
---|---|---|
Portion of distribution system with SCADA due to SGIG/SGD program | 100.00% | Subproject 3: This Supervisory Control And Data Acquisition (SCADA) system is new for the project and the hardware and software installation is complete. The numerator of this equation is equal to the number of feeders that have DA equipment fully installed as a result of this project (1). The denominator is equal to the total number of feeders participating in the subproject (1). |
Portion of distribution system with DA due to SGIG/SGD program | 48.57% | Subproject 5: The numerator of this equation is equal to the number of feeders that have distribution automation (DA) equipment fully installed as a result of this project (2). The denominator is equal to the total number of feeders participating in the subproject (10). Subproject 8: Site one is served by six (6) substations and thirty-three (33) distribution circuits. The smart grid systems are part of three of these substations and nine distribution circuits in total. (Of which the fault detection, isolation, and recovery (FDIR) is part of three substations and four circuits, and the Volt/VAR optimization is part of two substations and eight circuits). Site two is served by one (1) substation and four (4) distribution circuits. The smart grid systems are part of that one substation but only on two of the circuits. (The FDIR system is only on one circuit, and the Volt/VAR application is part of two circuits.) The numerator of this equation is equal to the number of feeders that have DA equipment fully installed as a result of this project (14). The denominator is equal to the total number of feeders participating in the subproject (22). Subproject 9: Distributed Automation (DA) is not yet fully implemented. The numerator of this equation is equal to the number of feeders that have DA equipment fully installed as a result of this project (0). The denominator is equal to the total number of feeders participating in the subproject (2). Software has been installed. Vendor training and configuration has again been delayed by vendor. Subproject will configure with vendor support while testing has been put on hold. This module suffers from the same issues as integrated volt var control (IVVC). Data collection methodologies planned for the monitoring phase of the software implementation has begun despite software issues. Subproject 10: One feeder has distribution automation. The numerator of this equation is equal to the number of feeders that have DA equipment f |
DA devices installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Automated feeder switches | 78 | Subproject 1: Three sets of automated switchgear have been installed to switch backup generators online in the case of an outage. A total of 39 automated line switches and 13 station recloser devices have been installed and are used to identify and respond to faults or outages. Subproject 5: Four (4) remotely controlled motorized switch operators act to restore outages quickly to reduce the outage duration when the fault indicators identify a fault in the system. Subproject 8: Smart distribution switches used for fault detection, isolation, and recovery (FDIR). Subproject 9: In the event of a fault, a Supervisory Control And Data Acquisition (SCADA) system will calculate an optimal feeder configuration and control a total of 11 automated feeder switches to prevent further outages. Manual process not fully automated. Subproject 10: The subproject installed four (4) automated switches / reclosers to island a feeder upon the occurrence a fault. | $3,129,442 |
Automated capacitors | 41 | $1,987,554 | |
Automated regulators | 52 | $2,193,152 | |
Feeder monitors | 12,822 | $2,588,996 | |
Remote fault indicators | 315 | $0 | |
Transformer monitors (line) | 400 | $57,836 | |
Smart relays | 55 | ||
Fault current limiter | 0 | $0 | |
Other devices | 1 | $1,396,686 |
SCADA and DA communications network | Cost |
---|---|
Communications equipment and SCADA | $3,978,398 |
Distribution management systems integration | Integrated | Description |
---|---|---|
AMI | Yes | Subproject 1: ACS provides the Distribution Management System (DMS), which controls all voltage and var transactions as well as automated restoration. Real-time power flow calculation and simulation is possible. Integration of the Advanced Metering Infrastructure (AMI) system with the DMS is complete. |
Outage management system | Yes | Subproject 5: The subproject’s Outage Management System (OMS) was awarded and is currently undergoing engineering design and is scheduled to be implemented in February 2015. |
Distributed energy resource interface | Yes | Subproject 1: The subproject uses a Spirae platform with a commercial building energy management system (EMS). The EMS system is installed in the commercial buildings participating in the subproject. The EMS provides forecasting of availability of HVAC, lighting, and distributed generation assets. The Spirae platform calculates, based on the transactive incentive signal (TIS), what the load demand is, and a graphical user interface (GUI) in the building receives a request from the Spirae platform to manually operate the asset controls. The distributed generation (DG) interface is now installed. Subproject 3: The subproject’s City Hall is the control terminal. A Supervisory Control And Data Acquisition (SCADA) system is in place and is monitoring and controlling the recloser at the subproject’s Renewable Park. The renewable energy devices in the park are monitored by the SCADA system. This SCADA system is new for the project and is complete. Subproject 10: The subproject interfaced with their distributed generation via asset control software. Using high-speed communications, the subproject can remotely start and operate customer-owned, standby generators for system operating reserves and peak load management. Subproject 11: Spirae provided a software package called Bluefin, which provides data analysis capabilities of energy production data from the different energy resources. Data is received from the mediators installed by Subproject 11’s contractor McKinstry. Bluefin also does future energy production predictions from the different sources, needed for the project’s transactive control system. Bluefin includes a visualization interface. The Bluefin software is installed. |
Other | No | n/a |
Distribution automation features / functionality | Function enabled | Description |
---|---|---|
Fault location, isolation and service restoration (FLISR) | Yes | Subproject 1: Fault Detection, Isolation, and Restoration (FDIR) within the subproject’s DMS provides by the Advanced Control Systems (ACS) and uses smart relays and feeder monitors within automated line switches for feeder lockout. This application can be operated in 3 modes; manual upstream/downstream, automated upstream/manual downstream, automated upstream/automated downstream. We are currently operating automated upstream/automated downstream, 24x7. Subproject 5: Fault circuit interrupters identify faults and the faults are cleared remotely, thus reducing the duration of outages. Subproject 8: The utility is using automated switches and remote fault indicators to perform fault detection, isolation, and restoration in the case of an outage. Subproject 9: Fault detectors and the Supervisory Control And Data Acquisition (SCADA) system are used to locate faults and gather system status information to support an automated switching scheme. Fault detector communications path issues have been resolved and the fault detectors have been installed, tested and deployed. The detectors support the functionality of the FDIR module. Configuration with vendor is still on hold but data is being reported as if the system were to operate as intended. |
Voltage optimization | Yes | Subproject 1: A total of 39 voltage regulator controllers and switched capacitor banks are used for voltage optimization. Thirty-nine (39) have been installed. This application is in operation on all 13 feeders. Subproject 5: A load tap change controller and a smart relay, centrally controlled using an existing A Supervisory Control And Data Acquisition (SCADA) system, is used to provide voltage optimization with the help of transactive control. That system also uses the transactive incentive signal (TIS) to reduce energy consumption and improve the feeder voltage profile. Subproject 6: Adaptive voltage control (AVC) and conservation voltage reduction (CVR) is being achieved using data from approximately 2,200 advanced metering infrastructure (AMI) meters to reduce peak demand. Subproject 7: The subproject uses voltage regulators, controlled remotely and automatically, to reduce peak demand and conserve energy. This application is currently in operation. Subproject 8: S&C Electric’s IntelliTeam VV Volt-VAR Optimization System is being used in 2 locations. All system operation testing is complete. End-of-line voltage sensors are used to feedback voltage information to the optimization system. Subproject 9: The Supervisory Control And Data Acquisition (SCADA) system and advanced metering infrastructure (AMI) meters on two feeders are used to capture the voltage profile of the feeder to support set point changes for voltage controls. The additional voltage sensors were ordered and received. Configuration with vendor is still on hold. Man-in-the-middle scheme implemented. Transactive node monitored daily and appropriate action is taken when system conditions permit. Transformer monitors for voltage monitoring are installed. |
Feeder peak load management | Yes | Subproject 7: The subproject uses voltage regulators, controlled remotely and automatically, to reduce peak demand and manage peak feeder loads. This application is currently in operation. |
Microgrids | Yes | Subproject 10: Depending on the location of a fault, automated switches / reclosers are designed to form a microgrid. Energy storage and distributed generation are used to carry the load. Supervisory and control work for the Intellirupters is underway. |
Other functions | Yes | Subproject 5: Power factor control to optimize system efficiency. |
* 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.