Recipient information | Input |
---|---|
Total number of customers served by utility / utilities supporting the project | 12,839 |
Total number of residential customers served by utility / utilities supporting the project | 10,956 |
Total number of commercial customers served by utility / utilities supporting the project | 1,864 |
Total number of industrial customers served by utility / utilities supporting the project | 19 |
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 | $3,039,800 |
Residential | 11,088 | |
Commercial | 1,858 | |
Industrial | 17 |
AMI smart meter features operational | Feature enabled | # of meters with feature |
---|---|---|
Interval reads | Yes | 12,963 |
Remote connection/disconnection | Yes | 945 |
Outage detection/reporting | Yes | 12,963 |
Tamper detection | Yes | 12,963 |
AMI communication networks and data systems | Description | Cost |
---|---|---|
Backhaul communications description | This project deployed a hybrid fiber optic, Wi-Max, and 200Mhz radio communication backhaul network system-wide. This network allows a high level of interconnectivity for all aspects of municipal operations and assure long-term system regulatory compliance. The network supports the AMI backhaul, distribution-automation/SCADA communications, and monitoring at capacitor banks, reclosers, and switches. The supply contract for Wi-Max equipment was bid and awarded to WPCS. Twenty six (26) gatekeepers are currently installed and operational in Danvers; four (4) are served from by fiber optic, fifteen (15) are served by Wi-Max,seven (7) are served by 200Mhz radio backhauled to Wi-Max. The AMI communication backhaul is completely built-out and fully performing its intended purpose. This backhaul system was enabled by the grant project. | $1,191,600 |
Meter communications network | The grant funded procurement and implementation of Elster’s fixed network AMI system throughout the Town. The system is a mesh 900MHz spread spectrum licensed network and will replace manual meter reading system-wide. Twenty six (26) Elster gatekeepers (collectors) are installed and operational. This is the entire compliment of gatekeepers that will be required in Danvers. Implementation of this technology was planned exclusive of grant funding. | |
Head end server | Elster Energy Axis MAS AMI head end (EA_MS) is installed. This system provides meter data collection, on-request functionality, and control of service connects, among other features. Implementation of this technology was planned exclusive of grant funding. | $1,115,800 |
Meter data analysis system | The highly configurable meter data management and operational data store enables customized reporting, transformer load management reporting, alarm reporting, and outage and restoration reporting. Implementation of this system was planned exclusive of grant funding. | |
Other IT systems and applications | AMI is fully integrated with online customer systems. The first release of customer facing web-features was in Q2 2011, and included web presentment of account information, billing history, rate information, and online bill payment. The second release, made available in January 2013, included daily interval data and weather trend information. These systems were enabled by the grant and will encourage reduced customer demand and improved customer service features. |
Web portal deployed and operational | Quantity* | Description |
---|---|---|
Customers with access to web portal | 13,064 | |
Customers enrolled in web portal | 4,725 | The first release of customer facing web-features was in Q2 2011, and included web presentment of account information, billing history, rate information, and online bill payment. The second release, delivered in January 2013, included daily interval data and weather trend information. These features are enabled by the grant project and are available to all customers who choose to enroll. In this quarter, Danvers Electric customers paid approximately 5,621 bills online (some monthly some quarterly). The number of customers with access will change period to period due to normal customer addition and subtraction. |
Customer systems installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Communication networks and home area networks | N/A | N/A | |
In home displays | 0 | Grounded Power in-home displays were deployed to provide select customers access to consumption data, rates, and cost of use data. This technology has been deployed at select large-consumption users as part of a pilot study. Danvers has determined that they will discontinue use of the piloted equipment because it produces a separate load profile than as-metered by Danvers and because the HAN equipment manufacturer no longer supports the piloted equipment. HAN equipment was not purchased from grant funds. | $19,400 |
Energy management device | 0 | N/A | |
Direct load control devices | 0 | $0 | |
Programmable communicating thermostats | 0 | $0 | |
Smart appliances | 0 | $0 |
Customer system communication networks | Description |
---|---|
Network characteristics within customer premise |
Pricing program | Customers with access | Customers enrolled | Description |
---|---|---|---|
Flat Rate | 12,642 | 12,642 | This is an existing rate program. Rate classes include R-1(Residential), G-1(Small General), and MG-1(Municipal General). All of these rate classes are charged for energy consumption at a flat rate plus minimum charges. Classes G-1 & MG-1 also include basic monthly charges. Customer enrollment changed since last period due to normal customer addition and subtraction. |
Flat Rate Plus Demand Charges | 421 | 421 | Flat Rate Plus Demand Charges - This is an existing rate program. Rate classes include G-2(Demand General), G-3(Large General), and MG-2(Municipal General Large). All of these rate classes are charged for energy consumption at a flat rate plus basic monthly charges and demand charges. Demand charges are a function of peak interval (15-min) demand during the reporting period. G-2 & MG-2 also include minimum monthly charges. Customer enrollment changed since last period due to normal customer addition and subtraction. |
Net Metering | 2 | 2 | Two customers have net metering enabled (1 residential, 1 large commercial). |
Recipient information | Input |
---|---|
Total number of customers served by utility / utilities supporting the project | 12,839 |
Total number of residential customers served by utility / utilities supporting the project | 10,956 |
Total number of commercial customers served by utility / utilities supporting the project | 1,864 |
Total number of industrial customers served by utility / utilities supporting the project | 19 |
Total number of distribution circuits within utility service territory | 0 |
Total number of distribution substations | 0 |
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 | 94.00% | The numerator is the total number of project components configured with SCADA (80) and the denominator is the total number of similar components on circuits improved by the project (85). |
Portion of distribution system with DA due to SGIG/SGD program | 94.00% | The project automates Station 42 and (4) of the (9) 4.16kV substations. These substations were selected because they could potentially carry 50% of the system load. The substations included in the project were equipped with a data concentrator/NTU, a HMI (Human/Machine Interface), and digital feeder protection relays. The numerator of this calculation includes the total number of DA enabled devices (switches, reclosers, capacitors, feeder monitors, substations, etc.) installed as part of the SGIG project (80) through this reporting period. The denominator is equal to the total number of such devices on the project-automated circuits (85). |
DA devices installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Automated feeder switches | 50 | "The SGIG plan proposes complete automation of Danvers Electric’s 23kV system. The plan included furnishing new, or retrofitting, 28 gang-operated load break switches (GOABS), 22 reclosers, 15 capacitor banks, and 16 feeder monitors. The actual equipment installed included 29 gang-operated load break switches (GOABS), 21 reclosers, 14 capacitor banks, and 12 feeder monitors. The switches and reclosers are equipped with 3 Ø voltage and current measuring devices. These devices report data (voltage, current, power factor, %THD, and fault indication) required for use with each of the efacec/ACS software packages including PRISM, FDIR, OMS, Simulation, and Power Factor Correction. The automated capacitors include voltage and current monitoring devices. These devices report kVAR, Power Factor, and Voltage for use with the Power Factor Correction Software Package. Primary feeder monitors provide additional telemetry data and augment fault indication. Equipment options were tested in controlled environments and bid specs were drafted to purchase the most advantageous systems. (8) ""smart"" switches/reclosers installed before the grant project have been retained." | $1,617,800 |
Automated capacitors | 14 | $208,400 | |
Automated regulators | 0 | $0 | |
Feeder monitors | 12 | $185,200 | |
Remote fault indicators | 0 | $0 | |
Transformer monitors (line) | 0 | $110,400 | |
Smart relays | 0 | ||
Fault current limiter | 0 | $0 | |
Other devices | 8 | $0 |
SCADA and DA communications network | Cost |
---|---|
Communications equipment and SCADA | $1,206,000 |
Distribution management systems integration | Integrated | Description |
---|---|---|
AMI | No | Integration between the OMS and EA_MS will be done utilizing MultiSpeak protocol. Event notices shall be transferred over web services through the integration server. DMS shall be fully integrated with OMS. |
Outage management system | No | The OMS business requirements document and Proof of Concept plan for AMI/MDM/OMS integration is complete. It will also allow for transformer load simulation through interval data analysis. Two-way data exchange between these systems will be enabled. These systems will contribute to enabling improved outage detection and service restoration as well as improved power quality management. Benefits will include better reliability indices and improved power quality. |
Distributed energy resource interface | No | |
Other | No | AMI is fully integrated with online customer systems. The first release of customer facing web-features was in Q2 2011, and included web presentment of account information, billing history, rate information, and online bill payment. The second release, made available in January 2013, included daily interval data and weather trend information. These systems were enabled by the grant and will encourage reduced customer demand and improved customer service features. |
Distribution automation features / functionality | Function enabled | Description |
---|---|---|
Fault location, isolation and service restoration (FLISR) | No | A FDIR application has been configured on the 23kV system to provide automatic fault detection, sectionalizing of the fault, restoration of unfaulted sections, and re-routing of de-energized lines to alternative power sources. The system requires refinement, a comprehensive protection stufy, and business process development before it is made operational. This restoration process will be configured so it may be set to automatic or manual. The automatic setting will provide restoration to un-faulted line sections in as little as 20 seconds. |
Voltage optimization | No | The project included efacec/ACS XpertSim & Power Factor Correction packages. These applications allow system planning & optimization using real-time and historic data supplied from the SCADA/DMS platform. This software enables Volt/VAR control by analyzing reactive power flows and determining control actions for switching the individual capacitor banks on or off. Feeder losses can be minimized and still maintain voltages and power factors at capacitor bank locations within specified limits. The software can automatically control feeder-based switchable capacitor banks. Some of the other applications include Short Circuit Analysis, Load Estimator, Optimal Switching, Protection Coordination, and Optimal Capacitor Placement. System refinement is required before these systems can be utilized in the manner intended. |
Feeder peak load management | No | |
Microgrids | No | |
Other functions | No | "Power Factor Correction (formerly known as ""Economic Dispatch"") is an additional efacec/ACS distribution management application. This application will automatically monitor and control feeder capacitor banks. This will minimize system losses, reduce reactive power flows, and maintain voltage and power factor. System refinement and configuration is required before this system may be utilized as intended." |
* 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.