Recipient information | Input |
---|---|
Total number of customers served by utility / utilities supporting the project | 2,131,067 |
Total number of residential customers served by utility / utilities supporting the project | 1,932,344 |
Total number of commercial customers served by utility / utilities supporting the project | 197,728 |
Total number of industrial customers served by utility / utilities supporting the project | 995 |
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 | $114,506,836 |
Residential | 636,571 | |
Commercial | 52,146 | |
Industrial | 0 |
AMI smart meter features operational | Feature enabled | # of meters with feature |
---|---|---|
Interval reads | Yes | 688,717 |
Remote connection/disconnection | Yes | 636,571 |
Outage detection/reporting | Yes | 688,717 |
Tamper detection | Yes | 688,717 |
AMI communication networks and data systems | Description | Cost |
---|---|---|
Backhaul communications description | Detroit Edison's backhaul network consists of both public cellular and private mesh backbone. Benefits include access to hourly customer energy consumption data. | $0 |
Meter communications network | Detroit Edison's meter communication technology is composed of a 900 MHz spread spectrum meter-to-concentrator network in an unlicensed frequency band. Benefits include access to hourly customer energy consumption data. | |
Head end server | The headend system is ITRON's collection engine, system release 3.7. The collection engine provides 2 way communication with the meters, through ITRON cell relays. | $15,834,287 |
Meter data analysis system | The analytics tool is ITRON's Operational Reporting System, version 4.x. ORS can be used for Read Rates, Install Metrics, Meter Counts, and Meter Issues. | |
Other IT systems and applications |
Web portal deployed and operational | Quantity* | Description |
---|---|---|
Customers with access to web portal | 315,137 | |
Customers enrolled in web portal | 2,528 | The Web Portal provides the customer with hourly and daily usage information and pricing information. DECo offers customers the opportunity to view key energy usage data, shadow rate comparisons, and other relevant information and analytics. |
Customer systems installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Communication networks and home area networks | N/A | The Home Area Network will consist of a broadband gateway with a Zigbee chip that will communicate with the AMI network and customer in-home devices that are also Zigbee enabled. | N/A |
In home displays | 871 | GE's energy display with Brillion technology will receive signals from smart meters and provide continuous energy information, including continuous energy use and cost information, variable (time-of-use) pricing, historical energy usage, energy analysis, and messages from DECo. | $1,379,091 |
Energy management device | 0 | N/A | |
Direct load control devices | 0 | $0 | |
Programmable communicating thermostats | 805 | GE PCT is a full-featured, 7 day PCT that is capable of temperature offset during critical events to provide management of energy during peak load excursions. Operating as a 3 heat, 2 cool universal thermostats, the PCT has a touch screen/button interface and a filter replacement. | $1,931,276 |
Smart appliances | 162 | GE Brillion-enabled suite of appliances responds to the utility rate signals, automatically delay or defer cycles during the more expensive peak demand times, and run in hours when demand is low. Appliances in DECo's pilot include: GE Profile Side-by-Side Refrigerator, GE Profile Dishwasher, GE Profile Front Load Washer, and GE Profile Front Load Electric Dryer. | $1,466,721 |
Customer system communication networks | Description |
---|---|
Network characteristics within customer premise | The Home Area Network will consist of a broadband gateway with a Zigbee chip that will communicate with the AMI network and customer in-home devices that are also Zigbee enabled. |
Pricing program | Customers with access | Customers enrolled | Description |
---|---|---|---|
Inverted Block | 636,571 | 605,307 | Inverted Block - DECo's current residential inverted block rate offering is 6.912¢ per kWh for the first 17 kWh per day, 8.257¢ per kWh for excess over 17 kWh per day. |
Prepay | 200 | 3 | DECo will be offering a limited pre-pay billing option for up to 200 customers including, 1) 100 customers on the existing tariff, and 2) 100 customers on DPP. Pre-pay billing allows customers to pre-pay for electric service when they want and in the amounts that they want, essentially providing a "pay as you go" option for customers. Customers must have AMI, enroll in on-line or electronic billing, and have two applicable communication methods. |
Time of Use Rate | 636,571 | 0 | Optional to full-service residential customers whose previous twelve months average usage is equal to or greater than 750 kWh/month, and desires time of day service. Limited to a maximum of 10,000 customers. Summer On-Peak: 12.371¢ per kWh for all kWh used between 11A.M. and 7P.M. Monday through Friday. Summer Off-Peak: 4.165¢ per kWh for all kWh used between 7 P.M. and 11 AM Monday through Friday. Winter On-Peak: 10.451¢ per kWh for all kWh used between 11 A.M. and 7 P.M. Monday through Friday. Winter Off-Peak: 4.002¢ per kWh for all kWh used between 7 P.M. and 11 A.M. Monday through Friday. |
Time of Use rate with Critical Peak Pricing | 636,571 | 1,489 | Optional to full-service residential customers, limited to a maximum of 1,625 customers with an AMI meter and the rate as follows: On-Peak : 12.0¢ per kWh for all kWh used between 3P.M. and 7P.M. Monday through Friday, excluding holidays. Mid Peak: 7.0¢ per kWh for all kWh used between 7A.M. and 3P.M., and between 7P.M. and 11P.M., Monday through Friday excluding holidays . Off-Peak: 4.0¢ per kWh for all kWh used between 11 P.M and 7 A.M. Monday through Friday, and all weekend and holiday hours. Critical-Peak Rate: $1.00 per kWh for all kWh used during critical hours, which, when announced, will replace the full on-peak time period from 3 P.M. to 7 P.M. |
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 | 2,131,067 |
Total number of residential customers served by utility / utilities supporting the project | 1,932,344 |
Total number of commercial customers served by utility / utilities supporting the project | 197,728 |
Total number of industrial customers served by utility / utilities supporting the project | 995 |
Total number of distribution circuits within utility service territory | 3,271 |
Total number of distribution substations | 716 |
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 | 1.54% | The numerator of this calculation is equal to the number of SCADA substations that are part of this project. The denominator is equal to the total number substations in the service territory. This will provide real-time information about the substations. |
Portion of distribution system with DA due to SGIG/SGD program | 1.56% | The numerator of this equation is equal to the number of feeders that have DA in the 11 SCADA-equipped substation project area. The denominator is equal to the total number of feeders in the service territory. This will provide information about real-time loading and operating conditions at the substations and circuits. |
DA devices installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Automated feeder switches | 9 | Automated switches will enable automated switching to improve outage restoration. Regulators and capacitors will provide voltage control. All three will improve power quality in the area. Data from these devices collected by SCADA will be inputted to models to analyze future peak system loads. | $11,325,493 |
Automated capacitors | 40 | $395,557 | |
Automated regulators | 16 | $588,109 | |
Feeder monitors | 0 | $0 | |
Remote fault indicators | 0 | $0 | |
Transformer monitors (line) | 2 | $4,705,583 | |
Smart relays | 75 | ||
Fault current limiter | 0 | $0 | |
Other devices | 0 | $0 |
SCADA and DA communications network | Cost |
---|---|
Communications equipment and SCADA | $600,860 |
Distribution management systems integration | Integrated | Description |
---|---|---|
AMI | Yes | The DMS is now in production. The DMS network model has been created for the 11 substations. DMS applications include: fault locating, restoration and switching analysis, unbalanced load flow, and voltage and VAR optimization. |
Outage management system | Yes | This metric was not in Detroit Edison's approved MBRP; and therefore, it is out of scope. |
Distributed energy resource interface | No | |
Other | No |
Distribution automation features / functionality | Function enabled | Description |
---|---|---|
Fault location, isolation and service restoration (FLISR) | Yes | As of 3rd quarter 2012, Smart Circuit has installed, but was not able to use FLISR to address one or more major events as FLISR implementation is facing software issues. The Smart Circuit team is working to get these issues resolved. |
Voltage optimization | Yes | This application provides more optimized control of voltage and Var levels of the distribution system. This will lead to better power quality and improved system efficiency. Some regulators and capacitors are capable of being controlled remotely, with the automated control functionality in the future. Regulators and capacitors will be coordinated to manage voltage over the entire feeder, using data from feeder monitors. As of 3rd quarter 2012, the functionality is in production but is currently being tested. The system supervisors will be trained once the engineers are comfortable with the technology and the results. |
Feeder peak load management | No | This metric was not in Detroit Edison's approved MBRP; and therefore, it is out of scope. |
Microgrids | No | This metric was not in Detroit Edison's approved MBRP; and therefore, it is out of scope. |
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.