Recipient information | Input |
---|---|
Total number of customers served by utility / utilities supporting the project | 2,042,352 |
Total number of residential customers served by utility / utilities supporting the project | 1,789,077 |
Total number of commercial customers served by utility / utilities supporting the project | 253,275 |
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 | $330,701,313 |
Residential | 1,859,008 | |
Commercial | 271,729 | |
Industrial | 0 |
AMI smart meter features operational | Feature enabled | # of meters with feature |
---|---|---|
Interval reads | Yes | 2,130,737 |
Remote connection/disconnection | Yes | 2,038,499 |
Outage detection/reporting | Yes | 2,130,737 |
Tamper detection | Yes | 2,130,737 |
AMI communication networks and data systems | Description | Cost |
---|---|---|
Backhaul communications description | The Backhaul Network is comprised of a communication path from the cell relays, through the Wi-Max tower (aggregation point) locations to the CEHE Data Center. The primary path is Wide-Area-Network (WAN) and consists of Point-to-Point, Point-to-Multiple-Point microwave, as well as fiber. The secondary (redundant) path from the cells relays utilizes a public provider cellular network to provide a secondary connection from the cell relay to the CEHE Data Center. The backhaul network was first installed and operational in 1Q 2009. | $81,831,423 |
Meter communications network | The meter communication network comprises a communication path from the meters to the cell relays and then on to the Wi-Max network and ultimately to the data center. The meters form a RFLAN mesh network (900MHz unlicensed) that incorporates the cell relays. The cell relays in turn are connected to (3.65GHz registered) Wi-Max radios that communicate to Wi-Max towers (aggregation points) that are predominately located at substations. From the Wi-Max towers, connectivity is established to CEHE’s backhaul network connecting to the data center. | |
Head end server | The DCE (Data Collection Engine) Head End collects all meter data that is transmitted from the meters via cell relays and or Wi-Max Towers. The DCE Head End sends the meter data to other integrated systems such as a MDM or CIS system. In addition, the DCE Head End serves as the originator of all commands and requests to cell relays and meters and monitors the status and health of these devices. | $80,178,901 |
Meter data analysis system | ||
Other IT systems and applications |
Web portal deployed and operational | Quantity* | Description |
---|---|---|
Customers with access to web portal | 2,344,905 | |
Customers enrolled in web portal | 18,798 | CEHE daily sends 15-minute consumption data for each accepted and approved smart meter to the Smart Meter Texas Web Portal. Consumers can then register an account with the Smart Meter Texas Web Portal to view their 15-minute consumption from two days ago and prior, as well as their daily and monthly historical usage. |
Customer systems installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Communication networks and home area networks | N/A | N/A | |
In home displays | 504 | The Public Utility Commission of Texas has approved CEHE's deployment of up to 500 In Home Displays. These devices allow the consumer to monitor current consumption and cumulative consumption. CNP has deployed approximately 50 additional HAN devices to Low Income using social agencies to identify accounts that qualify. These customers were surveyed for their impressions of HAN devices and its impact on their electric usage habits. | $4,117,010 |
Energy management device | 0 | N/A | |
Direct load control devices | 0 | $0 | |
Programmable communicating thermostats | 0 | $0 | |
Smart appliances | 0 | $0 |
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 | 2,042,352 |
Total number of residential customers served by utility / utilities supporting the project | 1,789,077 |
Total number of commercial customers served by utility / utilities supporting the project | 253,275 |
Total number of industrial customers served by utility / utilities supporting the project | 0 |
Total number of distribution circuits within utility service territory | 1,516 |
Total number of distribution substations | 240 |
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 | 100.00% | Number of circuits or feeders with SCADA / Distribution Automation divided by the total number of circuits or feeders within the recipient's service territory; Note: SCADA includes monitoring, even if no control functionality is implemented. Entire system has SCADA at the feeder headend level. |
Portion of distribution system with DA due to SGIG/SGD program | 11.74% | Distribution automation is being installed at the rate of approximately 2.5 devices per 12 kV feeder and 3.5 devices per 35 kV feeder. Placement drivers are reliability based, and include customer count and difficulty of access. The % is calculated by taking the number of circuits with distribution automation divided by 183 (1Q13 decreased from original 226 due to revised PEP) to obtain the project % value. |
DA devices installed and operational | Quantity* | Description | Cost |
---|---|---|---|
Automated feeder switches | 567 | Intelligent Grid Switching Devices (IGSD), are a comprehensive package of technologies installed on distribution feeders that perform a number of key IG functions. The devices act as a switching device. They use an enclosed switching body, similar to a line recloser, to provide reliable switching operations across thousands of operations without maintenance. IGSD's also include monitoring equipment to measure load and voltage accurately enough to enable power quality analysis at the device. The IGSD's have a robust control, data storage and communications control package that provides the ability to store data, perform analytics and communicate rapidly with processors at both the substation and at the Company's central computing location. The devices can be remotely controlled either manually by Distribution Controllers or automatically by the Distribution Management System. | $30,425,566 |
Automated capacitors | 0 | $0 | |
Automated regulators | 0 | $0 | |
Feeder monitors | 0 | $0 | |
Remote fault indicators | 0 | $0 | |
Transformer monitors (line) | 0 | $11,741,750 | |
Smart relays | 171 | ||
Fault current limiter | 0 | $0 | |
Other devices | 0 | $0 |
SCADA and DA communications network | Cost |
---|---|
Communications equipment and SCADA | $18,684,481 |
Distribution management systems integration | Integrated | Description |
---|---|---|
AMI | Yes | |
Outage management system | Yes | The Advanced Metering System (AMS) team has rolled out the Outage Management System utilizing meter Power Off Notifications (PON) and Power Restore Notifications (PRN). At times we de-activate this service to address functionality as we continue to enhance our legacy outage systems to handle the volumes of these PON and PRNs. |
Distributed energy resource interface | Yes | |
Other | Yes |
Distribution automation features / functionality | Function enabled | Description |
---|---|---|
Fault location, isolation and service restoration (FLISR) | No | Fault Location Application locates the physical location of fault. Fault is isolated - commands are sent to SCADA to isolate fault automatically. Once fault is isolated, commands are sent to SCADA to restore recoverable sections automatically. Fault isolating switching options allow manual and automated devices to be operated to restore service around a fault. Switching plans can be downloaded to mobile device for final execution. Once the System is in operation, the data historian will record all faults located and how service was restored around the fault and to the fault location. |
Voltage optimization | No | |
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.