Data reported by:
Oklahoma Gas & Electric
| Recipient information | Input |
|---|---|
| Total number of customers served by utility / utilities supporting the project | 766,886 |
| Total number of residential customers served by utility / utilities supporting the project | 657,391 |
| Total number of commercial customers served by utility / utilities supporting the project | 84,491 |
| Total number of industrial customers served by utility / utilities supporting the project | 9,480 |
| 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 | $153,693,666 |
| Residential | 706,501 | |
| Commercial | 102,699 | |
| Industrial | 9,214 |
| AMI smart meter features operational | Feature enabled | # of meters with feature |
|---|---|---|
| Interval reads | Yes | 818,415 |
| Remote connection/disconnection | Yes | 736,178 |
| Outage detection/reporting | Yes | 818,415 |
| Tamper detection | Yes | 818,415 |
| AMI communication networks and data systems | Description | Cost |
|---|---|---|
| Backhaul communications description | WiMAX will provide point-to-multi-point Wide Area Network (WAN) from access points and from there it will be supported by a point-to-point microwave network | $59,095,426 |
| Meter communications network | Radio Frequency (RF) mesh from smart meter to access points. | |
| Head end server | The AMI Network Management System is an essential component that performs several important functions, including; management of the AMI communications network, scheduling and collection of meter reads, collection of end point alarms and events, and a communication conduit for Home Area Network devices. The headend we selected is the UIQ from SSN | $18,310,749 |
| Meter data analysis system | Data stored in MDMS will be made accessible to a variety of internal organizations to support analyses (load research, load and load forecast). The data will also be made available to customers via the web to review historical consumption patterns | |
| Other IT systems and applications |
| Web portal deployed and operational | Quantity* | Description |
|---|---|---|
| Customers with access to web portal | 843,914 | |
| Customers enrolled in web portal | 61,097 | A web-based customer portal that will provide historical usage information, tools to analyze their energy consumption, and evaluate the merits of various rate programs |
| Customer systems installed and operational | Quantity* | Description | Cost |
|---|---|---|---|
| Communication networks and home area networks | N/A | The system that allows smart meters to communicate with Programmable Communicating Thermostats (PCT) and In Home Displays (IHD) utilizing a ZigBee or some other standard protocol. | N/A |
| In home displays | 0 | $0 | |
| Energy management device | 0 | N/A | |
| Direct load control devices | 0 | $0 | |
| Programmable communicating thermostats | 28,668 | Programmable Communicating Thermostats (PCT) are capable of accepting commands over the HAN allowing the remote manual or automatic adjustment of temperature either based on personal preferences or pricing signals. For example, a consumer could chose to set a higher temperature setting on their air conditioner that would automatically adjust based on a Peak Price signal. This setting could potentially be set directly on the PCT. | $17,265,671 |
| Smart appliances | 0 | $0 |
| Customer system communication networks | Description |
|---|---|
| Network characteristics within customer premise | The system that allows smart meters to communicate with Programmable Communicating Thermostats (PCT) and In Home Displays (IHD) utilizing a ZigBee or some other standard protocol. |
| Pricing program | Customers with access | Customers enrolled | Description |
|---|---|---|---|
| TOU with Critical Peak Pricing | 2,126 | 2,126 | Time of Use with Critical Peak Pricing (TOU-CPP) is a stated rate in which the prices for the off-peak period are fixed each day with a higher tier price for the on-peak hours and a top tier for the CPP. OG&E may call the CPP at any time of the year with at least a two hour notice. OG&E proposes two tariffs for TOU-CPP – a Residential TOU-CPP tariff applicable to residential customers and a General Service TOU-CPP tariff, applicable to General Service. |
| TOU with Variable Peak Pricing | 1,983 | 1,983 | Time of Use with Variable Peak Pricing (VPP) is a form of Day-Ahead Pricing in which the prices for the off-peak period are fixed each day and the price for the on-peak period varies each day based on the day-ahead expected system conditions. OG&E proposes two tariffs for VPP – a Residential VPP tariff applicable to residential customers and a General Service VPP tariff, applicable to General Service. |
| Time of Use Rate | 843,914 | 38,997 | N/A |
| Time of Use rate with Critical Peak Pricing | 1,536 | 1,536 | Time of Use with Critical Peak Pricing (TOU-CPP) is a stated rate in which the prices for the off-peak period are fixed each day with a higher tier price for the on-peak hours and a top tier for the CPP. OG&E may call the CPP at any time of the year with at least a two hour notice. OG&E proposes two tariffs for TOU-CPP – a Residential TOU-CPP tariff applicable to residential customers and a General Service TOU-CPP tariff, applicable to General Service. |
| Variable | 843,914 | 37,461 | Time of Use with Variable Peak Pricing (VPP) is a form of Day-Ahead Pricing in which the prices for the off-peak period are fixed each day and the price for the on-peak period varies each day based on the day-ahead expected system conditions. OG&E proposes two tariffs for VPP – a Residential VPP tariff applicable to residential customers and a General Service VPP tariff, applicable to General Service. |
| Recipient information | Input |
|---|---|
| Total number of customers served by utility / utilities supporting the project | 766,886 |
| Total number of residential customers served by utility / utilities supporting the project | 657,391 |
| Total number of commercial customers served by utility / utilities supporting the project | 84,491 |
| Total number of industrial customers served by utility / utilities supporting the project | 9,480 |
| Total number of distribution circuits within utility service territory | 1,062 |
| Total number of distribution substations | 386 |
| 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 | 0% | |
| Portion of distribution system with DA due to SGIG/SGD program | 11.62% | Number of feeders with Automated Switches or IVVC equipment divided by the total number of feeders |
| DA devices installed and operational | Quantity* | Description | Cost |
|---|---|---|---|
| Automated feeder switches | 0 | The DA devices include: Automated Switches Integrated Volt/VAr Controls (Cap Bank and LTC). The automated switching devices operate quickly and automatically to isolate the damaged section of line and restore power when a sustained fault occurs. Automation of capacitor banks and voltage regulators are to provide Volt/VAR optimization. The DA devices will allow to send diagnostic alarms to system operators using the Smart Grid communication network avoiding more costly periodic and reactive inspections. | $0 |
| Automated capacitors | 456 | $7,717,976 | |
| Automated regulators | 0 | $0 | |
| Feeder monitors | 0 | $0 | |
| Remote fault indicators | 0 | $0 | |
| Transformer monitors (line) | 0 | $0 | |
| Smart relays | 14 | ||
| Fault current limiter | 0 | $0 | |
| Other devices | 126 | $0 |
| SCADA and DA communications network | Cost |
|---|---|
| Communications equipment and SCADA | $0 |
| Distribution management systems integration | Integrated | Description |
|---|---|---|
| AMI | No | Distribution Management System (DMS) with an accurate electrical connectivity model (with GIS ) will provide the ability to automatically generate temporary switching plans saving a considerable amount of administrative time associated with the current manual process.DMS can also support efficient decision-making or automatically reduce loading on circuits by transferring load to neighboring circuits which is a major challenge during high load periods |
| Outage management system | No | OMS will be integrated with AMI headend for outage identification and restoration |
| Distributed energy resource interface | No | |
| Other | No |
| Distribution automation features / functionality | Function enabled | Description |
|---|---|---|
| Fault location, isolation and service restoration (FLISR) | No | The Distribution Management System (DMS) can enhance fault location determination with the system’s Faulted Circuit Calculation application. This functionality will enable faster fault location and isolation, improving field force productivity as well as improve SAIDI. |
| Voltage optimization | Yes | DA will leverage AMI, DMS and capacitor controls to optimize voltage distribution to reduce line losses and peak energy demand |
| 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.
