Rocky Mountain Power - Net Metering

Idaho does not have a statewide net-metering policy. However, each of the state's three investor-owned utilities -- Avista Utilities, Idaho Power and Rocky Mountain Power -- has a net-metering tariff on file with the Idaho Public Utilities Commission (PUC). The framework of the utilities' net-metering programs is similar, in that each utility's original program: (1) offers net metering to customers that generate electricity using solar, wind, hydropower, biomass or fuel cells; (2) limits net metering to 0.1% of its retail peak demand in a baseline year (2002 for Rocky Mountain Power); (3) limits residential systems to 25 kilowatts; and (4) restricts any single customer from generating more than 20% of such peak production.* In an April 2016 order, the PUC removed both the system-wide capacity cap of 0.1% of peak demand, and the individual capacity cap of 20% of the customer's peak production. Rocky Mountain Power must submit annual reports to the PUC on net metering participation.Rocky Mountain Power's net-metering tariff is Schedule 135 which closed to new applicants in October 2020, existing customers will remain on this schedule for 25 years. The PUC then approved the company's net billing program, Schedule 136, which became effective in November 2020.In November 2025, the Commission issued an order approving Rocky Mountain Power’s request to transition to an export credit rate (ECR) as directed in Docket PAC-E-23-17. The ECR would be calculated at an instantaneous netting interval and include avoided energy cost, integration cost, avoided line losses, avoided generation capacity, and avoided transmission and distribution capacity. The current export credit rate, as of March 2026, is $0.14666/kWh (on-peak) and $0.05597/kWh (off-peak) during June - October, and $0.03664/kWh (on-peak) and $0.01228 (off-peak) during November - May. Excess credits will carry-over to the next monthly bill. Excess credits may only be used to offset charges at the meter originating the credit or other eligible meters. If excess credits exist at a meter at the end of the customer’s February billing period the customer may request to transfer the unused excess credits to offset charges at the customer’s other eligible meters. Excess credits may be transferred to a meter or meters and a meter aggregation fee of $10 applies. The order also suspended the ECR annual update requirement until 2028, at which point the proposed ECR must be calculated using an average of data from the three previous years. *