Avista Utilities - Interconnection Guidelines (Idaho)
Last modified on May 23, 2011.
Rules Regulations Policies Program
|Name||Avista Utilities - Interconnection Guidelines|
|Applicable Sector||Commercial, Residential, Agricultural|
|Eligible Technologies||Solar Thermal Electric, Photovoltaics, Wind, Biomass, Hydroelectric, Fuel Cells, CHP/Cogeneration, Other Distributed Generation Technologies|
|Energy Category||Renewable Energy Incentive Programs|
|External Disconnect Switch||Yes|
|Insurance Requirements||Not specified|
|Net Metering Required||Yes (utility guidelines)|
|System Capacity Limit||25 kW for net-metered systems; 10 average MW for qualifying facilities that are not net-metered|
|Date added to DSIRE||2003-06-18|
|Last DSIRE Review||2007-03-21|
Idaho has not established uniform interconnection rules and procedures either for net-metered systems or for larger distributed-generation (DG) systems that are not net-metered. However, through their respective tariffs, each of the state's three investor-owned utilities -- Avista Utilities, Idaho Power and Rocky Mountain Power -- has established guidelines for the interconnection of small renewable-energy systems and larger DG.
Avista Utilities' interconnection guidelines for net metering, included in Schedule 63 and Schedule 70, do not specify technical requirements in detail. For net-metered systems, an external disconnect switch is required, and all equipment must meet applicable safety, power quality and interconnection requirements established by the National Electrical Code (NEC), National Electrical Safety Code (NESC), the Institute of Electrical and Electronics Engineers (IEEE), and Underwriters Laboratories (UL). Net metering is generally available to customers who generate electricity using a renewable-energy system up to 25 kilowatts (kW) in capacity.
Avista Utilities also has also developed interconnection guidelines for DG systems up to 300 kilowatts (kW) in capacity. There is a $100 application fee for proposed systems. An external disconnect switch is required, and a separate transformer may be required. No additional insurance is necessary for systems powered by solar, wind, hydropower or fuel cells, but additional insurance and indemnification may be required for other systems. Systems must comply with all applicable codes and standards for safe and reliable operation, including the NEC, NESC, IEEE, ASNI and UL. Interconnection to network distribution systems may be permitted if the customer provides evidence that a proposed system will not result in reverse current flow. The interconnection of Qualifying Facilities (QFs)* up to 10 average megawatts in capacity is addressed briefly by the utility's Schedule 62.
In an order issue January 24, 2007, the Idaho Public Utilities Commission ruled that the National Association of Regulatory Utility Commissioners (NARUC) interconnection model should be used as a "guideline" for interconnection agreements.
* This term, defined in the Public Utility Regulatory Policies Act of 1978 (PURPA), generally includes renewable-energy systems and combined-heat-and-power (CHP) systems.
|Contact Name||Rick Sterling|
|Department||Idaho Public Utilities Commission|
|Address||472 W. Washington|
|Address 2||PO Box 83720|
- Incentive and policy data are reviewed and approved by the N.C. Solar Center's DSIRE project staff.