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 developed a net-billing tariff that has been approved by the Idaho Public Utilities Commission (PUC). Idaho Power's net-metering tariff is Schedule 6 for residential customers, Schedule 8 for small general service customers, and Schedule 84 for large general service customers. Systems owned or operated by residential and small general service customers must be 25 kW or smaller to participate in net billing. Large general service, large power service, and agriculture irrigation service customers

NOTE: In May 2018, S.B. 9 signed into law and made significant changes to the state's Renewable Portfolio Standard and Net Metering policies. The law ends net metering to new customers when the Residential Solar Investment Program ends on January 1, 2022. The existing net metering customers will be grandfathered until December 2039. Starting January 1, 2022, new customers will be able to select a buy-all, sell-all option, or net billing option under the new Net-Tariff program. The Public Utilities Regulator Authority (PURA) has finished implementing the new program as the Residential Renewable Energy Solutions Program. Non-residential customers can participate

Note: The California Public Utilities Commission (CPUC) issued a decision in December 2022 phasing out the previous Net Energy Metering (NEM 2.0) tariff and replacing it with a new net billing tariff. Customer generators who submit interconnection applications on or after April 15, 2023 will only be eligible for the new net billing tariff. The summary immediately below describes the net billing tariff, followed by a description of the previous NEM 2.0 rules for historical purposes. 

Net Billing Tariff 

Customer generators who submit interconnection applications on or after April 15, 2023 must take service under the new net billing tariff

The Pennsylvania Public Utilities Commission was required to adopt interconnection standards and net-metering rules by the Alternative Energy Portfolio Standards Act of 2004. The PUC subsequently adopted interconnection standards for net-metered distributed generation (DG) systems in August 2006. In July 2007, H.B.1203 required the Pennsylvania Public Utilities Commission (PUC) to develop "technical and net-metering interconnection rules for customer-generators... consistent with rules defined in other states within the service region of the regional transmission organization that manages the transmission system in any part of the [state]."

In July 2008 the PUC issued a final rulemaking order (effective November 2008) adopting new net

In December 2005 the Colorado Public Utilities Commission (PUC) adopted standards for net metering and interconnection, as required by Amendment 37, a renewable energy ballot initiative approved by Colorado voters in November 2004.

Customer-generators are eligible for net metering in Colorado for retail renewable distributed generation. The following sections describe the rules that apply to investor-owned utilities (IOUs), with the last section detailing net metering for municipal utilities and electric cooperatives. All utilities subject to the below net metering rules are required to provide net metering service at non-discriminatory rates to customer-generators.

Systems sized up to 200% of

Nevada has a number of laws which prohibit restrictions on solar and wind energy systems. 

Nevada Revised Statutes 111.239 and 111.2395 relate to property. The laws disallow covenants, deeds, contracts, ordinances or other legal instruments which unreasonably restrict a property owner from using a solar or wind energy system on his or her property. For solar systems, unreasonable restrictions are those which decrease system performance by more than 10%. For wind systems, unreasonable restrictions are those which “significantly” decrease the efficiency or performance of the system. Further restrictions can be placed on a wind system based on its height, noise

Note: The Arizona Corporation Commission is currently considering changes to the state's Renewable Energy Standard in Docket No. RE-00000A-24-0026.

In November 2006, the Arizona Corporation Commission (ACC) adopted final rules to expand the state's Renewable Energy Standard (RES) to 15% by 2025, with 30% of the renewable energy to be derived from distributed energy technologies. In June 2007, the state attorney general certified the rule as constitutional, allowing the new rules to go forward, and they took effect 60 days later. Investor-owned utilities and electric power cooperatives serving retail customers in Arizona, with the exception of distribution companies with

In 1983, Iowa became the first state in the U.S. to adopt a renewable portfolio standard (RPS) by enacting the Alternative Energy Production law. The Iowa RPS requires its two investor-owned utilities (MidAmerican Energy and Alliant Energy Interstate Power and Light) to own or to contract for a combined total of 105 megawatts (MW) of renewable generating capacity and associated energy production.

Eligible Technologies

Eligible resources include solar, wind, electric storage unit, nuclear, waste management, resource recovery, refuse-derived fuel, agricultural crops or residues, wood-burning facilities, or small hydropower facilities.

Requirements

The Iowa Utilities Commission (IUC) has allocated the 105 MW

Pennsylvania's Alternative Energy Portfolio Standard (AEPS), created by S.B. 1030 on November 30, 2004, requires each electric distribution company (EDC)* and electric generation supplier (EGS) to retail electric customers in Pennsylvania to supply 18% of its electricity using alternative-energy resources by 2020.** 

Eligible technologies

The eligible alternative energy resources are categorized into two “Tiers”. The standard calls for utilities to generate 8% of their electricity by using "Tier I" energy sources and 10% using "Tier II" sources by May 31, 2021. 

Tier I sources include new and existing facilities which produce electricity using the following sources/technologies

At the request of a customer or a potential customer, Colorado electric utilities are required to conduct a cost comparison of a photovoltaic (PV) system to any proposed distribution line extension if the customer or potential customer provides the utility with load data (estimated monthly kilowatt-hour usage) requested by the utility to conduct the comparison, and if the customer's or potential customer's peak demand is estimated to be less than 25 kilowatts (kW). In performing the comparison analysis, the utility must consider line-extension distance, overhead or underground construction, terrain, other variable construction costs, and the probability of additions to the