Rebates

In November 2005, the Indiana Utility Regulatory Commission (IURC) approved rules governing the interconnection of distributed generation (DG). Indiana's interconnection rules require the state's investor-owned utilities to provide three levels of interconnection to customer-generators.

• Level 1: Applies to inverter-based systems with a maximum nameplate capacity of 10 kilowatts (kW). These systems must comply with IEEE 1547 and UL 1741 standards. There are no application fees or other fees for Level 1 interconnection review. Utilities may not impose additional requirements not specified in the IURC rules. There are specific limitations on a single system's potential impact and the aggregate potential impact

Note: Xcel is not currently accepting proposals for this program. The most recent application deadline was April 1, 2013. See the program web site for information regarding future solicitations.

The Xcel Energy Renewable Development Fund (RDF) was created in 1999 as an outcome of 1994 Minnesota legislation concerning spent nuclear fuel at Xcel Energy’s Prairie Island Nuclear Plant. The original legislation has been amended and added to several times, expanding the amount of money collected by the fund and prescribing funding allocations for specific programs. Funding available for the grant program thus depends on the other funding obligations that

Nevada's Energy Portfolio Standard requires NV Energy to derive or save a minimum percentage of the electricity it sells from renewable energy resources or energy efficiency measures. Included in the standard is a Portfolio Energy Credit (PC) trading program.
Beginning January 1, 2003, Nevada's renewable energy producers can earn PCs, which can then be sold to utilities that are required to meet Nevada's portfolio standard. One PC represents one kilowatt-hour (kWh) of electricity generated, with the exception of the multipliers described below.   Each kWh generated by a photovoltaic (PV) system installed on the premises of a retail customer on

The Arizona Corporation Commission adopted final rules for interconnection of distributed generation facilities in 2020 after a multi-year proceeding. 

There are three levels of review for interconnection applications:

1. Super Fast Track - available for inverter-based generating facilities with a maximum capacity of 20 kW or less which only uses certified equipment

2. Fast Track - available for generating facilities with a maximum capacity of less than 2 MW.

3. Study Track - available for generating facilities of 2 MW or greater or that do not meet the screening requirements for the other tracks.

Additionally, customers seeking interconnection of a

Hawaii has established simplified interconnection rules for small renewables and separate rules for all other distributed generation (DG). For inverter-based systems up to 10 kilowatts (kW) in capacity, there is a simple application process for interconnection. Systems must meet all applicable performance and safety standards from the Institute of Electrical and Electronics Engineers, Underwriters Laboratories, National Electric Code, and where applicable, public utilities commission rules.  For other smaller systems, there are simplified interconnection procedures for net metered systems powered by solar, wind, biomass and hydroelectric up to 50 kW. 

History

Two dockets were opened in 2006 to streamline interconnection procedures

Massachusetts' interconnection standards apply to all forms of distributed generation (DG), including renewables, and all customers of the state's three investor-owned utilities (Unitil, Eversource, and National Grid).

Massachusetts requires investor-owned utilities to have standard interconnection tariffs. There are three basic paths for interconnection in the state:

• The Simplified interconnection process applies to IEEE 1547.1-certified, inverter-based facilities with: 
1. A power rating of 15 kW or less for single-phase systems located on a radial distribution circuit, 
2. A power rating of 25 kW or less for three-phase systems located on a radial distribution circuit (where the aggregated facility capacity is less than 15% of

NOTE: The PSC adopted additional changes in September 2019 through a rulemaking proceeding (Docket R-33929), which include: removing the 0.5% cap on solar users; customers that submit a completed interconnection request and have completed installation by December 31, 2019 are grandfathered for 15 years, and will receive credit at full retail rates; those that do the same but after 2019 will be credited at avoided cost; and any RECs owned by the customer will be retained, and can be transferred upon selling the associated property.
Louisiana enacted legislation in June 2003 establishing net metering.
  Eligibility and Availability

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)

Iowa imposes a replacement generation tax of $0.0006 per kilowatt-hour (kWh) on various forms of electricity generated within the state. This tax is imposed in lieu of a property tax on generation facilities.

Under the Energy Replacement Generation Tax Exemption, the following facilities are exempt from the replacement tax:

• All energy generated by methane gas conversion property to the extent the property is used in connection or conjunction with a publicly-owned sanitary landfill or used to collect waste that would otherwise be collected by or deposited with a publicly-owned sanitary landfill,
• Wind energy conversion property that is eligible for a tax

Note: Wisconsin has adopted revised interconnection rules, effective May 1, 2024. The revised rules adopt the most recent equipment standards for DG systems and inverters (IEEE Std. 1547 and UL 1741). Energy storage systems are required to be UL 9540-listed.

In February 2004, the Wisconsin Public Service Commission adopted interconnection standards for distributed generation (DG) systems up to 15 megawatts (MW) in capacity. All investor-owned utilities (IOUs) and municipal utilities are required to abide by the standard provisions. Electric cooperatives are encouraged -- but not required -- to adopt the state standards. The rules categorize DG systems by capacity and