Rebates

New York was the second state to adopt uniform interconnection standards for distributed generation (DG) systems. The New York Public Service Commission (PSC) originally adopted Standard Interconnection Requirements (SIR) for systems up to 300 kilowatts (kW) in capacity in December 1999. The Standard Interconnection Requirements (SIR) have subsequently been amended several times since, necessitated by changing net metering rules and other legislations. Most recently, the rules were updated on January 2017 which require the developers to demonstrate that they have obtained site control while applying for interconnection. During April to December in 2016 more than 2,000 projects between 50kW and

New Jersey's interconnection standards apply statewide to all electric distribution utilities, but not to the small number of municipal utilities and electric cooperatives in the state. The current standards include the following basic provisions:

• Systems powered by Class I renewable energy resources are eligible. This includes solar, wind, fuel cells powered by renewable fuels, geothermal technologies, wave or tidal action, landfill gas, anaerobic digester gas, and sustainable biomass.
• There are three different levels of review procedures for applications, depending on size and certification. Level 1 applies to inverter-based systems with a capacity rating of 10 kilowatts (kW) or less. Level

In December 2003, the Nevada Public Utilities Commission (PUC) adopted interconnection standards for customers of NV Energy (formerly Nevada Power and Sierra Pacific Power) with on-site generation up to 20 megawatts (MW) in capacity. These standards are largely consistent with IEEE 1547 standards, California's interconnection rule (California Rule 21) and the model interconnection agreement developed by the National Association of Regulatory Utility Commissioners (NARUC). Significantly, the PUC determined that NV Energy may assess customer-generators for past fuel and purchased-power expenses in tariffs. NV Energy has incorporated the standards into their tariffs as Rule 15.

The interconnection standards approved by

In April 2007, Maryland enacted legislation (S.B. 595) requiring the Maryland Public Service Commission (PSC) to form a small generator interconnection working group to develop interconnection standards and procedures that are "consistent with nationally adopted interconnection standards and procedures," and to revise the state's interconnection standards and procedures on or before November 1, 2007. Final rules were adopted in March 2008 and became effective June 9, 2008.

The new rules apply to interconnections of all types of distributed generation systems of less than 10 MW to the electric distribution system for all types of utilities -- investor-owned utilities

Missouri enacted legislation in June 2007 requiring all electric utilities—investor-owned utilities, municipal utilities, and electric cooperatives—to offer net metering to customers that generate electricity using wind energy, solar-thermal energy, hydroelectric energy, photovoltaics (PV), fuel cells using hydrogen produced by one of the aforementioned resources, and other sources of energy certified as renewable by the Missouri Department of Natural Resources.

The Missouri Public Service Commission (PSC) adopted administrative rules for investor-owned utilities that included simplified interconnection standards, and electric cooperatives and municipal utilities adopted their own rules, including an all-in-one document that includes a simple interconnection request, simple procedures, and a

NOTE: Delaware law (26 Del. C. § 1014) requires the Delaware Public Service Commission (PSC), Delaware Electric Cooperative (DEC), and municipal utilities to develop interconnection rules using as a guide the Interstate Renewable Energy Council's (IREC) model interconnection rules and the U.S. Department of Energy's best practices for interconnection. This entry largely addresses the rules used by Delmarva Power, the state's largest utility.

Delmarva, Delaware's only investor-owned electric utility, has four basic levels of interconnection based on system size and system type (inverter-based or non-inverter-based). In June 2011 the PSC issued Order No. 7984 approving final revised rules

Note: The California Public Utilities Commission (CPUC) has an ongoing interconnection rule revision docket (Rulemaking (R.) 17-07-007) that has made many revisions to interconnection rules since July 13, 2017. Current interconnection rules for each utility are available at the CPUC website.

California's "Rule 21" generally applies to systems connecting to an investor-owned utility’s distribution grid, non-export generating facilities connecting to an investor-owned utility’s transmission grid and all net metered facilities in an investor-owned utility’s service territory. Systems connecting to an investor-owned utility’s distribution grid for the purpose of participating in a wholesale transaction must apply under the investor-owned utility’s Wholesale

Note: S.B. 295 was signed in March 2023, and changes related to interconnection were approved by the Public Service Commission in late September 2023 via Order No. 7 in Docket No. 23-021-R.

In April 2001, Arkansas enacted legislation directing the Arkansas Public Service Commission (PSC) to establish net-metering rules for certain renewable-energy systems. The Arkansas Public Service Commission (PSC) adopted net-metering rules in July 2002 (Docket No. 02-046-R, Order No. 4), which include interconnection requirements for net metering facilities interconnect to existing electric power systems (Section 3).* Systems that generate electricity using solar, wind, hydro, geothermal and biomass

Eligibility and Availability

Utah’s net metering policy, adopted in 2002, applies to all electric investor-owned utilities and electric cooperatives. Systems up to 25 kW in capacity for residential and up to 2 MW for non-residential that generate electricity using solar, wind, hydrogen, organic waste, hydroelectric, waste gas and waste heat capture/recovery, certain biomass and woody debris, agricultural residues, dedicated energy crops, landfill or biogas, or geothermal are eligible. Enrollment is limited to 0.1% of the corporation’s peak demand during 2007 (this limit may be increased by the corporation’s governing authority). 

Net Excess Generation

Net excess generation (NEG) is credited to

Massachusetts Public Benefit Funds

Massachusetts's 1997 electric utility restructuring legislation created two separate public benefit funds to promote renewable energy and energy efficiency for all customer classes.

Funding and Administration

The Massachusetts Renewable Energy Trust Fund is supported by a non-bypassable systems benefits charge of $0.0005 per kilowatt-hour (0.5 mill/kWh), imposed on customers of all investor-owned electric utilities and competitive municipal utilities in Massachusetts. (Non-competitive municipal utilities generally may opt into the Fund by agreeing to the same provisions that apply to investor-owned utilities and competitive municipal utilities.) 

The Massachusetts Clean Energy Center, a quasi-public research and development entity, administers