Rebates

DGS purchases electricity in de-regulated power markets on behalf of all state agencies. Through an innovative electricity purchasing strategy for larger accounts, DGS hedges for a portion of the future power requirements of state facilities. By locking in rates for a portion of future power needs and purchasing the balance at real-time rates, favorable trends in power prices are exploited to the State's benefit. This strategy is referred to as “Block and Index.” Through these reverse auctions the state avoided costs of $4.7M in fiscal year 2019. The state's renewable portfolio standard requires that at least 30.8% of electricity procured

NOTE: A.B. 3723 enacted in May 2018 included several updates to the state's Renewable Energy Portfolio standard including i) increasing the RPS standard to 50% by 2030, ii) increasing the offshore wind carveout, iii) increases in the Solar carveout, iv) changes to the alternative compliance payments, and other several minor changes. 

Requirements:

New Jersey's Renewable Portfolio Standard (RPS) was first adopted in 1999 and has been updated several times. In May 2018, A.B. 3723 increased the total RPS requirement in New Jersey to 35% by 2025 and 50% by 2030 where the specified percentage of electricity sold in the the state

Section 73 of the California Revenue and Taxation Code allows a property tax exclusion for certain types of solar energy systems installed between January 1, 1999, and June 30, 2026. This section was amended by AB 1451 in September 2008 to include the construction of an active solar energy system incorporated by an owner-builder in the initial construction of a new building that the owner-builder does not intend to occupy or use. This only applies if the owner-builder did not already receive an exclusion for the same active solar energy system and only if the initial purchaser purchased the new

Wyoming enacted legislation in February 2001 that established statewide net metering. The law applies to investor-owned utilities, electric cooperatives and irrigation districts. Eligible technologies include solar, wind, biomass and hydropower systems up to 25 kilowatts (kW) in capacity. Systems must be intended primarily to offset part or all of the customer-generator's requirements for electricity.

Net excess generation (NEG) is treated as a kilowatt-hour (kWh) credit or other compensation on the customer's following bill.* At the beginning of the calendar year, a utility will purchase any unused credits at the utility's avoided-cost rate. Utilities may not charge net-metered customers any additional

Note: A.B. 209 of 2022 extended eligibility for this program to residential solar photovoltaic systems paired with energy storage systems. The CPUC will need to develop rules before these new incentives are available. 

Initiated in 2001, the Self-Generation Incentive Program (SGIP) offers incentives to customers who produce electricity with wind turbines, fuel cells, various forms of combined heat and power (CHP) and advanced energy storage. Retail electric and gas customers of San Diego Gas & Electric (SDG&E), Pacific Gas & Electric (PG&E), Southern California Edison (SCE) or Southern California Gas (SoCal Gas) are eligible for the SGIP. Beginning in May

Tennessee Valley Authority (TVA) and participating power distributors of TVA power offer a performance-based incentive program to homeowners and businesses for the installation of renewable generation systems from the following qualifying resources: PV, wind, hydropower, and biomass. The long term Green Power Providers program replaces the Generation Partners* pilot program. The energy generated from these renewable generation systems will count towards TVA's green power pricing program, Green Power Switch.

The Green Power Providers program contract term is 20 years. Generation credit will be paid at the following flat rates for the entirety of the 20-year contract:

•Residential/GSA-1 customers with system

Note: S.B. 295 was signed in March 2023, and changes related to net metering 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 (H.B. 2325) directing the Arkansas Public Service Commission (PSC) to establish net-metering rules for certain renewable-energy systems.* The PSC approved final rules for net metering in July 2002. Net metering rules and related state statutes have been amended several times afterward, including through H.B. 2334 (April 2007; expanding net metering availability), H.B. 1004 (March 2015; revised rule provisions related

Note: This credit expired on December 31, 2014, and is not allowed for devices installed on or after January 1, 2015. However, wind energy systems whose construction began prior to January 1, 2015 and were completed by January 1, 2017 are eligible for this credit.

North Dakota offers a corporate income tax credit for the cost of acquiring and installing a geothermal, solar, biomass, or wind energy system in a building or on a property owned or leased by a North Dakota taxpayer. For systems installed after December 31, 2000, and before January 1, 2015, the credit is equal to

Note: Funds for residential and large commercial rebates have been fully reserved. Rebates are no longer available for residential systems or large commercial systems. 

The City of Palo Alto Utilities (CPAU) PV Partners Program offers incentives to customers that install qualifying PV systems. The program, which has a budget of approximately $13 million over 10 years, is divided into 10 steps (residential incentives have 12 steps), each funded at $1.3 million. 

Incentive levels as of 3/11/2016 are described below. For current levels, consult the program web site above.

• Small/Medium Commercial (Rate E-2, E-4) <30 kW: $1.20/watt AC
  
• Small/Medium Commercial (Rate

The Los Angeles Department of Water and Power's (LADWP) Solar Incentive Program began in 2000, with a funding level of $150 million. The California Solar Initiative, created in 2007 upon the enactment of SB 1, established new guidelines for municipal utilities to follow, and established new funding levels. The LADWP Board of Commissioners approved the Solar Incentive Program Guideline Revisions on September 4, 2007, to comply with SB1. The revised program was suspended in early 2011, but was revised and relaunched on September 1, 2011.

The Solar Incentive Program has 10 phases with declining incentive levels as certain installed