Renewable portfolio standards in the United States

RPS multipliers adjust the amount of renewable energy credits (RECs) awarded (up or down) for each MWh of electricity produced based on its source.[5] Since the definition of what is considered "renewable energy" varies, for example, nuclear power, and whether an RPS program should consider environmental damage of a renewable energy source (for example, hydroelectric dams, bird strikes of wind turbines, geothermal earthquakes, solar thermal water use) affects RPS program design and implementation. A state can use a multiplier as protectionism to local renewable energy generators from out of state renewable generators. Since RECs are regulated at a state level, their ability to be traded over state lines varies.

Over 16 of the approximately 30 states with RPS programs have also established a set-aside for solar energy. This results in the creation and trading of RECs specific to solar known as solar renewable energy certificates (SRECs). With a separate market for SRECs, states are able to ensure that a portion of their renewable energy comes from solar. As a result, states with solar carve-outs, such as New Jersey, have had more success in promoting solar energy through the RPS than states, such as Texas, with a generic REC market or REC multiplier.

Energy supply companies need to show that they have acquired a particular percentage of their power sales from the designated technology type. Multiple technology types are bundled together in tiers or classes with similar effect. Not all states have set-asides or tiers (some preferring to promote particular technologies through credit multipliers) and each state that groups technologies together in a tier does so differently.

Every state defines renewable technologies differently. Many states exclude existing renewable facilities from benefiting from an RPS program. A state's definition of eligible technologies is also driven by the objectives of the program. Programs designed to promote diversity in generation types may include or promote technologies different from programs designed to achieve environmental goals.

In a 2011 report published by the Union of Concerned Scientists, Doug Koplow said:

Nuclear power should not be eligible for inclusion in a renewable portfolio standard. Nuclear power is an established, mature technology with a long history of government support. Furthermore, nuclear plants are unique in their potential to cause catastrophic damage (due to accidents, sabotage, or terrorism); to produce very long-lived radioactive wastes; and to exacerbate nuclear proliferation.[6]

In order to motivate compliance, states that have enforceable standards will have penalties for utilities that fail to reach the specified targets. States may choose to set penalty values or make arbitrary penalty amounts when suppliers fail to meet a renewable target. Where specific technologies are promoted through either tiers or set-aside provisions, the penalties for missing these targets are typically separate and higher. Some states have higher penalties for repeat violations and others escalate penalties on a yearly basis according to price indices.

All states either place caps on the cost of the program or include some form of 'escape clause' whereby the regulatory authority can suspend the program or exempt utilities from meeting its requirements. The need for such measures arises from the difficulties in estimating in advance the actual cost of the RPS program. The realized cost to the utility and the ratepayer is not known until the supply and cost base of renewable power, along with actual demand, is established. However, likely costs can be estimated, and some states appear to have set cost caps low enough that complete RPS requirements could not be fulfilled without a significant decrease in renewables costs.[7] Empirical estimates suggest that states with RPSs experienced an approximately 11 percent increase in electricity prices (data for 1990–2013) and that these standards are approximately twice as costly as an equivalent least-cost portfolio to achieve CO2 reductions with natural gas.[8][9]

With few exceptions, utilities are allowed to recover the additional cost of procuring renewable power. The method by which this can be achieved varies by state. Some states opt for a ratepayer surcharge while others require utilities to include costs in rate base. In some instances, utilities are even able to recover the cost of penalties associated with non-compliance.

However, the federal government has discussed enacting a nationwide RPS in the future. Such a policy would establish a common goal for every state in the country, which is less confusing than the state by state table below. If the federal government does pass a national Renewable Portfolio Standard it could be problematic for some states. Since each state has a unique environmental landscape, each state has different abilities when it comes to producing renewable energy. States with less renewable resources available could be penalized for their lack of ability.

RPS mechanisms have tended to be most successful in stimulating new renewable energy capacity in the United States where they have been used in combination with federal Production Tax Credits (PTC). In periods, where PTC have been withdrawn the RPS alone has often proven to be insufficient stimulus to incentivise large volumes of capacity.[10]

Public Utility Regulatory Policies Act is a law passed in 1978 by the United States Congress as part of the National Energy Act that is meant to promote greater use of renewable energy.

In 2009, the US Congress considered Federal level RPS requirements. The American Clean Energy and Security Act reported out of committee in July by the Senate Committee on Energy & Natural Resources includes a Renewable Electricity Standard that calls for 3% of U.S. electrical generation to come from non-hydro renewables by 2011–2013.[11] However, the proposed Support Renewable Energy Act died in the 111th Congress.

In 2007, the Edison Electric Institute, a trade association for America’s investor-owned utilities, reiterated their continuing opposition to a nationwide RPS; among the reasons included were that it conflicts with and preempts existing RES programs passed in many states, it does not adequately consider the uneven distribution of renewable resources across the country, and it creates inequities among utility customers, by specifically exempting all rural electric cooperatives, and government-owned utilities from the RES mandate.[12]

The American Legislative Exchange Council (ALEC) drafted the model bill Electricity Freedom Act, which ALEC affiliate representatives are attempted to roll out in various states and which "would end requirements for states to derive a specific percentage of their electricity needs from renewable energy sources."[13] As a result, of being unable to stop the approval of this model legislation, the American Wind Energy Association and the Solar Energy Industry Association allowed their ALEC membership lapse after one year as members.

Different state RPS programs issue a different number of Renewable Energy Credits depending on the generation technology; for example, solar generation counts for twice as much as other renewable sources in Michigan and Virginia.[14]

General citation:[15] States with active RPS that have not yet been met are in bold.

Georgia, Indiana, Kansas, North Dakota, Oklahoma, South Dakota, and Utah have set voluntary standards;[15] these are not shown to result in additional renewable generation installations and are not listed in this table.

The California Renewables Portfolio Standard was created in 2002 under Senate Bill 1078 and further accelerated in 2006 under Senate Bill 107. The bills stipulate that California electricity corporations must expand their renewable portfolio by 1% each year until reaching 20% in 2010. On November 17, 2008, Governor Arnold Schwarzenegger signed executive order S-14-08 which mandated a RPS of 33% by 2020 which sits in addition to the 20% by 2010 order.[43][44] The target has been extended to 50% by 2030.[45] In September 2018, Governor Jerry Brown signed legislation increasing the state's requirement to 100% clean energy by 2045 and increasing the interim target to 60% by 2030.[46]

The Colorado Renewable Portfolio Standard was updated from 20% to 30% in the 2010 Legislative Session as House Bill 1001. This increase is anticipated to increase solar industry jobs from current (2009) estimated 2,500 to 33,500 by 2020. The updated RPS is also anticipated to create an additional $4.3B (U.S.) in state revenue within the industries.[47]

On October 6, 2008, Public Act 295 was signed into law in the State of Michigan. This Act, known as the Clean, Renewable and Efficient Energy Act, established a Renewable Energy Standard for the State of Michigan. The Renewable Energy Standard requires Michigan electric providers to achieve a retail supply portfolio that includes at least 10% renewable energy by 2015.[48]

A ballot proposal to raise the standard to 25% renewable energy by 2025 as a constitutional amendment was put to the voters in the November 2012 General Election as Proposal 3. A Proposal To Amend the State Constitution to Establish a Standard for Renewable Energy.[49] The ballot proposal was defeated with over 60% opposing the proposal.[50]

According to the State of Michigan, as of March 4, 2013 "progress toward the first compliance year in 2012 and the 10 percent renewable energy standard in 2015 is going smoothly. Michigan’s electric providers are on track to meet the 10 percent renewable energy requirement. The renewable energy standard is resulting in the development of new renewable capacity and can be credited with the development of over 1,000 MW of new renewable energy projects becoming commercially operational since the Act became law. The weighted average price of renewable energy contracts is $82.54 per MWh which is less than forecasted in REPs."[51]

In 1997 Nevada passed a Renewable Portfolio Standard as part of their 1997 Electric Restructuring Legislation (AB 366) It required any electric providers in the state to acquire actual renewable electric generation or purchase renewable energy credits so that each utility had 1 percent of total consumption in renewables. However, on June 8, 2001, Nevada Governor Kenny Guinn signed SB 372, at the time the country's most aggressive renewable portfolio standard. The law requires that 15 percent of all electricity generated in Nevada be derived from new renewables by the year 2013.[52]

The 2001 revision requires that at least 5 percent of the renewable energy projects must generate electricity from solar energy, which have a credit multiplier.[52]

In June 2005, the Nevada legislature extending the deadline and raising the requirements of the RPS to 20 percent of sales by 2015.[52] This was further raised to 25 percent by 2025 in 2009.

In an April 2008 unanimous vote, the Ohio legislature passed a bill requiring 25 percent of Ohio's energy to be generated from alternative and renewable sources, of which half or 12.5 percent must derive from renewable sources.[53] In July 2019, Ohio passed House Bill 6 in order to subsidize two failing nuclear power plants and eliminate their RPS altogether at 8.5% in 2026.[54]

For Oregon’s three largest utilities (Portland General Electric (PGE), PacifiCorp and the Eugene Water and Electric Board), the standard starts at 5% in 2011, increases to 15% in 2015, 20% in 2020, and 25% in 2025. Other electric utilities in the state, depending on size, have standards of 5% or 10% in 2025.[55] In 2016, the target was raised to 50%, as two companies must supply 50% of Oregon's power as renewable by 2040.[36]

The Texas Renewable Portfolio Standard was originally created by Senate Bill 7 in 1999. The Texas RPS mandated that utility companies jointly create 2000 new MWs of renewables by 2009 based on their market share. In 2005, Senate Bill 20, increased the state’s RPS requirement to 5,880 MW by 2015, of which, 500 MW must come from non-wind resources. The bill set a goal of 10,000 MW of renewable energy capacity for 2025. The state's installed capacity reached the 10,000 MW target in early 2010, 15 years ahead of schedule.[56]