EPA states that one goal of the RFS is to reduce greenhouse gas emissions. Specifically, the RFS is designed to reduce these emissions by increasingly replacing petroleum-based fuels with biofuels that have lower associated greenhouse gas emissions released throughout their lifecycle. Some of these greenhouse gas emissions are directly released at each stage of a fuel’s lifecycle, which, for biofuels, includes the emissions associated with growing the feedstock, transporting it, converting it to a biofuel, distributing the biofuel, and burning it in an engine. Other emissions are released indirectly through broad economic changes associated with increased biofuel use, such as changes in land use. The lifecycle greenhouse gas emissions from biofuels cannot be directly measured, so they are estimated using mathematical models that account for greenhouse gas emissions at each stage of the lifecycle. These models—in particular, Argonne National Laboratory’s Greenhouse Gases, Regulated Emissions, and Energy Use in Transportation model—have been used by researchers for nearly 30 years. However, the complexity of estimating the lifecycle emissions associated with biofuels and the sensitivity of the models to assumptions limit the precision of the modeled results. The RFS established statutory greenhouse gas reduction requirements for specific types of biofuels. These types can be grouped into two broad categories—conventional biofuels and advanced biofuels—defined by the amount of reduction they are required by statute to achieve in lifecycle greenhouse gas emissions relative to the 2005 emissions baseline for gasoline or diesel. Conventional. Conventional biofuels from new facilities must achieve greenhouse gas emissions at least 20 percent lower than traditional petroleum-based fuels, which include gasoline and diesel. The dominant conventional biofuel produced to date is corn-starch ethanol. Advanced. Advanced biofuels must achieve lifecycle greenhouse gas emissions at least 50 percent lower than traditional petroleum-based fuels. Advanced biofuels may include a number of fuels, including fuels made from algae or sugar cane, but the category excludes ethanol derived from corn starch. This category includes the following subcategories: Biomass-based diesel: biodiesel or renewable diesel that has lifecycle greenhouse gas emissions at least 50 percent lower than traditional petroleum-based diesel fuels. Cellulosic: renewable fuel derived from any cellulose, hemicellulose, or lignin that is derived from renewable biomass and has lifecycle greenhouse gas emissions at least 60 percent lower than traditional petroleum-based fuels. The RFS established statutory requirements for the amount of biofuels that must be blended into gasoline. These amounts increase from 9 billion gallons in 2008 to 36 billion gallons in 2022. The RFS sets statutory volume requirements for each type of biofuel based on the categories described above, but EPA can waive those requirements and establish its own, if warranted. From 2010 through 2013, EPA used its waiver authority each year to reduce the volume requirement for cellulosic biofuel while keeping the total volume requirement for all biofuels at the statutory level. Starting in 2014, EPA set lower volume requirements for all advanced biofuels and lower total biofuel blending requirements. EPA cited, among other things, inadequate domestic supply as a reason for the waivers. Since 2014, the gap between RFS requirements for advanced biofuels and EPA requirements after waivers were issued has increased. Figure 1 compares RFS statutory volumes for various types of biofuels with volumes that EPA established using the waiver authority. In 2018, the biofuel used most often to comply with the RFS has been conventional ethanol derived from corn starch. As we reported in 2016, production of cellulosic and other advanced biofuels has not progressed as initially expected under the RFS. Although, as we reported, advanced biofuels are technologically well understood, current production is far below the volume needed to meet the statutory targets for these fuels. For example, the cellulosic biofuel blended into transportation fuel in 2015 was less than 5 percent of the statutory target of 3 billion gallons. Given current production levels, most experts we interviewed told us that advanced biofuel production cannot achieve the statutory targets of 21 billion gallons by 2022. The shortfall of advanced biofuels is the result of high production costs, despite years of federal and private research and development (R&D) efforts. The federal government has supported R&D related to advanced biofuels through direct research and grants in recent years, with the focus of this R&D shifting away from cellulosic ethanol, an advanced biofuel that is not fully compatible with current vehicle engines and fuel distribution infrastructure, and toward other biofuels that are compatible with this infrastructure. Even before the establishment of the RFS, ethanol was used as an additive in gasoline. It serves as an oxygenate, to prevent air pollution from carbon monoxide and ozone; as an octane booster, to prevent early ignition, or “engine knock;” and as an extender of gasoline stocks. In purer forms, it can also be used as an alternative to gasoline in automobiles specially designed for its use. Approximately 99 percent of blended gasoline consumed in the United States is “E10”—a blend of gasoline with up to 10 percent ethanol. The use of ethanol as an oxygenate is linked to the demise of a petroleum derivative known as methyl tertiary butyl ether, or MTBE. MTBE had been used as an octane booster since the late 1970s, and was used in later years to fulfill the oxygenate requirements set by Congress in the 1990 Clean Air Act amendments. According to a report by the Congressional Research Service, MTBE contaminated drinking water, and about half of the states passed legislation to ban or restrict its use. Although MTBE was not restricted by federal law, gasoline refiners sought a substitute because of concerns over potential liability. To replace MTBE, refiners switched to ethanol. Congressional Research Service, MTBE in Gasoline: Clean Air and Drinking Water Issues (updated Apr. 14, 2006). Five states passed and put into effect ethanol mandates similar to the RFS—Hawaii, Minnesota, Missouri, Oregon, and Washington. In Minnesota, Missouri, and Oregon these mandates required 10 percent of blended gasoline to be ethanol, while Washington required 2 percent ethanol in gasoline and Hawaii required that 85 percent of fuel sold in the state must contain 10 percent ethanol. Minnesota was the first to put an ethanol mandate into effect—in May 2003. Hawaii followed with an effective date of April 2006. The Missouri, Oregon, and Washington mandates were put into effect in 2008. Louisiana, Montana, and Pennsylvania also passed laws requiring ethanol blending mandates, but these mandates have not gone into effect because in-state ethanol production volumes have not reached levels required to trigger them. The federal government has supported the development of a domestic biofuels industry not only through the RFS but also through tax credits. The Energy Tax Act of 1978, among other things, provided tax incentives designed to stimulate the production of ethanol for blending with gasoline. These blending incentives were restructured as part of the Volumetric Ethanol Excise Tax Credit (VEETC) in 2004. In 2009, we found that the VEETC and the RFS may have been duplicative with respect to their effects on ethanol consumption. We and others found that the VEETC was no longer stimulating additional ethanol consumption. The blending incentives in the VEETC expired in December 2011. There are also federal tax incentives to promote the production and use of advanced biofuels. These include the Biodiesel Income Tax Credit, which provides a $1 per-gallon tax credit for producers of certain forms of biodiesel or renewable diesel. Separately, the Second Generation Biofuel Producer Tax Credit provided advanced biofuel producers a tax credit of up to $1.01 per gallon of advanced biofuel produced and used domestically. Evidence from studies, interviews with experts, and our analysis suggest that the nationwide RFS was likely associated with modest price increases outside of the Midwest. Likely variations in these gasoline price effects depended, in part, on state-by-state variation in the costs to transport and store ethanol. For example, the Midwest was already producing and blending ethanol, so it had lower transportation costs and had already built necessary storage infrastructure. Other regions began blending ethanol later as rising volumes of ethanol required under the RFS forced more ethanol into the system and as states began blending ethanol. These states incurred new transportation and storage infrastructure costs, which likely resulted in higher gasoline prices compared to those in the Midwest states or states that had not yet begun to blend ethanol. Overall, it is likely that as the expanded blending requirements of the RFS caused non-Midwestern states and localities to begin blending ethanol, these states and localities experienced increased gasoline prices of a few cents per gallon compared to what they otherwise would have been. According to the experts we interviewed as well as the studies we reviewed, the RFS likely caused small changes in retail gasoline prices that varied by region. The experts, stakeholders, and studies identified two main ways in which the RFS may have affected prices. Specifically, the RFS may have (1) increased transportation and storage costs in regions outside the Midwest, and, (2) caused an initial increase in refining investment costs that over the long term reduced refining costs for gasoline. The RFS may have affected retail gasoline prices by increasing transportation costs in certain regions. Retail gasoline consists of two components—ethanol and blendstock, which is the petroleum-based gasoline that ethanol is blended with to make retail gasoline. Currently, blendstock and ethanol are typically transported in different ways. Blendstock can be shipped via pipeline, which is the most cost-efficient method of transporting fuel. However, ethanol is more corrosive and cannot be shipped in pipelines currently used for blendstock; as a result, it must be transported using costlier methods, such as rail, barge, and tanker truck. Ethanol is produced primarily in the Midwest, where most corn is produced. According to the studies we reviewed, this means that Midwest gasoline retailers, being closer to the supply of ethanol, may have been able to charge consumers lower prices for retail gasoline relative to non- Midwest gasoline retailers because of their lower transportation costs for ethanol. Similarly, higher transportation costs outside of the Midwest may have resulted in higher prices of retail gasoline in those regions. Figure 2 illustrates U.S. ethanol production in 2005, before the RFS became effective. In addition, the RFS may also have affected retail gasoline prices by increasing storage costs in certain regions. Because ethanol is more corrosive than blendstock, it must be stored differently. According to one study we reviewed, ethanol was being blended into gasoline in many locations in the Midwest prior to the establishment of the RFS. As a result, the Midwest already had the infrastructure needed to store ethanol. According to another study, in some places outside of the Midwest ethanol was typically not being blended into gasoline prior to the establishment of the RFS, and therefore costly infrastructure changes, such as installing different seals and gaskets in tanks, were needed so that retailers could store blended gasoline. For example, the California Energy Commission estimated the costs of such infrastructure changes to be approximately $60 million in California. Unlike transportation costs, the costs of infrastructure changes were incurred just once, according to industry stakeholders we interviewed; therefore the effect of such costs on retail prices would be expected to have diminished over time. The cost of producing retail gasoline depends in part on the costs of its two components. The RFS may have affected the costs of blendstock and ethanol in various ways, and according to the experts we interviewed, past GAO work, and the studies we reviewed, these costs may have contributed to changes in gasoline prices. Blendstock. The RFS may have initially increased both refiners’ costs to produce blendstock compatible with ethanol blending and the costs of shipping and storing such blendstock; however, these costs may have decreased over time. More specifically, the RFS may have initially increased refiners’ costs because refiners had to change their configuration to produce a lower octane blendstock to accommodate ethanol blending. Many experts we interviewed stated that producing blendstock with a lower octane level required costly changes to refinery infrastructure and processes. However, according to these experts and stakeholders, since ethanol is relatively high in octane, blending ethanol into retail gasoline allows refiners to produce blendstock with a lower octane level. As a result, according to many of the experts we interviewed, after the initial investment by refineries to switch to the lower octane blendstock, refiners could produce that blendstock at lower cost. This would have led to higher initial costs but lower long-term costs once infrastructure costs had been capitalized. The higher initial cost is consistent with our past work in which we noted that shipping more types of blendstocks—the result of a proliferation of blendstocks adopted by states and localities to meet Clean Air Act standards—increases the costs of shipping and storing blendstocks at terminals for distribution to retail sellers. As a result, according to one expert familiar with our past work, as ethanol blending spread further and further away from the production center in the Midwest states, there were more types of blendstocks in the pipeline and storage terminals, which would have increased costs. This expert said that over the longer run and once ethanol blending had expanded to encompass the majority of gasoline sold in the United States, this effect would have disappeared because virtually all the blendstock flowing through the pipeline and storage system would be compatible with blending ethanol. Ethanol. It is unclear whether the RFS increased or decreased the cost of ethanol. One source we reviewed indicated that the RFS may have increased the cost of ethanol by increasing demand for corn, which would drive up the price of corn. On the other hand, one expert we spoke to stated that the RFS may have decreased the cost of ethanol in the long term by providing incentives for producers to invest in more efficient ethanol production processes, which would lower production costs over time. However, it is unclear what the longer-term effects of ethanol blending on gasoline prices have been. We believe this is because once all locations had made the infrastructure investments and most gasoline blendstock produced was consistent with blending ethanol then there would be two continuing effects: (1) the transportation and blending costs of ethanol, which would tend to push retail prices higher and depend on the distance traveled and the modes of transport, and (2) the lower cost of producing lower octane blendstock. The former effect might dominate for locations far from the production source of ethanol and for which more costly modes of transport were used while the lower blendstock costs might dominate for locations close to the production source of ethanol, those that have low transportation costs, or both. However, the data available to us do not allow us to test this long-term effect. We studied the effects of ethanol blending mandates in the five states that had such mandates prior to and including 2008; these mandates are similar to but preceded the RFS ethanol blending mandates on retail gasoline prices. We found that these state mandates were associated with gasoline price decreases in the two Midwestern states we evaluated and price increases in three non-Midwestern states. Specifically, during the period we studied, when the ethanol mandates in Minnesota and Missouri were in effect, our model estimates that, all else remaining equal, retail gasoline prices were lower by approximately 8 and 5 cents per gallon in these states, respectively, than they would have been without the mandates. By contrast, when the ethanol mandates in Hawaii, Oregon, and Washington were in effect, our model estimates that, all else remaining equal, retail gasoline prices were higher by approximately 8, 2, and 6 cents per gallon in these states, respectively, than they would have been without the mandates. These results are consistent with what other studies and experts found about the effects of blending ethanol with gasoline. Our model provides an indicator of the types of effects that the RFS likely had on retail gasoline prices as the increasing ethanol blending targets of the RFS began to push ethanol into more gasoline markets. Specifically, we can infer from the model that the RFS was associated with a modest gasoline price decrease in Midwest states. According to one expert familiar with our analysis and with the blendstock pipeline and storage system, expanding the volumes of lower octane feedstocks to the Midwest states would have the effect of reducing refining production costs because refiners serving the Midwest could do larger runs of lower octane blendstock and therefore benefit from economies of scale in refining runs. In addition, this would also have the effect of reducing pipeline and storage costs for blendstocks because larger volumes of lower octane blendstock could be shipped northward from the refining center in the Gulf of Mexico states to the Midwest. Larger volumes of uniform blendstock during pipeline shipping reduce costs compared to smaller shipments because different blendstocks intermix at the point they interface in a pipeline, and these mixed blendstocks either have to be downgraded and sold for less or pulled out entirely and re-refined to meet existing fuel standards. Conversely, we can infer from the model that the RFS was associated with modest gasoline price increases in states further from the Midwest producers as increasing ethanol targets caused those states to begin blending ethanol for the first time and for which more refining capacity had to convert to produce lower octane feedstock and ship it to more locations, thereby initially raising refining, pipeline, and storage costs as discussed previously in this report. The results of our analysis are also generally consistent with other work that examined the effects of different state ethanol-blending requirements on gasoline prices. For example, some states and localities started blending ethanol before the RFS made it effectively mandatory when these states and localities banned MTBE, an additive that increased the oxygen content of the fuel. When MTBE was banned, ethanol was typically added in its place. The one peer-reviewed study we identified that estimated the effects of the MTBE ban on gasoline prices found that in locations required to blend ethanol because of state MTBE bans, retail gasoline prices increased by 3 to 6 cents per gallon in non-Midwestern states, with larger price increases during times of high ethanol prices relative to crude oil prices. This study also found that retail gasoline prices in the Midwest may not have changed. While our own analysis, other studies we reviewed, and experts we spoke to cannot estimate precise price effects of the RFS on retail gasoline, we believe that collectively the evidence points to likely effects that varied by geographic region and that as RFS blending requirements rose and more and more non-Midwestern states and localities adopted ethanol blending, it is likely they saw modest increases in retail gasoline prices on the order of several cents per gallon. Conversely, as more and more states and localities blended ethanol and more refiners began producing larger runs of lower octane blendstock, the costs of acquiring this blendstock likely fell, and because Midwestern states had very low transportation costs for ethanol, their gasoline prices likely fell. Most of the experts we interviewed generally agreed that to date the RFS has likely had a limited effect, if any, on greenhouse gas emissions. Further, the RFS is unlikely to meet the greenhouse gas emissions reduction goals envisioned for the program through 2022. Regarding the RFS and greenhouse gas emissions to date, experts noted that the effect has been difficult to assess precisely and we found disagreement among some experts about whether the effect has been positive or negative. However, most experts agreed that the effect—whether an increase or decrease—has likely been limited. Regarding meeting RFS greenhouse gas emission reduction goals through 2022, as we reported previously, although advanced biofuels, such as cellulosic ethanol, achieve greater greenhouse gas reductions than conventional biofuels, such as corn- starch ethanol, the latter are likely to continue to account for most of the biofuel blended into domestic transportation fuels under the RFS because they are economical to produce while most advanced biofuels are not. Of the 13 experts we interviewed, 10 generally agreed that the RFS has likely had a limited effect, if any, on greenhouse gas emissions to date. However, these experts said that the effect is difficult to assess precisely, and they disagreed on whether the limited effect has been positive or negative. Specifically, the experts commenting on the topic were roughly evenly split between increases or decreases in greenhouse gas emissions, with some saying there were negligible effects. Experts we interviewed said that the effect that the RFS has had on greenhouse gas emissions is difficult to assess precisely because it involves complex factors that are challenging to quantify, including the lifecycle emissions associated with biofuel use. The RFS’s reliance on corn-starch ethanol to fill biofuel mandates has limited the ability of the RFS to reduce greenhouse gas emissions. Specifically, as we reported in November 2016, most of the biofuel blended to date has been conventional corn-starch ethanol, which has a smaller potential to achieve greenhouse gas reductions compared with advanced biofuels. Because of this, several experts we interviewed for the November 2016 report raised concerns about the extent to which the RFS has achieved its design of reducing greenhouse gas emissions. Furthermore, because the RFS has not been responsible for all of the ethanol used in the United States since the program took effect, not all greenhouse gas reductions associated with ethanol use have been the result of the RFS. More specifically, most experts agreed that ethanol use was historically driven, in part, by favorable market conditions and other policies, including state biofuel mandates, ethanol tax credits, and the phaseout of MTBE as an oxygenate for gasoline. Most experts we interviewed said they believed that the RFS had some effect on biofuel production by creating a guaranteed market for biofuels. Although experts’ views differed on the amount of ethanol that would have been produced without the RFS, most of them said that ethanol production capacity would likely be lower today if the RFS had not helped to establish markets. For example, four experts and one industry stakeholder representative that we interviewed hypothesized that if the RFS were repealed, refiners would continue to blend ethanol into fuel, although two experts and one stakeholder representative acknowledged that less ethanol would probably be blended without the RFS. In contrast, one expert indicated that the RFS provides a safety net for the ethanol industry but that this safety net may not be needed anymore. In addition, according to EPA officials, the vast majority of the corn-starch ethanol used to date has been produced by so-called grandfathered plants—plants in operation or under construction before a certain date— that have been exempt from RFS emissions reductions requirements. The grandfathered plants have likely limited the ability of the RFS to achieve greenhouse gas emissions reductions, but this effect has likely changed over time. Early on, when a higher percentage of grandfathered ethanol plants used coal as an energy source and had older technologies, EPA estimates indicated that ethanol from such plants produced more greenhouse gas emissions than petroleum-based gasoline. However, most of the experts we interviewed told us that over time grandfathered plants have upgraded technology to remain economically competitive and have converted to natural gas as an energy source, resulting in industry- wide efficiency improvements that reduce greenhouse gas emissions. These experts indicated that such upgraded plants do not likely have significantly different emissions than the newer plants subject to RFS emissions reductions requirements. Little quantitative information is available to compare the difference between greenhouse gas emissions associated with grandfathered plants and those associated newer plants. Finally, experts we interviewed disagreed on whether ethanol produced today generally complies with the RFS statutory requirement to reduce lifecycle greenhouse gas emissions by 20 percent relative to those of petroleum-based gasoline, which affects the extent to which the RFS has influenced greenhouse gas emissions. Of the 11 experts commenting on the topic, approximately half said that ethanol produced today likely met the 20 percent RFS greenhouse gas reduction requirement. Most of these experts pointed to recent lifecycle analysis studies. Recent studies have found that, relative to petroleum-based gasoline, corn-starch ethanol could reduce lifecycle emissions by 19 to 48 percent. While there are limitations and uncertainty associated with all lifecycle analyses, most experts we interviewed said that the models used for lifecycle analyses have improved over time and can provide reasonably accurate estimates of certain components of direct lifecycle greenhouse gas emissions, such as emissions associated with the energy used for farming and for producing the biofuel in a plant. Of the roughly half of experts who said that corn-starch ethanol likely does not meet the RFS greenhouse gas reduction requirements, almost all pointed to the potential for indirect emissions associated with biofuel production and use. Indirect emissions are complex to estimate and a source of uncertainty in lifecycle estimates, but including them could offset emissions reductions. These indirect emissions can be produced as the result of broad economic changes associated with increased biofuel use, including the following: Indirect land use change. Indirect land use change occurs when using agricultural land to grow biofuel feedstocks causes the conversion of previously nonagricultural lands in the United States and elsewhere in the world to maintain world agricultural production of food, feed, and fiber. Fuel market effects. Though difficult to quantify, expanded biofuel use may lead to an unintended increase in the global use of transportation fuel and more greenhouse gas emissions, according to most of the experts saying that corn-starch ethanol does not meet greenhouse gas reduction requirements. For example, increasing biofuel use in one part of the world could increase the relative supply of petroleum in other parts of the world, thereby lowering petroleum prices and increasing use of petroleum products there. In November 2016 we reported that, with the exception of biomass-based diesel, production of advanced biofuels was far below the volume needed to meet the statutory targets for these fuels (see fig. 3). For example, we reported that the cellulosic biofuel blended into transportation fuel in 2015 was less than 5 percent of the statutory target of 3 billion gallons. We found in another November 2016 report that the shortfall was the result of high production costs, despite years of federal and private R&D efforts. With regard to future advanced biofuel production, most experts we interviewed for the November 2016 report told us that such production cannot achieve the statutory targets of 21 billion gallons by 2022 because the investments and development required to make these fuels more cost-effective, even in the longer run, were unlikely in the investment climate at the time. Factors affecting this included the magnitude of investment and the expected long time frames required to make advanced biofuels cost competitive with petroleum-based fuels. Because the bulk of greenhouse gas emissions reductions were to come from such advanced biofuels, the expected emissions reductions have also not occurred. As mentioned previously, EPA uses RINs to regulate compliance with the RFS. Refiners or importers of transportation fuel in the United States are known as “obligated parties” and must submit RINs to EPA. The number of RINs that an obligated party must submit to EPA is proportional to the volume of gasoline and diesel fuel that it produces or imports and depends on the volumes of biofuel that must be blended with transportation fuels during the following calendar year as set by EPA. In accordance with EPA guidelines, a biofuel producer or importer assigns a unique RIN to a gallon of biofuel at the point of production or importation. When biofuels change ownership (e.g., are sold by a producer to a blender), the RINs generally transfer with the fuels. When a gallon of biofuel is blended or supplied for retail sale, the RIN is separated from the fuel and may be used by the obligated party to demonstrate compliance with the RFS or may be traded, sold, or held for use in the following year. Some vertically integrated refiners own blending operations, so they generate RINs that they can use to demonstrate compliance because they also blend their own fuel. Other refiners do not blend their own fuel and must purchase RINs to demonstrate compliance. The latter are called merchant refiners. Since biofuels supply and demand can vary over time and across regions, a market has developed for trading RINs. If a supplier has already met its required share and has supplied surplus biofuels for a particular biofuel category, it can sell the extra RINs to another entity or it can hold on to the RINs for future use. An obligated party that faces a RIN deficit can purchase RINs to meet its obligation. In our March 2014 report on petroleum refining, we noted that the RFS had increased compliance costs for the domestic petroleum refining industry or individual refiners. We reported that, according to the U.S. Energy Information Administration, corn-based ethanol RIN prices were low—from 1 to 5 cents per gallon from 2006 through much of 2012— because it was generally economical to blend up to or above the level that the RFS required. However, in 2013, prices for these RINs increased to over $1.40 per gallon in July before declining to about 20 cents per gallon as of mid-November. Several stakeholders told us at the time that this increase in RIN prices was primarily due to RFS requirements exceeding the capability of the transportation fuel infrastructure to distribute and the fleet of vehicles to use biofuels, a situation referred to as the blend wall. EPA officials told us at the time that high corn prices, which made ethanol more expensive relative to gasoline, also contributed to higher RIN prices during this period. A refiner we spoke with at the time attributed the decline in RIN prices in the second half of 2013 to EPA’s statements expressing its desire to address the blend wall. In our report, we noted that while the RFS applies to all refiners in the same way, the effect of the rise in RIN prices may depend on each refiner’s situation. Figure 4 shows historical RIN prices for conventional, advanced, and biodiesel RINs. Since our March 2014 report, corn-starch ethanol RIN prices have experienced periods of volatility. One expert stated that this is because ethanol prices have become tied with biodiesel prices since the RFS has required levels above the 10 percent blend wall. EPA officials agreed that once the 10 percent blend wall was reached, ethanol RIN prices have often risen to the price of biodiesel RIN prices. More specifically, biodiesel RIN prices are strongly affected by expectations about whether the biodiesel tax credit will be allowed to expire, which has often happened. In fact, EPA has at times explicitly taken the existence of the biodiesel tax credit into account when making rulings related to the RFS. As a result, both biodiesel RIN prices and ethanol RIN prices experience volatility. In general, ethanol RIN prices have closely tracked biodiesel RIN prices for the last 5 years. As we noted in our March 2014 report on petroleum refining, prices for RINs reflect several factors, including the cost of renewable fuels compared with the petroleum fuels they displace and the stringency of annual blending requirements. One expert we spoke with during the course of the audit work for this report stated that uncertainty about the future of the RFS has also affected RIN prices. Three experts and three industry stakeholders we interviewed spoke directly about the effect of RINs on retail fuel prices. All three experts stated that if RINs have any effect on prices it is small, while two of those experts also asserted that it was possible that RINs had no effect on prices at all. These experts argued that in a perfectly competitive fuel market, the blendstock refiners increase the price of blendstock because they know that they will need to pay for the RINs. At the same time, the retail gasoline blenders are able to save costs related to ethanol because of the value they receive for selling the RINs. In practice, according to experts, the market may not be perfectly competitive, so it is possible that RINs add from 1 to 10 cents to the retail price of gasoline in some parts of the country. One industry stakeholder also expressed the opinion that RINs would have little to no effect on retail gasoline prices, citing the same argument. Two industry stakeholders indicated that RINs would increase retail gasoline prices, although they did not specify by how much. These stakeholders argued that RINs represent the cost of producing retail gasoline; because ethanol has historically had a higher cost per mile than gasoline (though not per gallon), the RINs would represent this increased cost and would be reflected in retail gasoline prices. An EPA analysis found that RIN prices did not have a significant impact on retail fuel prices and concluded that any expected impact would be very small. For retail gasoline, EPA made the same argument as experts and stakeholders cited above. Although oil refineries and importers are the entities that are obligated to demonstrate compliance with the RFS, not all of them produce blended fuels. Thus, these entities cannot earn RINs themselves and need to purchase them on the RIN market. Our past work, as well as EPA analysis, has identified several issues of concern with RINs, including possible fraud in the market and concerns about the effect on small refiners, price volatility, and the point of obligation. Fraudulent RINs. As we reported in our November 2016 report on the RFS, some experts we spoke with at the time identified reducing RIN fraud and price volatility as a federal action that could incrementally encourage investment in advanced biofuels. Specifically, these experts said that a lack of transparency in the RIN trading market has led to an increased risk of fraud and increased volatility of RIN prices. Because RINs are essentially numbers in a computerized account, there have been opportunities for fraud, such as double counting RINs or generating RINs for biofuels that do not exist. For example, in our March 2014 report on petroleum refining we reported that EPA had issued several notices of violation alleging that five companies generated invalid RINs without producing qualifying renewable fuels. EPA officials told us that, since that time, EPA has made additional notices of violation, although many pertain to actions taken prior to March 2014. Since the start of the RFS, EPA has alleged that approximately 382,524,480 RINs are invalid. Furthermore, obligated parties that inadvertently purchase fraudulent RINs lose the money spent to purchase them, must purchase additional RINs to meet their obligations, and face additional costs. This has a disproportionate effect on small refiners, according to our November 2016 report. Whereas large obligated parties—in particular, vertically integrated refiners that typically own blending operations—can generate RINs by blending fuel, small refiners do not blend fuel, must purchase their RINs on the market to meet their obligations, and are therefore more likely to be adversely affected by fraudulent RINs. To address concerns over these issues, EPA established an in-house trading system called the EPA Moderated Transaction System (EMTS). EPA officials believe that this system provides significant capabilities over prior reporting tools used to implement the RFS, allowing enforcement to more quickly identify potential RFS violations versus entry errors that were common with pre-EMTS RFS reporting. EPA officials also informed us of a voluntary quality assurance program intended to provide obligated parties a program to ensure that RINs entering commerce are valid. However, EPA has maintained that verifying the authenticity of RINs is the duty of obligated parties. Distribution of compliance costs. In our March 2014 report on petroleum refining, we reported that, according to EPA, refiners experience the same compliance costs regardless of whether they are vertically integrated refiners or merchant refiners that purchase RINs for compliance. However, we also reported that the views of several stakeholders differed from EPA’s. In that regard, in a 2011 study, the Department of Energy reported that the degree to which a small refiner can actively blend refinery production with biofuels could contribute greatly to the economic hardship incurred from complying with the RFS. We noted that, while the RFS applies to all refiners in the same way, effects of rising or falling RIN prices may vary depending on each refiner’s situation. According to several stakeholders we interviewed at the time, RFS compliance had been most difficult for merchant refiners, because they did not blend their own fuel and had to purchase RINs from others, increasing their costs of compliance. Price volatility. Similarly, according to the experts we interviewed for our November 2016 report on the RFS, price volatility in RIN markets had adversely affected small refiners in particular and led to uncertainty among investors. While most RINs are bought and sold through private contracts registered with the EMTS, as we mentioned previously, RINs are also traded in markets. Some experts that we interviewed for the November 2016 report told us that price volatility may have been due, in part, to nonobligated parties speculating in these markets. Such price fluctuations introduced uncertainty for small refiners about the costs of compliance with the RFS because they had to purchase their RINs on the market. Placement of the point of obligation. In our November 2016 report on the RFS, we reported that according to some experts, blenders should be the obligated parties instead of importers and refiners. According to some of these experts, when EPA designed the RFS, it placed the obligation for compliance on the relatively small number of refiners and importers rather than on the relatively large number of downstream blenders in order to minimize the number of obligated parties to be regulated and make the program easier to administer. However, these experts told us that obligating refiners and importers has not worked to incentivize investors to expand infrastructure to accommodate higher ethanol blends. One expert we spoke with stated that because blenders are either retailers or sell to retailers, blenders would be better situated to pass RIN savings along to consumers. This in turn might encourage demand for higher ethanol blends and incentivize infrastructure expansion. Some experts told us at the time that EPA should make RIN market trading more open and transparent like other commodity markets, which could reduce the potential for fraudulent RIN activities and reduce RIN price volatility. EPA has taken some actions to address these issues. Specifically, EPA officials we interviewed for this report told us that EPA publishes a variety of aggregated information on its website each month to promote market transparency, including RIN generation and use, available RINs, RIN prices and trade volumes, RIN holdings, and small refinery exemption information. According to these officials, EPA also requires all RIN trades to be entered into EMTS from both the buy and sell sides, and only finalizes a transaction in the system if the buy and sell sides match. EPA officials said that transparency of aggregated RIN data helps the market function more efficiently and minimizes price volatility; however, they acknowledged that many factors contribute to RIN prices and RIN price changes, and it is impossible to attribute such changes to any single factor. Furthermore, according to EPA officials, the memorandum of understanding on RIN market manipulation that EPA has entered into with the Commodity Futures Trading Commission will also help make RIN markets more open and transparent. Finally, EPA officials stated that in response to a recent White House direction, EPA is currently drafting a regulatory proposal to implement market reforms and additional transparency measures to prevent price manipulation in the RIN market. According to EPA officials we interviewed for this report, EPA received several petitions requesting that it consider changing the point of obligation from refiners and fuel importers to fuel blenders. In November 2017, EPA denied the petitioners’ request. In the denial, EPA said that it does not expect a benefit of increased use of biofuels as a result of changing the point of obligation. Furthermore, it is EPA’s position that changing the point of obligation could increase the complexity of the RFS program and would likely disrupt both the RFS program and the fuels market. By law, small refineries were exempted from the RFS through compliance year 2010, and 24 small refineries were granted an exemption for compliance years 2011 and 2012. Beginning with the 2013 compliance year, small refineries have been able to petition EPA annually for an exemption from their RFS obligations. EPA states on its website that EPA may grant the extension of the exemption if EPA determines that the small refinery has demonstrated disproportionate economic hardship. According to EPA officials, the statute directs EPA to consult with the Department of Energy, and to consider the department’s Small Refinery Study and “other economic factors” in evaluating small refinery exemption petitions. EPA conducts its review of small refinery petitions on a case-by- case basis and applies these statutory criteria to its evaluations. According to EPA’s website, EPA’s decision to grant an exemption has the effect of exempting the gasoline and diesel produced at a refinery from the percentage standards, and the exempted refinery is not subject to the requirements of an obligated party for fuel produced during the compliance year for which the exemption has been granted. For the first few years, EPA data show that EPA granted roughly half of petitions; however, starting in compliance year 2016, the number of exemptions granted increased significantly. In compliance year 2016, EPA received 20 petitions and granted 19, with the final petition still pending. In compliance year 2017, EPA received 37 petitions and granted 29, with 1 declared ineligible or withdrawn and the remaining 7 still pending. The data show that this increase in granted exemptions correlates to an increase in estimated exempted volumes of gasoline and diesel, with the exempted amounts increasing from 3.07 billion gallons in compliance year 2015 (equivalent to an estimated 290 million RINs) to 13.62 billion gallons in compliance year 2017 (equivalent to an estimated 1,460 million RINs). To put these volumes into context, EPA data show that the total renewable volume obligation for compliance year 2015 was 17.53 billion gallons and for compliance year 2017 it was 18.91 billion gallons. We provided a draft of this report to the Departments of Agriculture and Energy, and to the Environmental Protection Agency, for review and comment. USDA, DOE, and EPA provided technical comments, which we incorporated where appropriate. USDA also provided written comments, which are reproduced in appendix IV. In summary, USDA expressed concerns in three areas. First, USDA disagreed with GAO’s conclusion that the RFS has had a limited effect, if any, on reducing greenhouse gas emissions. USDA asserts that scientific research shows significant effects on greenhouse gas emissions from blending ethanol into the nation’s fuel supply, based on the greenhouse gas benefits of ethanol produced using current technologies relative to gasoline. The objective of our work was to address the effect to date on greenhouse gas emissions that has been specifically attributable to the RFS, not whether blending ethanol into the nation’s fuel supply has effects on greenhouse gas emissions. We report that the RFS is not the only reason that ethanol is used in the fuel supply, and that ethanol would have been produced and used in the United States, even without the RFS. For example, as we noted in the report, ethanol blended into gasoline provides benefits as an oxygenate, to prevent air pollution from carbon monoxide and ozone; as an octane booster, to prevent early ignition, or “engine knock;” and as an extender of gasoline stocks. As a result, not all greenhouse gas reductions associated with ethanol use have been the result of the RFS. Drawing conclusions about the broader impact of ethanol on emissions generally was not our objective and is not appropriate for a report examining the impact of the RFS. Second, USDA criticized our methodology, which reported experts’ views on the effect of the RFS on greenhouse gas emissions. USDA stated that this methodology, by design, could not arrive at a consensus and did not synthesize the latest research. We chose our methodology, which relied on expert views supplemented by relevant reported research, because of its ability to yield more extensive, informative, and supportable answers to our objective than a narrower literature review, as suggested by USDA. More specifically, we reviewed much of the literature on this subject, and used the literature, along with referrals from other experts and recommendations from the National Academy of Sciences for prior GAO work, to assist in selecting experts whose expertise included knowledge of the relevant and most recent research on the issue. We selected respected experts representing all perspectives to span the disciplines required to answer our objective and to guard against drawing biased conclusions. Those experts were aware of all research, even that with conclusions contrary to their own. The studies that USDA cites do not represent a wide range of perspectives; they represent the views of a few studies focused specifically on the lifecycle emissions of ethanol. In addition, as we indicate, the perspectives we obtained from industry stakeholders were not used to support our findings on the effects of the RFS on greenhouse gas emissions, as USDA implies. Rather, stakeholders’ views were used to inform some of our examples and corroborate some aspects of the experts’ views—we attribute information to the stakeholders in these instances. The consensus we found among experts representing diverse perspectives was that the RFS has likely had a limited effect on greenhouse gas emissions to date and that the program is unlikely to meet its future greenhouse gas emissions reduction goals. Third, USDA commented that our conclusion that the RFS likely had modest impacts on gasoline prices should be augmented by a discussion of the volatility of gasoline prices. USDA’s comments appear to imply that the changes in prices we found are even smaller or less impactful on consumers because overall gasoline prices are themselves volatile. This is not an accurate interpretation of what we found. For example, increased prices in non-Midwest states represent additional expenditures on gasoline and consequent reductions in other household spending. Because a discussion of historic gasoline price volatility does not have bearing on the effect of the RFS on prices, we are not including it. As agreed with your office, unless you publicly announce the contents of this report earlier, we plan no further distribution until 30 days from the report date. At that time, we will send copies to the appropriate congressional committees; the Secretaries of Agriculture and Energy; the Administrator of the Environmental Protection Agency; and other interested parties. In addition, the report will be available at no charge on the GAO website at http://www.gao.gov. If you or your staff members have any questions about this report, please contact me at (202) 512-3841 or ruscof@gao.gov. Contact points for our Offices of Congressional Relations and Public Affairs may be found on the last page of this report. GAO staff who made key contributions to this report are listed in appendix V. To determine what is known about the effect that the Renewable Fuel Standard (RFS) has had to date on 1) retail gasoline prices in the United States and 2) greenhouse gas emissions, we conducted semistructured interviews with 18 experts with expertise on these topics. Of the 18 experts we interviewed, 7 discussed the effect that the RFS has had on retail gasoline prices. Thirteen discussed the effect that the RFS has had on greenhouse gas emissions, though one expert declined to be identified. Two of the experts commented on the effect of the RFS on both prices and emissions. The specific areas of expertise varied among the experts we interviewed, so not all of the experts commented on all of our interview topics. The experts we interviewed for each topic are listed below. Dr. Antonio Bento, University of Southern California Dr. John M. DeCicco, University of Michigan Dr. Jason Hill, University of Minnesota Dr. Stephen Kaffka, University of California, Davis Dr. Madhu Khanna, University of Illinois Dr. Lee Lynd, Dartmouth College Dr. Steve McGovern, PetroTech Consultants, LLC Dr. John Miranowski, Iowa State University Dr. GianCarlo Moschini, Iowa State University Dr. Richard Plevin, University of California, Berkeley Dr. Wallace E. Tyner, Purdue University Dr. Michael Wang, Argonne National Laboratory One expert we interviewed declined to be identified. This appendix describes the econometric model we developed to estimate the effect of the state ethanol mandates on retail gasoline prices, provides the results, and discusses limitations. In order to develop evidence of the likely effects of the Renewable Fuel Standard (RFS) on the incremental adoption of ethanol blending by states as RFS targets grew, we developed an econometric model to analyze the effect state ethanol mandates on retail gasoline prices. Specifically, we analyzed how state policies mandating certain levels of ethanol blending in retail gasoline affected retail gasoline prices in those states. We obtained retail gasoline price data from the Oil Price Information Service. The data identified the simple average price across each state for each grade of fuel—regular grade gasoline, midgrade gasoline, premium gasoline, and diesel. There also exist local fuel specifications, on top of state policies. Price data are only available at the state level, and we are not able to identify directly the effect of local fuel policies on prices. We therefore included controls that represent the percentage of retail stations in the state that are affected by the local specifications. To reduce distortion from dissimilar regulations and outliers, we did not include prices (1) from the state of California and (2) for products other than regular-grade gasoline. Therefore, the data we used for our analysis comprised prices collected from 49 states and the District of Columbia for the period of 2001 through 2010, for a total of 6,000 observations. Over the period 2001 through 2010, retail gasoline prices are highly correlated across states over time. Specifically, to illustrate, we ran a simple regression model of retail gasoline prices on year-month (fixed- effect) controls. The results show that over 90 percent of the variation in retail gasoline prices over time across states is explained by these simple year-month controls. This suggests nationwide factors explain much of the variation in retail gasoline prices across states over time. The available data are not sufficiently rich to allow us to reliably disentangle the separate effects on retail gasoline prices of various nationwide factors, such as, perhaps, changes in crude oil prices, demand for gasoline, and the roll-out of the RFS. Hence, below, we examine instead the (incremental) effect on state-level retail gasoline prices of state ethanol mandates that are effective at a time when the RFS was requiring relatively low levels of ethanol blending nationwide. Our dependent variable in the model was the monthly average after-tax retail price in dollars per gallon of regular-grade gasoline. Our model included a variety of explanatory variables, including state ethanol mandates, other state and local ethanol policies and fuel specifications, and the Petroleum Administration for Defense District (PADD)-level gasoline inventory-sales ratios and refinery capacity utilization rates. State ethanol mandates. The variables of interest in the model were indicators for state ethanol mandates; the state ethanol mandate indicator variables take the value of one for any month in which that state has an effective ethanol mandate and take a value of zero otherwise. The mandates ranged in the percentage of ethanol they required to be blended into gasoline, from approximately 10 percent in Minnesota, Missouri, and Oregon to 2 percent in Washington, with Hawaii having a unique requirement that 85 percent of fuel sold in the state must contain 10 percent ethanol. Other state ethanol policies. We used as controls indicators for several other state ethanol policies to shed light on how these policies may have affected retail gasoline prices. Specifically, we controlled for state fleet requirements to use ethanol; direct ethanol incentives that reduce the cost of ethanol per gallon of fuel, such as tax credits or rebates; ethanol production incentives; and ethanol consumption incentives. Production incentives included financial incentives to produce ethanol, such as grants or payments to build or operate an ethanol plant or to grow ethanol feedstock. Consumption incentives included financial incentives to sell or use ethanol, such as grants or tax incentives to upgrade fueling infrastructure to sell ethanol or a tax credit to stations selling ethanol. We also controlled for state methyl tertiary butyl ether (MTBE) bans, as ethanol was the primary substitute that could be used in place of MTBE. Local-level fuel specification requirements. We controlled for local- level fuel specification requirements, such as the gasoline type, RVP levels, and oxygenated fuel requirements. Volume of inventory of gasoline relative to the volume of sales of gasoline. We used as a control the ratio of finished motor gasoline stocks to the sales of motor gasoline. This variable indicates when supply is high relative to demand and vice versa. Refinery capacity utilization rate. We controlled for refinery operable utilization rate, which represents the utilization of crude oil distillation units. This variable represents the balance between supply volume and costs of production. Both this variable and the inventory- sales ratio have been found to be endogenous in past work. State gas taxes. We control for the level of state gas taxes using data from the Department of Transportation’s Federal Highway Administration. Fixed effects. We used a set of indicator variables to account for fixed effects associated with time and individual states. Specifically, we used a set of state fixed effects to account for persistent differences between states, such as transportation costs of fuels to that state. Each model also included year-month fixed effects—one for each month in the data—to control for nationwide events, as well as state-calendar month fixed effects to allow seasonality to vary by state. Our model can be written as follows: 𝑦𝑦𝑠𝑠𝑠𝑠𝑠𝑠= 𝛽𝛽0 𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑦𝑦 𝑒𝑒𝑒𝑒𝑒𝑒𝑒𝑒𝑒𝑒𝑒𝑒 +(𝑆𝑆𝑆𝑆𝑅𝑅𝑆𝑆𝐸𝐸𝑠𝑠×𝑒𝑒𝑅𝑅ℎ𝑎𝑎𝑎𝑎𝑒𝑒𝑎𝑎𝑎𝑎𝑎𝑎𝑅𝑅𝑎𝑎𝑎𝑎𝑅𝑅𝑒𝑒𝑠𝑠𝑠𝑠𝑠𝑠)′𝛽𝛽1 ′ 𝛽𝛽3+𝛼𝛼𝑠𝑠𝑠𝑠+ 𝛾𝛾𝑠𝑠𝑠𝑠 𝑦𝑦𝑠𝑠𝑠𝑠𝑠𝑠 is the dependent variable in our model; namely, the average after-tax price per gallon of regular grade gasoline at state 𝑒𝑒 in month 𝑎𝑎 and year 𝑅𝑅. 𝑆𝑆𝑆𝑆𝑅𝑅𝑆𝑆𝐸𝐸𝑠𝑠×𝑒𝑒𝑅𝑅ℎ𝑎𝑎𝑎𝑎𝑒𝑒𝑎𝑎𝑎𝑎𝑎𝑎𝑎𝑎𝑎𝑎𝑎𝑎𝑅𝑅𝑒𝑒𝑠𝑠𝑠𝑠𝑠𝑠 is a vector of interaction terms, where 𝑆𝑆𝑆𝑆𝑅𝑅𝑆𝑆𝐸𝐸𝑠𝑠 is a vector of dummies for each state with a mandate—Hawaii, Minnesota, Missouri, Oregon, or Washington—and 𝑒𝑒𝑅𝑅ℎ𝑎𝑎𝑎𝑎𝑒𝑒𝑎𝑎𝑎𝑎𝑎𝑎𝑎𝑎𝑎𝑎𝑎𝑎𝑅𝑅𝑒𝑒𝑠𝑠𝑠𝑠𝑠𝑠 an indicator that is equal to 1 for all months that an ethanol mandate is effective for that state, and zero otherwise. 𝐹𝐹𝑅𝑅𝑅𝑅𝑅𝑅𝑠𝑠𝑠𝑠×𝐹𝐹𝐹𝐹𝐸𝐸𝐹𝐹𝑅𝑅𝐸𝐸𝐹𝐹𝑆𝑆𝑠𝑠𝑠𝑠𝑠𝑠 is a vector of interaction terms where 𝐹𝐹𝑅𝑅𝑅𝑅𝑅𝑅𝑠𝑠𝑠𝑠 is a measure of the proportion of gas stations in a state likely affected by various fuel regulations in a given year, and 𝐹𝐹𝐹𝐹𝐸𝐸𝐹𝐹𝑅𝑅𝐸𝐸𝐹𝐹𝑆𝑆𝑠𝑠𝑠𝑠𝑠𝑠 is a 𝑋𝑋𝑠𝑠𝑠𝑠𝑠𝑠 is a vector of remaining control variables, including state 𝛼𝛼𝑠𝑠𝑠𝑠 is a set of state-calendar month fixed effects to account for 𝛾𝛾𝑠𝑠𝑠𝑠 is a set of month-year fixed effects to account for time-varying vector of indicator variables equal to one in those months that a state is subject to fuel regulations related to RVP levels, boutique fuels, reformulated gasoline, and oxygenated fuel. gasoline tax in cents per gallon, inventory sales-ratio, refinery utilization rate, and indicator variables for other state ethanol policies, including effective MTBE bans, fleet requirements, direct incentives, production incentives, and consumption incentives. permanent differences in a state’s average gasoline prices across months. factors affecting average gasoline prices for all states, such as fluctuations in crude oil prices. 𝜀𝜀𝑠𝑠𝑠𝑠𝑠𝑠 is an error term that is clustered by state. Our model assumes that after controlling for time-variant factors, the timing of state ethanol mandates going into effect is not correlated with unobserved time-variant factors that affect gasoline prices. When this assumption is satisfied, then our model may estimate the effect of state mandates on gasoline prices. Since ethanol mandates go into effect at different times—in 2003 (Minnesota), 2006 (Hawaii), and 2008 (Missouri, Oregon, Washington)—our quasi-experiment introduces variation in ethanol mandates across time and across states. We are able to address many concerns about omitted variable bias by including detailed state- calendar month fixed effects and month-year fixed effects. We estimate that all else remaining equal, when the ethanol mandates in the Midwestern states of Minnesota and Missouri were in effect, retail gasoline prices in those states were lower by approximately 8 and 5 cents, respectively, than they would have been without the mandates. We also estimate that all else remaining equal, when the ethanol mandates in Hawaii, Oregon, and Washington were in effect, retail gasoline prices in those states were higher by approximately 8, 2, and 6, cents, respectively, than they would have been without the mandates. The variables used in the model to control for effects other than ethanol mandates had the expected directional effect on price or else were not significant (using a 5 percent significance level). Our controls for the boutique fuel blends and the state gasoline taxes were significant and positive, suggesting that states with more stringent fuel specifications and higher gasoline taxes have a higher after-tax gasoline price. The estimated effect for refinery utilization rate is negative and statistically significant, suggesting that fuel prices decrease with refinery utilization rates because higher supply decreases prices. Although we might expect that fuel prices would decrease with the inventory/sales ratio because this indicates that supply is high relative to demand, it is also possible that when inventories are below a critical threshold, prices will rise regardless of how high inventories are relative to sales, as has been seen in prior work, so the positive coefficient in our model has precedent. See Kendix and Walls, “Oil industry consolidation and refined product prices: Evidence from US wholesale gasoline terminals” Energy Policy, vol. 38 (2010), pp. 3498-3507. Estimated coefficient -0.0071 (0.011) -0.0027 (0.015) -0.0034 (0.012) 0.0072 (0.015) (0.0085) Percentage of gasoline stations in the state selling fuel with less than 9 lbs. Reid vapor pressure (RVP) 0.070 (0.11) Percentage of gasoline stations in the state selling fuel with at least 9 lbs. RVP (0.040) Percentage of gasoline stations in the state selling boutique fuel 0.14*** (0.037) Percentage of gasoline stations in the state selling reformulated gasoline (0.45) Percentage of gasoline stations in the state selling oxygenated fuel 0.0029 (0.018) 0.0028 (0.092) (0.00050) 1.87*** (0.11) Legend: * = parameter estimate significance less than 10 percent; ** = parameter estimate significance less than 5 percent; *** = parameter estimate significance less than 1 percent. We tested alternate specifications, such as the following: Including different subsets of the explanatory control variables in the model. Treating the inventory/sales ratio and the refinery utilization rate as endogenous. Using pre-tax prices by subtracting state gasoline taxes from after-tax prices rather than including taxes as a control variable. Our results, including the magnitude and directional impact of the various state ethanol mandates, were not meaningfully affected across such specification tests. Our analysis had a number of limitations as listed below. We did not directly estimate the effect of the RFS on prices. The policy was nationwide and there are no reliable state-level data with which to measure state-level ethanol gasoline blend rates as the RFS was implemented over time. However, there is no reason to believe that other states that incrementally adopted the blending of ethanol as a result of increasing RFS targets would have experienced different effects. There may be some endogeneity in the timing of the adoption of the ethanol mandates. These policies are likely easier to pass through state legislatures when corn or ethanol prices are lower than oil or gasoline prices or when gasoline prices are high, but given that the effective dates are usually several years after the laws are enacted, this actual effective timing should be exogenous. We believe the state-level ethanol regulation data are comprehensive, but some regulations may not appear in the data. In our analysis, we include controls for ethanol mandates as well as several other types of ethanol incentives and fuel specification requirements. These variables control for the effects of related ethanol policies as well as variations in the cost of producing retail gasoline. We are certain that all state ethanol mandates were included in the model. However, our model may not perfectly control for all other regulations that could affect retail gasoline prices. Some control variables were not available at the state or monthly level. For example, some controls, such as the refinery capacity utilization rate, were available at the regional level only, so we had to parse out the regionally aggregated observations accordingly. As in any model, there is the possibility of misspecification or bias. Inappropriate assumptions about the functional form of the model, failure to deal with endogenous variables, or exclusion of relevant variables could also cause our estimated effects to deviate from the true effects. Some amount of this bias is present in almost all regression results, although the amount may not be very large. In addition to the contact named above, Karla Springer (Assistant Director), Stuart Ryba (Analyst in Charge), Luqman Abdullah, Benjamin Adrian, Jaci Evans, Ellen Fried, William Gerard, Cindy Gilbert, Anne Hobson, Jordan Kudrna, Joe Maher, Caroline Prado, Oliver Richard, Rachel Rhodes, Dan Royer, Barbara Timmerman, and William D. Walls made key contributions to this report.
Congress established the RFS in 2005 and expanded it 2 years later. The RFS generally mandates that transportation fuels—typically gasoline and diesel—sold in the United States contain increasing amounts of biofuels. In addition, the RFS is designed to reduce greenhouse gas emissions by replacing petroleum-based fuels with biofuels expected to have lower associated greenhouse gas emissions. The most common biofuel currently produced in the United States is corn-starch ethanol, distilled from the sugars in corn. EPA uses RINs associated with biofuels blended with petroleum-based fuels to regulate compliance with the program. In 2014, GAO found that refiners' costs for complying with the RFS had increased, and in 2016, GAO found that greenhouse gas emissions are unlikely to be reduced to the extent anticipated because production of advanced biofuels—which reduce greenhouse gas emissions more than corn-starch ethanol—has not kept pace with the yearly increases or the target of 21 billion gallons by 2022 called for by the statute. GAO was asked to review additional issues related to the effects of the RFS. This report examines what is known about (1) the effect the RFS has had to date on retail gasoline prices in the United States and (2) the RFS's effect on greenhouse gas emissions and whether the RFS will meet its goals for reducing those emissions. The report also provides information about RINs. To address the likely effects of the RFS on gasoline prices, GAO reviewed studies and interviewed experts and industry stakeholders, and conducted a statistical analysis of state ethanol mandates that were similar to the mandates of the RFS. GAO selected the experts based on their published work and recognition in the professional community. GAO selected stakeholders representing a range of perspectives, including stakeholders from the renewable fuels, petroleum, and agricultural industries, as well as from environmental groups. Because the RFS was implemented on a nationwide basis at the same time that other factors, such as the global price of crude oil and domestic demand for retail gasoline, were affecting retail gasoline prices across the nation, it is not possible to directly isolate and measure the effect the RFS had on gasoline prices nationwide given data available to GAO. Instead GAO developed and extensively tested an econometric model that estimated the effects on retail gasoline prices of state ethanol mandates. These state mandates are similar to the RFS but were put in place voluntarily by states before the RFS led to widespread ethanol blending in every state. This model estimated how ethanol mandates affected gasoline prices in these five states. These estimates suggest the RFS likely had effects in states that did not have state-wide mandates. These states incrementally blended ethanol because of the increasing volumes of ethanol required to be blended nationally by the RFS. Regarding the RFS's effect on greenhouse gas emissions, GAO interviewed 13 experts in government and academia. GAO selected these experts based on their published work, prior GAO work, and recommendations from other experts. During the course of the work, GAO gathered information on the topic of RINs through interviews, a review of relevant literature, and prior GAO work. GAO makes no recommendations in this report. In commenting on a draft of this report, USDA disagreed with GAO's finding that the RFS has had a limited effect on greenhouse gas emissions, citing research on the effects of ethanol on reducing emissions generally. GAO reported on the specific effects of the RFS on emissions. USDA also criticized GAO's methodology using experts' views. GAO employed that method to reach consensus among those with a range of perspectives. DOE and EPA did not comment on the draft report. Effect on prices. Evidence from studies, interviews with experts, and GAO's analysis suggest that the nationwide Renewable Fuel Standard (RFS) was likely associated with modest gasoline price increases outside of the Midwest and that these price increases may have diminished over time. Variations in these gasoline price effects likely depended, in part, on state-by-state variation in the costs to transport and store ethanol. For example, the Midwest was already producing and blending ethanol when the RFS came into effect, so that region had lower transportation costs and had already invested in necessary storage infrastructure. Other regions began blending ethanol later to meet the RFS's requirements, thereby incurring new transportation and storage infrastructure costs that resulted in gasoline prices that were several cents per gallon higher than they otherwise would have been. In addition, experts told GAO that the RFS caused an initial increase in refining investment costs that, over the long term, reduced refining costs for gasoline. Specifically, once all locations had made the infrastructure investments and most gasoline blendstock produced was consistent with blending ethanol then there would be two continuing effects: (1) the transportation and blending costs of ethanol, which would tend to push retail prices higher and depend on the distance traveled and the modes of transport, and (2) the lower cost of producing lower octane blendstock. The former effect might dominate for locations far from the production source of ethanol and for which more costly modes of transport were used, while the lower blendstock costs might dominate for locations close to the production source of ethanol and/or those that have low transportation costs. GAO's analysis of the effect that state ethanol mandates had on gasoline prices also showed gasoline price effects that differed in the Midwest and elsewhere. Specifically, during the period GAO studied, when the ethanol mandates in Minnesota and Missouri were in effect, all else remaining equal, retail gasoline prices were lower by about 8 and 5 cents per gallon in these states, respectively, than they would have been without the mandates. In contrast, when the ethanol mandates in Hawaii, Oregon, and Washington were in effect, GAO's model showed that retail gasoline prices were higher by about 8, 2, and 6 cents per gallon, respectively, than they would have been without the ethanol mandates. These results suggest that the RFS likely had gasoline price effects in other states that did not have state-wide ethanol mandates but that incrementally began blending ethanol as a result of increasing RFS requirements that by around 2010 had led to almost all gasoline sold in the United States being blended with 10 percent ethanol. Effect on greenhouse gas emissions. Most of the experts GAO interviewed generally agreed that, to date, the RFS has likely had a limited effect, if any, on greenhouse gas emissions. According to the experts and GAO's prior work, the effect has likely been limited for reasons including: (1) the reliance of the RFS to date on conventional corn-starch ethanol, which has a smaller potential to reduce greenhouse gas emissions compared with advanced biofuels, and (2) that most corn-starch ethanol has been produced in plants exempt from emissions reduction requirements, likely limiting reductions early on when plants were less efficient than they are today. Further, the RFS is unlikely to meet the greenhouse gas emissions reduction goals envisioned for the program through 2022. Specifically, GAO reported in November 2016 that advanced biofuels, which achieve greater greenhouse gas reductions than conventional corn-starch ethanol, have been uneconomical to produce at the volumes required by the RFS statute so the Environmental Protection Agency (EPA) has waived most of these requirements (see figure). Renewable identification numbers. EPA uses renewable identification numbers (RINs) to regulate industry compliance with RFS requirements for blending biofuels into the nation's transportation fuel supply. In GAO's March 2014 report on petroleum refining, GAO noted that the RFS had increased compliance costs for the domestic petroleum refining industry or individual refiners. GAO reported that corn-based ethanol RIN prices had been low—from 1 to 5 cents per gallon from 2006 through much of 2012—but in 2013, RIN prices increased to over $1.40 per gallon in July before declining to about 20 cents per gallon as of mid-November 2013. Since the March 2014 report, corn-ethanol RIN prices have experienced more periods of volatility. Most experts and stakeholders GAO interviewed recently stated that RINs had either a small effect on prices or no effect on prices, though a few disagreed. Finally, GAO's past work, as well as EPA analysis, has identified several issues of concern with RINs, including possible fraud in the market and concerns about the effect on small refiners, price volatility, and the point of obligation.