EO12866_RFS standards 2060

- AQ76 FRM FRN_20120 62 8.docx

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ENVIRONMENTAL PROTECTION AGENCY

40 CFR Part 80

[EPA

- HQ

- OAR

- 2010

- 0133; FRL

- 9678

- 7]

RIN 2060

- AR55

Regulation of Fuels and Fuel Additives: 2013 Biomass

- Based Diesel Renewable Fuel

Volume

AGENCY: Environmental Protection Agency (EPA).

ACTION: Final rule.

SUMMARY: Under the Clean Air Act Section 211(o), the Environmental Protection Agency is required to determine the applicable volume of biomass

- based diesel to be used in setting annual percentage standards under the renewable fuel standard program f or years after 2012. We proposed an applicable volume requirement for 2013 of 1.28 billion gallons on July 1, 2011. In order to sufficiently evaluate the many comments on the proposal from stakeholders as well as to gather additional information to enha nce our analysis, we did not finalize this volume requirement in the January 9, 2012, rulemaking setting the 2012 percentage standards. In this action we are finalizing an applicable volume of 1.28 billion gallons of biomass

- based diesel for calendar year 2013.

DATES: This final rule is effective on [ insert date of publication in the Federal Register ].

ADDRESSES: EPA has established a docket for this action under Docket ID No. EPA

- HQ

OAR

- 2010

- 0133. All documents in the docket are listed in the www.regul ations.gov index. Although listed in the index, some information is not publicly available, e.g., CBI or other information whose disclosure is restricted by statute. Certain other material, such as copyrighted material, will be publicly available only in hard copy. Publicly available docket materials are available either electronically in www.regulations.gov or in hard copy at the Air and Radiation Docket and Information Center, EPA/DC, EPA West, Room 3334, 1301 Constitution Ave., NW, Washington, DC. Th e Public Reading Room is open from 8:30 a.m. to 4:30 p.m., Monday through Friday, excluding legal holidays. The telephone number for the Public Reading Room is (202) 566

- 1744, and the telephone number for the Air Docket is (202) 566

- 1742.

FOR FURTHER INF ORMATION CONTACT: Julia MacAllister , Office of Transportation and Air Quality, Assessment and Standards Division, Environmental Protection Agency, 2000 Traverwood Drive, Ann Arbor MI 48105 ; Telephone number: 734

- 214

- 4131 ; Fax number: 734

- 214

- 4816 ; E

- mail a ddress: macallister.julia@epa.gov, or the public information line for the Office of Transportation and Air Quality; telephone number (734) 214

- 4333; E

- mail address OTAQ@epa.gov.

SUPPLEMENTARY INFORMATION:*** E.O. 12866 Review

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I. General Information

A. Does this Action Apply to Me?

Entities potentially affected by this proposed rule are those involved with the production, distribution, and sale of transportation fuels, including gasoline and diesel fuel or renewable fuels such as ethanol and biodiesel. Potentially reg ulated categories include:

Category NAICS 1

Codes SIC 2

Codes Examples of Potentially Regulated Entities

Industry Industry Industry Industry Industry Industry

Industry 324110

325193

325199

424690

424710

424720

454319 2911

2869

2869

5169

5171

5172

5989 Petroleum Refineries Ethyl alcohol manufacturing Other basic organic chemical manufacturing Chemical and allied products merchant wholesalers

Petroleum bulk stations and terminals Petroleum and petroleum products merchant

wholesalers

Other fuel dealers

1 North American Industry Classification System (NAICS)

2 Standard Industrial Classification (SIC) system code.

This table is not intended to be exhaustive, but rather provides a guide for readers regarding entities likely to be regulated by this final action. This table lists the types of entities that EPA is now aware could potentially be regulated by this final action. Other types of entities not listed in the table could also be regulated. To determine whether your activities will be regula ted by this final action, you should carefully examine the applicability criteria in 40 CFR part 80. If you have any questions regarding the applicability of this final action to a particular entity, consult the person listed in the preceding section.

Outline of this preamble

I. Executive Summary

................................ ................................ ................................ ................ 5

A. Purpose of This Action

................................ ................................ ................................ ....... 5

B. Summary of Today's Action

................................ ................................ ............................... 5

C. Impacts of This Action

................................ ................................ ................................ ........ 6

II. Statutory Requirements

................................ ................................ ................................ ........... 7

III. Factors Affecting Supply and Consumption

................................ ................................ ......... 10

A. Demand for Biomass

- Based Diesel

................................ ................................ .................. 11

B. Availability of Feedstocks to Produce 1.28 Billion Gallons of Biodiesel

........................ 14

1. Grease and Rendered Fats

................................ ................................ ............................. 14

2. Corn Oil

................................ ................................ ................................ ........................ 16

3. Soybean Oil

................................ ................................ ................................ ................... 16

4. Effects on Food Prices

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5. Other Bio

- oils

................................ ................................ ................................ ................ 19

C. Production Capacity

................................ ................................ ................................ .......... 19

D. Consumption Capacity

................................ ................................ ................................ ...... 20

E. Biomass

- Based Diesel Distribution Infrastructure

................................ ........................... 23

A. Consideration of Statutory Factors

................................ ................................ ................... 31

1. Climate Change

................................ ................................ ................................ ............. 31

2. Energy Security

................................ ................................ ................................ ............. 35

3. Agricultural Commodities and Food Prices

................................ ................................ .. 38

4. Air Quality

................................ ................................ ................................ .................... 40

5. Deliverability and Transport Costs of Materials, Goods, and Products Other Than

Renewable Fuel

................................ ................................ ................................ ..................... 42

6. Wetlands, Ecosystems, and Wildlife Habitats

................................ .............................. 43

7. Water Quality and Quantity

................................ ................................ .......................... 44

a. Impacts on Water Quality and Water Quantity Associated with Soybean Production

45

b. Impacts on Water Quality and Water Quantity Associated with Biodiesel Production

47

8. Job Crea tion and Rural Economic Development

................................ .......................... 48

B. Consideration of Applicable Statutory Economic Factors

................................ ................ 51

1. Monetized Quantifiable Costs

................................ ................................ ....................... 52

a. Impact on the Cost of Soybean Oil

................................ ................................ ........... 52

b. Cost of Displacing Petroleum

- Based Diesel with Soybean

- Based Biodiesel

........... 53

c. Transportation Fuel Costs

................................ ................................ ......................... 55

2. Monetized Quantifiable Benefits

................................ ................................ .................. 57

a. Energy Security

................................ ................................ ................................ ......... 57

b. Air Quality

................................ ................................ ................................ ................ 57

c. Greenhouse Gas Impacts

................................ ................................ ........................... 61

3. Quantifiable Benefits and Costs Compared

................................ ................................ .. 61

a. Combined Quantifiable Costs and Benefits for Bio diesel Produced in 2022

........... 62

b. Combined Quantifiable Costs and Benefits for Biodiesel Produced in 2013

........... 62

V. Final 2013 Volume for Biomass

- Based Diesel

................................ ................................ ..... 63

VI. Public Participation

................................ ................................ ................................ ........... 65

VII. Statutory and Executive Order Reviews

................................ ................................ ........... 66

A. Executive Order 12866: Regulatory Planning and Review and Executive Order 13563: Improving Regulation and Regulatory Review

................................ ................................ ........ 66

B. Paperwork Reduction Act

................................ ................................ ................................ . 66

C. Regulatory Flexibility Act

................................ ................................ ................................ 67

D. Unfunded Mandates Reform Act

................................ ................................ ...................... 67

E. Executive Order 13132: Federalism

................................ ................................ ................. 68

F. Executive Order 13175: Consultation and Coordination with Indian Tribal Governments

68

G. Executive Order 13045: Protection of Children from Environmental Health Risks and Safety Risks

................................ ................................ ................................ .............................. 68

H. Executive Order 13211: Actions Concerning Regulations That Significantly Affect Energy Supply, Distribution, or Use

................................ ................................ ......................... 68*** E.O. 12866 Review

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I. National Technology Transfer Advancement Act

................................ ............................ 69

J. Executive Order 12898: Federal Actions to Address Environmental Justice in Minority Populations and Low

- Income Populations

................................ ................................ ............... 6 9

K. Congressional Review Act

................................ ................................ ................................ 69

VIII. Statutory Authority

................................ ................................ ................................ ........... 71*** E.O. 12866 Review

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I. Executive Summary

The Renewable Fuel Standard (RFS) program b egan in 2006 pursuant to the requirements in Clean Air Act (CAA) section 211(o) which were added through the Energy Policy Act of 2005 (EPAct). The statutory requirements for the RFS program were subsequently modified through the Energy Independence and S ecurity Act of 2007 (EISA), resulting in the promulgation of revised regulatory requirements on March 26, 2010 1 . The transition from the RFS1 requirements of EPAct to the RFS2 requirements of EISA generally occurred on July 1, 2010.

A. Purpose of This Action

While CAA section 211(o)(2)(B) specifies the volumes of biomass

- based diesel to be used in the RFS program through year 2012, it directs the EPA to establish the applicable

volume of biomass

- based diesel for years after 2012 no later than 14 months before the first year for which the applicable volume will apply. On July 1, 2011, we proposed that the applicable

volume of biomass

- based diesel for 2013 would be 1.28 bill gal. 2

In a final rulemaking published on January 9, 2012, we specified the 2012 standards for cellulosic biofuel, biomass

- based diesel, advanced biofuel, and total renewable fuel. Although we had intended to also finalize the applicable volume of biomass

- based diesel for 2013 in that rulemaking, we did not do so. In that f inal rule we explained that we were continuing to evaluate the many comments on the NPRM from stakeholders as well as fulfilling other analytical requirements. We indicated that we intended to gather additional information to enhance our analysis includin g consideration of costs and benefits. In today's notice we are finalizing the applicable volume of biomass

- based diesel for 2013. We believe that the volume we are finalizing today is not only feasible and consistent with the overall analytic approach t o the RFS2 program but also consistent with the overall intent of the act to expand the use of renewable fuels through the year 2022.

B. Summary of Today's Action

In today's action we are finalizing an applicable volume of 1.28 bill gallons for biomas s

based diesel for 2013. This is the volume that was projected for 2013 in the March 26, 2010, RFS2 final rulemaking, and we are requiring it in 2013 based on consideration of the factors specified in the statute.

Today's final rule does not specify the percentage standard for biomass

- based diesel in 2013, but only the applicable volume. The percentage standards for cellulosic biofuel, biomass

based diesel, advanced biofuel, and total renewable fuel that will be applicable in 2013 are being proposed in a separate Notice of Proposed Rulemaking, and we expect to issue a final rule establishing those standards by November 30, 2012.

1 75 FR 14670

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C. Impacts of This Action

The RFS program established by Congress is a long

- term program aimed at replacing

fossil fuels u sed in the transportation sector with low

- GHG renewable fuels over time. In the March 26, 2010 RFS2 final rule, EPA assessed the costs and benefits of this program as a whole when the program would be fully mature in 2022. We continue to believe is the a ppropriate approach to examining the costs and benefits of a long

- term program like the RFS2. However, we have estimated costs and benefits in 2013 where such estimates can reasonably be made and have provided trends and other information on likely impact s where quantification for just 2013 is not possible or would not reflect the continually progressive nature of the program.

We estimate that soybean prices could increase up to 3 cents per pound in 2013 if the 280 million gallon increment over the 2012 biodiesel standard is met solely with soybean oil. Again assuming the 280 billion gallon increase in required biomass

- based diesel is met through increased demand for soy oil, we estimate the cost of producing this increment in biomass

- based

diesel would range from $253 to $381 million in 2013. Illustrative of the changing impacts over the duration of the RFS program, the cost of this amount of soy

- based biodiesel in 2022 would

be between

- $195 million and $116 million. Adding the estimate of 2013 costs to the total 2013 fuel pool would suggest a diesel fuel cost increase of less than 1 cent per gallon. Of course, if less expensive feedstock is used, then the cost impacts would be smaller still

.

Quantified estimates of benefits include $ 45 million in energy security benefit s , $ 20

- 57 million in air quality dis benefit s and up to $ 120 million in GHG benefits. Other benefits include both direct and indirect employment benefits in rural areas due to increased biodiesel production. Impacts on water quality, water use, wetlands, ecosystems and wildlife habitats are expected to be likely directionally negative but modest due to both the small impact on crop acres planted necessary to supply sufficient soy oil feedstock and due to the relatively small impact on these measures of soybean production compared to other potential crops. Deleted: approximately 2 cents

Deleted: less

Deleted: 0.15 per gallon of biodiesel

Deleted: benefit, $15

Deleted: benefit

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II. Statutory Requirements

Section 211(o)(2)(B)(i) of the Clean Air Act specifies the applicable volumes of renewable fuel on which the annual percentage standards must be based, unless the applicable

volumes are waived or adjusted by EPA in accordance with specific authority and directives specified in the statute 3 . Applicable volumes are provided in the statute for years through 2022 for cellulosic biofuel, advanced biofuel, and total renewable fuel. For bi omass

- based diesel, applicable volumes are provided through 2012. For years after those specified in the statute (i.e.,

2013+ for biomass

- based diesel and 2023+ for all others), EPA is required under 211(o)(2)(B)(ii) to determine the applicable volume, in coordination with the Secretary of Energy and the Secretary of Agriculture, based on a review of the implementation of the program during calendar years for which the statute specifies the applicable volumes and an analysis of the following:

• The impact of the production and use of renewable fuels on the environment, including on air quality, climate change, conversion of wetlands, ecosystems, wildlife habitat, water quality, and water supply;

• The impact of renewable fuels on the energy security of th e United States;

• The expected annual rate of future commercial production of renewable fuels, including advanced biofuels in each category (cellulosic biofuel and biomass

- based diesel);

• The impact of renewable fuels on the infrastructure of the Unite d States, including deliverability of materials, goods, and products other than renewable fuel, and the sufficiency of infrastructure to deliver and use renewable fuel;

• The impact of the use of renewable fuels on the cost to consumers of transportation fuel and on the cost to transport goods; and

• The impact of the use of renewable fuels on other factors, including job creation, the price and supply of agricultural commodities, rural economic development, and food prices.

While EPA is given the author ity to determine the appropriate volume of renewable fuel for those years that are not specified in the statute based on a review of program implementation and analysis of the factors listed above, the statute also specifies that the applicable volume of

b iomass

- based diesel cannot be less than the applicable volume for calendar year 2012, which is 1.0 bill gallons.

As evidenced by the annual schedule of applicable volumes leading to 36 bill gallons by 2022, the statute is forward

- looking in its emphasi s on achieving environmental and energy goals. In assessing potential increases in the applicable volume requirement for biomass

- based diesel, then, we believe that many of the factors that we must consider under the statute are best analyzed for the long er term, while others are more appropriately analyzed for the near term.

3 For example, EPA may waive a given standard in whole or in part following the provisions at 211(o)(7).*** E.O. 12866 Review

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Those factors that we believe should be analyzed when the program has had time to evolve and mature include impacts on costs and benefits. Those factors that we believe should be an alyzed in the near term include production capacity, availability of feedstocks, and impacts on infrastructure. Thus for this NPRM, we have not simply looked at the impacts of the program in any one year with near term implementation, but have also looked at the evolving pattern of impacts through time.

It is useful to note that the statutory provisions described above are silent in two important areas. For instance, the statute does not provide numerical criteria or thresholds that

must be attained whe n EPA determines the applicable volume of biomass

- based diesel for years after 2012 (other than specifying a minimum volume of 1.0 bill gal), nor does it describe any overarching goals such as maximizing GHG benefits or energy security benefits, maximizing or minimizing supply of renewable fuel, or minimizing cost. Due to this ambiguity in the statute, commenters differed in their perspectives on the intent of Congress in allowing EPA to determine the appropriate applicable volume for biomass

- based diesel for years after 2012.

Some expressed the belief that Congress intended the required volumes of biomass

- based diesel to increase every year, with EPA's role being that of determining an achievable size of that increase. Others expressed their belief th at Congress intended for the statutory minimum volume of 1.0 bill gallons to be used to set the applicable volume for all years after 2012, with higher volumes being required only if EPA could demonstrate that those higher volumes were already being produc ed. Given that all biomass

- based diesel counts towards the advanced biofuel requirement, and that the statute requires annual increases in advanced biofuel through 2022, we believe that it is appropriate that biomass

- based diesel play an increasing role i n supplying advanced biofuels to the market between 2012 and 2022. However, the determination of whether to increase the volume requirement for biomass

- based diesel in any given year is subject

to a consideration of a number of factors in the statute as d escribed above.

We also note that the statute does not provide authority to raise the applicable volumes of advanced biofuel or total renewable fuel above those specified in the statute for years up to and including 2022. Thus, any increase in the biomass

- based diesel volume requirement above that specified for 2012 would not have any impact on the advanced biofuel or total renewable fuel volume requirements. While increasing the biomass

- based diesel volume requirement above the 1.0 bill gallons mi nimum value specified in the statute could result in a change in the makeup of biofuels used to meet the advanced biofuel and the total renewable fuel standards, doing so would not change the total required volumes of those fuels (in terms of ethanol

- equiv alent gallons).

We received one comment in response to the NPRM requesting that we prohibit increases

in biomass

- based diesel above 1.0 billion gallons in years after 2012. We disagree. As described in this preamble, we believe it is appropriate to req uire 1.28 bill gal of biomass

- based diesel in 2013, and that we should consider further increases in the future by evaluating the factors specified in the statute.

The statute also specifies the timeframe within which these volumes must be promulgated: the rules establishing the applicable volumes must be finalized no later than 14*** E.O. 12866 Review

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months before the first year for which such applicable volume will apply. For the biomass

- based diesel volume requirement applicable in 2013, the deadline for promulgation w as November 1, 2011. As described in the January 9, 2012, final rule that set the applicable percentage standards for 2012, we delayed issuing this final rule to allow additional time to evaluate the many

comments on the NPRM from stakeholders as well to fulfill other analytical requirements. To this end, we did in fact gather additional information to enhance our analysis of the factors required in the statute, and we considered costs and benefits. Our assessment is provided in

Sections III and IV. We do not believe that the delay in issuing this final rule will materially affect the regulated community, however, since we are setting the final volume requirement several months prior to the date when it will be applicable. This is still earlier than the final applicable 2013 standards that will be set for cellulosic biofuel, advanced biofuel, and total renewable fuel in November of this year.*** E.O. 12866 Review

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Page 10 of 71 III. Factors Affecting Supply and Consumption

As described i n Section II, we are required to review the implementation of the RFS program for years prior to 2013 and to use information from this review in determining the applicable volume of biomass

- based diesel for 2013. In the NPRM we indicated our belief that this review is of limited value due to the short history of the RFS program. Not only did the RFS1 program have no volume requirement specific to biomass

- based diesel, but even in 2010 under the RFS2 program several unique factors hindered biodiesel produ ction volumes from increasing substantially above historical levels. For instance, RFS1 RINs from both 2008 and 2009 could be carried over to 2010 and used to meet a combined 2009/2010 volume requirement

for biomass

- based diesel.

Since release of the NPRM, however, some information has become available on the implementation of the RFS program in 2011. The available data provide some indication as to

how the biomass

- based diesel standard for 2011 is affecting the market for biodiesel. Based on

informa tion provided through the EPA

- Moderated Transaction System (EMTS), reported biodiesel production increased significantly to about 1.07 bill gal in 2011. This is a significant increase over the 2010 production volume of about 400 mill gal and exceeds the a pplicable volume requirement of 800 mill gal for 2011. 2011 biomass

- based diesel RINs were available to meet the higher advanced biofuel volume requirement. Based on these results, we believe that the RFS program is driving production of biomass

- based di esel, and that higher applicable volume requirements in future years would likewise drive increases in production volumes.

In the NPRM we indicated that, based on the limited information available on the current and historical operation of the RFS pr ogram, it would be prudent for 2013 to consider only

moderate increases in biomass

- based diesel above the statutory minimum of 1.0 bill gallons. We

cited the annual increments in biomass

- based diesel volumes specified in the statute for years 2009 through 2012 and conveyed our belief that our proposed applicable volume of 1.28 bill gallons for 2013 was not a dramatic change from the trend in increments in the statute. In addition, since this biomass

- based diesel volume had already been partially evaluated in the RFS2 rule, we decided to evaluate the appropriateness of setting an applicable volume of 1.28 bill gallons for 2013 by considering whether 1.28 bill gal of biomass

- based diesel was reasonable given likely market demand, availability of feedstocks, production capacity, storage, distribution, and blending capacity, the capability of the existing diesel fleet to consume this volume of biodiesel, and the impacts of biomass

- based diesel in a variety of areas as required under the

statute.

In respondi ng to the NPRM, some commenters took issue with our characterization of the proposed volume of 1.28 bill gallons as a "moderate" increase consistent with the annual

increments in biomass

- based diesel volumes specified in the statute for years 2009 through 2012. These comments also suggested that any comparison to volume requirements in the statute is not appropriate. However, we did not base our proposed volume of 1.28 bill gallons on this comparison but referred to past statutory increments to put our pr oposal in context. Regardless of the size of these past statutory increments, however, we find the final 280 mill gal increment to be moderate and achievable, as described below, especially in light of the substantial increases in production volume that o ccurred in 2011 which were approximately twice the amount of the*** E.O. 12866 Review

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Page 11 of 71 280 mill gal increase we are adopting for 2013. Other commenters agreed with the comparison and agreed that the 0.28 bill gallons increment can appropriately be characterized as moderate.

In some cases commenters opposed the proposed volume requirement of 1.28 bill gallons, citing concerns that the 2012 applicable volume of 1.0 bill gallons is not achievable. As noted above, our evaluation indicates that biodiesel production exceeded 1.0 b illion gallons in 2011, confirming our projection that the 1.0 bill gallon applicable volume for 2012 is achievable. Therefore, concerns about the industry's ability to meet the applicable volume in 2012 are not a

reasonable basis for concerns about achie ving 1.28 bill gallons in 2013. Other commenters agreed with our assessment of 2012 and agreed that an increase of 0.28 bill gallons over the statutory minimum for 2013 is moderate given the capabilities of the industry.

Several commenters suggested t hat 1.28 bill gallons is an infeasible target for 2013 and requested that we set the biomass

- based diesel standard at the statutory minimum of 1.0 bill gallons. Commenters taking this view generally did not offer any data or information to support

their b elief that 1.28 bill gal is not achievable in 2013 beyond references to historical biodiesel production rates. As described in the NPRM, we believe that the use of biodiesel production data from 2010 and earlier is of limited value, and production capacit y as well as more recent data on actual production volumes does in fact demonstrate that the industry is capable of significant increases in production when demand for it exists. As described more fully in the sections below, we continue to believe that 1 .28 bill gallons is achievable based on production capacity, availability of feedstock, recent trends in production volumes, and efforts to update infrastructure for storage, transport, and blending. Our consideration of other impacts, such as

fuel costs and environmental impacts, can be found in Section IV.

A. Demand for Biomass

- Based Diesel

The demand for biomass

- based diesel in 2013 will be a function of not only the biomass

based diesel standard, but also the advanced biofuel standard, since the standards under the RFS2 program are nested. In addition to biomass

- based diesel, biofuels that are likely to be available for meeting the advanced biofuel standard would include cellulosic biofuel, imported sugarcane ethanol, and other domestically produ ced advanced biofuels. As described in the January 9, 2012 rulemaking establishing the 2012 standards 4 , cellulosic biofuels will be a very small fraction of the 2.0 bill gallon advanced biofuel requirement in 2012, and we expect the same to

be true in 201 3 with respect to the 2.75 bill gal advanced biofuel requirement. Regarding other domestically produced advanced biofuels, volumes reached about 60 mill gal in 2011, and we have projected in a separate Notice of Proposed Rulemaking for the applicable 2013 standards that they could reach 150 mill gal or more in 2013. As a result, most of the 2.75 bill gal advanced biofuel requirement will be met with biodiesel and imported sugarcane ethanol.

Recent market projections suggest that the volume of sugarcan e ethanol that can be imported into the U.S. from Brazil in 2013 could be on the order of historical import volumes

4 77 FR 1320*** E.O. 12866 Review

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Page 12 of 71 prior to 2010, with the potential to reach the historical maximum or more 5 . However, there is considerable variability in the projections f or 2013. For instance, one source that evaluates trends and issues for U.S. energy markets is the U.S. Energy Information Administration's (EIA) Annual Energy Outlook (AEO). 6 This report projects U.S. net ethanol imports in 2013 to be 306 million gallons . Another source for U.S. and world commodity projections is the Food and Agricultural Policy Research Institute's (FAPRI) U.S. and World Agricultural Outlook. The most current version of the FAPRI 2011 Agricultural Outlook projects for the year 2013 tha t the U.S. will have net ethanol imports of 768 million gallons. 7 As a result, while there is good reason to believe that there will be volumes of imported sugarcane ethanol in 2013 sufficient to meet the advanced biofuel standard, uncertainty in those vo lumes could create a demand for volumes of biodiesel in excess of 1.0 bill gallons.

If we do not set the biomass

- based diesel standard above 1.0 bill gallons, biodiesel producers will be less certain of the demand for their product given the opportuni ties that are also created by the advanced biofuel standard for imported sugarcane ethanol. Due to this uncertainty, the biodiesel industry is less likely to make preparations to increase production above 1.0 bill gallons. In the event that imported suga rcane ethanol volumes fall short of what is needed to meet the advanced biofuel volume requirement of 2.75 bill gal in 2013, the biodiesel industry would not be in an ideal position to make up the difference.

Thus in setting the biomass

- based diesel volume requirement at 1.28 bill gallons rather than at the statutory minimum of 1.0 bill gallons, we are creating greater certainty for both producers of biomass

- based diesel and obligated parties and increasing certainty that the

intended GHG emissions re ductions and energy security benefits associated with the use of advanced biofuels will be realized. It is possible that there may be some additional cost for compliance with the advanced biofuel requirement of 2.75 bill gallons under a biomass

- based

dies el requirement of 1.28 bill gallons, as compared to setting the biomass

- based diesel requirement at the statutory minimum of 1.0 bill gallons and allowing the market to determine the relative volumes of each type of advanced biofuel that will be produced i n 2013 to meet the advanced biofuel standard of 2.75 bill gallons. However, the potential for somewhat increased costs is appropriately balanced against the additional certainty of GHG reductions and enhanced energy security provided by the advanced biofu el volume requirement of 2.75 bill gallons. Therefore, after consideration of all the factors required under the statute, described in more detail below, we believe that the biomass

- based diesel standard of 1.28 bill gallons in 2013 is appropriate and in keeping with the goals of the statute.

Among the parties that submitted comments in response to the NPRM, none contested our assessment of the volumes of sugarcane ethanol that might be expected to be imported into

the U.S. from Brazil in 2013. Neverthe less, parties that were opposed to setting the biomass

based diesel applicable volume at 1.28 bill gallons in 2013 raised doubts about the projected

5 Historical maximum imports of ethanol were 730 mill gal in 2006. Total Brazillian exports of ethanol exceeded 900 mill gal annual for 2006

- 2009.

6 U.S. Energy Information Administration (EIA). “AEO2011 , Table 11” April 2011. http://www.eia.doe.gov/fo recasts/aeo/index.cfm

7 Table "Ethanol Trade", Commodity Outlook/Biofuels, FAPRI

- ISU 2011 World Agricultural Outlook. http://www.fapri.iastate.edu/outlook/2011/ Deleted: ,”*** E.O. 12866 Review

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Page 13 of 71 demand for biomass

- based diesel in 2013. In some cases commenters ignored the fact that much

of the advanc ed biofuel standard can be met with biodiesel or implicitly assumed that EPA would waive some portion of the advanced biofuel requirement. The American Trucking Association (ATA) explicitly requested that we lower the 2013 advanced biofuel standard in

ord er to ensure that demand for biomass

- based diesel would not exceed 1.0 bill gallons in 2013. As described in a separate Notice of Proposed Rulemaking 8 , we are proposing to not reduce the 2013 advanced biofuel requirement of 2.75 bill gal.

The American P etroleum Institute cited projections from AEO 2011 in support of their argument that biodiesel volumes will not reach 1.28 bill gallons in 2013. For instance, Table 11 of AEO 2011 projects a total biodiesel consumption of 1.04 bill gal in 2013. However, we do not believe that the projections provided in AEO 2011 can be used in this way, since EIA assumes that the required volume of advanced biofuel in any given year will be reduced concurrently with reductions in the required volume of cellulosic biofuel 9 . As a result, the total projected volume of biodiesel and imported ethanol in the 2013 EIA projections falls far short of what would be necessary to meet the applicable volume of 2.75 bill gal of advanced biofuel set

forth in the statute.

Some parti es that were opposed to setting the biomass

- based diesel applicable volume at 1.28 bill gallons in 2013 did recognize that the advanced biofuel requirement of 2.75 bill gal could place pressure on the industry to produce volumes of biodiesel in excess of 1 .0 bill gal but questioned the need to set the biomass

- based diesel standard above the statutory minimum of 1.0 bill gallons. They argued that the market should be allowed to determine the relative

volumes of biomass

- based diesel, imported sugarcane etha nol, and other advanced biofuels needed to meet the advanced biofuel standard of 2.75 bill gallons. This approach, they argued, could potentially minimize the overall cost of compliance with the advanced biofuel standard in 2013. However, as described in the NPRM, the statute does not provide any overarching goals for EPA to achieve in setting the applicable volumes for biofuels in years after those specifically set forth in the statute. Thus, the statute does not indicate that EPA should maximize GHG

b enefits or energy security benefits, maximize or minimize supply of renewable fuel, or minimize cost. Instead, the statute provides a list of factors we must consider. While one of those factors is cost, other factors must also be considered as described in Section II. Additionally, setting the biomass

- based diesel standard at 1.28 bill gallons instead of at the statutory minimum of 1.0 bill gallons will provide more certainty that the applicable volume of

advanced biofuel set forth in the statute will n ot need to be reduced. This, in turn, means that there will be more certainty of reduced GHG emissions through the use of more advanced biofuels and increased certainty of energy security benefits in terms of reduced reliance on fossil

fuels. In addition , increasing the biomass

- based diesel volume requirement to 1.28 bill gal in 2013 serves the long term goal of the statute to increase volumes of renewable fuels over time such that in the longer term they are more likely to be available to offset the need for crude oil.

8 This NPRM will propose the applicable 2013 percentage standards for cellulosic biofuel, bioma ss

- based diesel, advanced biofuel, and total renewable fuel.

9 Communication with W. Brown, Energy Information Administration*** E.O. 12866 Review

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Page 14 of 71 B. Availability of Feedstocks to Produce 1.28 Billion Gallons of Biodiesel

In the NPRM, we provided our assessment of the types and amounts of feedstock that could be used to produce 1.28 bill gallons of biomass

- based diesel in 2013. This assessment

included references both to the work that had been done in the RFS2 final rule as well as a recent report released by IHS Global Insight 10 . The feedstock estimates from these two sources are

shown in Table IV.B

- 1.

Table III.B

- 1

Feedstock S ources (in mill gallons) That May Contribute to 2013 Volume of 1.28 bill gal

Source RFS2 Final Rule IHS Global Insight

Grease and rendered fats 380 272

Corn oil 300 185 Soybean oil 600 624

Canola oil 0 68

Palm oil 0 7

Other 0 185

Total 1,280 1,340

As some comments pointed out, these two sources used fundamentally different approaches. In the case of the RFS2 final rule, projections of feedstock volumes were determined first, and then summed to conclude that 1.28 bill gal is a reasonable volume of

biomass

- based diesel that could be achieved in 2013. In contrast, the IHS Global Insight report began with the aim of reaching 1.3 bill gallons in 2013, and then conducted modeling to determine the likely mix of feedstock sources that would support that v olume. Nevertheless, we believe that these sources suggest two similar ways that the market could meet the demand for feedstock under a required volume of 1.28 bill gallons of biomass

- based diesel. The actual mix of feedstock sources used to produce 1.28 bill gallons of biomass

- based diesel could also differ substantially from the values shown in Table III.B

- 1 as the market adjusts to the new mandate.

One commenter stated that we relied too heavily on these sources without additional analysis. We did in fact conduct a more up

- to

- date analysis of these feedstock sources and, as described below, the updated analysis confirms our belief that the projections in Table III.B

- 1 are reasonable projections for the mix of feedstock sources that could be used to reach 1.28 bill gallons of biomass

- based diesel. Other comments agreed with our assessment of available

feedstock and our conclusions that there would be sufficient volumes to meet a biomass

- based diesel volume requirement of 1.28 bill gallons. A summar y of our updated assessment of

feedstock sources is included below.

1. Grease and Rendered Fats

10 Table 2, "Biodiesel Production Prospects for the Next Decade," IHS Global Insight, March 11, 2011*** E.O. 12866 Review

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Page 15 of 71 According to the U.S. Census Bureau, the total volume of yellow grease and other greases (most likely trap grease) produced in 2010 was about 340 mill gallons 11 . In the first half of 2011, production of greases was about 10% higher than for the same period in 2010, suggesting that total 2011 production could reach 370 mill gallons or more, similar to the production rates in 2008 and 2009.

With regard to inedible tallow, the volume produced in 2010 was about 440 mill gallons, and indications from the first half of 2011 are that a similar volume will be generated in 2011 as

well.

Taken together, the total volume of grease and rendered fats produced an nually is over 800 mill gallons. This is significantly more than was estimated in the RFS final rule and the report from IHS Global Insight for use in the production of biomass

- based diesel in 2013. Moreover, we have not included in our estimate other po tential sources, such as edible tallow, lard, and poultry fats. While these other potential feedstocks currently having existing markets, it may become economical for them to be used in the production of biomass

- based diesel.

In their comments on the N PRM, the America Cleaning Institute raised concerns about the diversion of animal fats from the oleochemical industry for the production of biofuels. We do not have the authority to prevent feedstocks that meet the statutory definition of renewable

biomass from being used in the production of renewable fuel. The choice of which feedstocks will be used to produce biomass

- based diesel will be determined by the market. We also note that in responding to comments to the rule establishing the RFS2 program, we acknowledged that animal fat can be used in other markets such as the soap industry, but that the diversion of some portion of this feedstock to the biofuels industry was both not prohibited and would not significantly impact the GHG assessment of biofuel made from this feedstock 12 . However, based on our assessment, it is possible that the 1.28 bill gall requirement could be met without the use of animal fats. As noted above, the total volume of grease and rendered fats is estimated at 800 mill gallons, far above the volumes listed in Table III.B

- 1. It is therefore possible that the industry may produce biodiesel predominately from waste grease instead of animal fats. Moreover, the volumes of other feedstock sources, such as corn oil and vegetable oils as described more fully below, may exceed the volumes needed to produce 1.28 bill gal biodiesel, further reducing the need to rely on animal fats for biodiesel production. Finally, EPA has received inquiries from industry regarding the use of additional sour ces of waste oils often from the food processing industry as biodiesel feedstock, indicating the sources of feedstock are likely to continue expanding, improving the availability of alternatives to animal fat as a biofuel

feedstock.

Since the market will determine how much animal fats are used in the production of biofuels, we cannot project how their availability for the production of oleochemicals might be affected. We agree with the American Cleaning Institute that increases in the use of animal fats

11 Current Industrial Reports, U.S. Census Bureau, M311K

- Fats and Oils: Production, Consumption, and Stocks, Table 2b. Assumes 7.5 lb/gal. http://www.census.gov/manufacturing/cir/historical_data/m 311k/index.html The U.S. Census Bureau terminated collection of data for this report as of July 2011 so updated data is not available.

12 "Renewable Fuel Standard Program (RFS2) Summary and Analysis of Comments," February 2010, EPA

- 420

- R

003, pages 6

- 15 a nd 7

- 304. Docket number EPA

- HQ

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Page 16 of 71 to produce biofuel could increase the price of those animal fats and/or reduce their availability for the production of oleochemicals. Such circumstances could in turn compel the oleochemical industry to use a greater fraction of alternative feedstock sou rces such as cottonseed oil. Given that we are projecting that a mandate for 1.28 bill gal biomass

- based diesel would increase jobs in the biodiesel industry, we believe it is likely that on balance for all industries using animal fats as feedstocks, the total number of jobs will not decrease but will at least remain approximately

constant or could even increase.

2. Corn Oil

The RFS2 final rule projected that by 2013, 34% of all dry mill ethanol facilities in the

U.S. would extract inedible corn oil f rom the by

- products of ethanol production using advanced extraction technologies. This estimated extraction rate led us to conclude that the volume of corn oil could reach 300 mill gallons in 2013. While currently available technologies have not been

abl e to reach the oil extraction rates that we assumed in the RFS2 final rule, these lower extraction rates have been offset by a higher number of ethanol plants utilizing some form of extraction technology. For instance, according to a recent article in Eth anol Producer Magazine, up to 55 percent of plants may be extracting corn oil by the end of 2012. 13 Similarly, in an article in Biodiesel Magazine, Dave Elsenbast, vice president of supply chain management for REG stated that as of July 2011 about 35% of U.S. corn ethanol plants had implemented corn oil extraction and that he expected that number to do uble within the next couple of years 14 . In the NPRM we stated our expectation that the percentage of dry mill ethanol facilities using some form of corn oil extraction technology will increase to 60% by 2013. Given the information

from Ethanol Producer Ma gazine and Biodiesel Magazine, this estimate appears reasonable.

If 60% of all dry mill corn ethanol facilities in the U.S. were extracting inedible corn oil at rates capable with current technology, the amount of corn oil available for biodiesel prod uction would be approximately 270 million gallons. However, we expect that by 2013 technology improvements will increase corn oil production levels to the 300 million gallons projected in the RFS2 rule. Additional corn oil could come from ethanol product ion facilities using corn fractionation or wet milling technology. This corn oil was not considered as a biodiesel feedstock in the RFS2 rule, but market conditions may result in its availability to the biodiesel industry. The higher adoption rate of cor n oil extraction in comparison to our projections from the RFS final rule, and the promise of ever

- increasing oil extraction yields, indicate that the 300 million gallons of corn oil extraction projected in the RFS2 rule in 2013 remains a reasonable projec tion. Comments from the Renewable Energy Group support this

view.

3. Soybean Oil

While a number of parties commented on the use of soybean oil for the production of biomass

based diesel, none provided data or information suggesting that there would be insufficient

13 Joseph Riley, "Customized Coproducts Needed as Industry Matures," June 6, 2011. Ethanol Producer Magazine.

14 Dave Elsenbast quoted in Ron Kotrba, “Biodiesel from corn oil: a growing force,” July 6, 2011. B iodiesel Magazine.*** E.O. 12866 Review

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Page 17 of 71 supplies to meet the need for 1.28 bill gallons of biomass

- based diesel as well as other traditional markets for soybeans. Instead, comments on the use of soybean oil were focused on costs. We have addressed these comments separately in Sec tion III.B.3. The rest of this section summarizes our assessment of soybean oil availability, updated since the NPRM.

Since the RFS2, other oilseeds (e.g., canola oil) have emerged as potential sources of biodiesel feedstock. However, the U.S. market f or soybean oil biodiesel is significantly more mature than for biodiesel made from other oilseeds. Because of this, we anticipate that soybeans will remain the primary source of U.S. biodiesel from oilseeds in 2013. It is possible that biodiesel producti on from other oilseeds such as canola could achieve a significant level of production by 2013. If other oilseeds with approved pathways are able to contribute to the biodiesel volumes, achieving the biomass based diesel mandate would be facilitated. For t he purposes of this analysis, EPA is making the conservative assumption that there will be no biodiesel production from other oilseeds in 2013.

We examined historical and projected soybean oil supplies and use to verify that the

volumes shown in Table III .B

- 1 are achievable in 2013. Our analysis concludes that there will be sufficient supplies of soybean oil to meet the needs of both biodiesel production and other domestic uses in 2013. Producing 600 million gallons of soybean

- based biodiesel will requir e 4,530 million pounds of soybean oil.

Table III.B.3

- 1 below lists U.S. Department of Agriculture (USDA) historical data and current projections for U.S. supply and use of soybean oil from the 2006/2007 crop year to the 2013/2014 year. Since 2006/2007, domestic use of soybean oil for non

- biodiesel purposes has ranged from 14,134 million pounds to 15,813 million pounds. USDA projects non

- biodiesel use will stay above 14,000 million lbs through the 2013/2014 year.

Table III.B.3

- 1 Historical Supplies and Use of Soybean Oil in the U.S. (in million lbs)

Year Starts

October 1 Total

Supplies Domestic Use

for Non

Biodiesel Purposes Supplies

Available for

Biofuel

Feedstock Use or Export Historical

Exports Historical

Biofuel

Feedstock

Use

2006/07 23,536 15,813 7,723 1,877 2,762

2007/08 23,730 15,089 8,641 2,911 3,245

2008/09 21,319 14,196 7,123 2,193 2,069

2009/10 22,578 14,134 8,444 3,359 1,680

2010/11 22,452 14,244 8,208 3,233 2,550

2011/12 a 21,215 14,100 7,115 * *

2012/13 a 21,075 14,200 6,875 * *

2013/14 a 21,290 14,400 6,890 * *

a Projected volumes. Sources: USDA, Agricultural Marketing Service, Oil Crops Outlook , February 10 th , 2012. USDA, Economic Research Service, Agricultural Long

- Term Projections , February 2012.*** E.O. 12866 Review

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Page 18 of 71 USDA projects that 6,875 million pounds of soybean oil will be available for biofuel feedstock use or export in the 2012/2013 crop year and that 6,890 million pounds will be available in the 2013/2014 year (see Table III.B.3

- 1). This is considerably more than the 4,530 million po unds needed to meet the soybean

- based biodiesel portion of the 1.28 billion gallon mandate. For this reason, EPA does not anticipate any shortage in availability of soybean oil feedstock for biodiesel production.

4. Effects on Food Prices

In order to determine the likelihood of a substantial increase in food prices, EPA projected the effects of a 1.28 billion gallon mandate using the CARD stochastic modeling framework discussed in Section IV.B.1. of this final rule. Assuming that the 280 million gall on increment is met entirely with soybean oil biodiesel in 2013, we project that the price of soybean oil will be $0.45 per pound under this mandate, compared to $0.42 under a 1.0 bill gal volume requirement. This represents a price increase of 3 cents per pound (about 7 percent). The increase in demand for soybean oil is also expected to have a small impact on the price of soybeans. We project that the pr ice of soybeans will be $10.39 per bushel under this mandate, compared to $10.21 per bushel under a 1.0 bill gal volume requirement. This represents a price increase of 18 cents per bushel (about 1.8 percent). Both of these projections are within the

rec ent historical range of prices (see Table III.B.4

- 1)

.

Table III.B.4

- 1 Historical and Projected Prices of Soybeans and Soybean Oil

(2010 dollars per lb)

Soybean Oil Soybeans

2006

- 2011 Low Annual Average Price $0.33 per lb $9.70 per bushel

2006

- 2011 High Annual Average Price $0.54 per lb $12.36 per bushel 2013 Projected Price $0.45 per lb $10.39 per bushel 2022 Projected Price $0.42 per lb $9.36 per bushel

Sources: USDA, Agricultural Marketing Service, Oil Crops Outlook , February 10 th , 2012. USDA, Economic Research Service, Agricultural Long

- Term Projections , February 2012.

The timeframe of this rulemaking did not permit large

- scale modeling of the impacts of

this mandate on the agricultural sector. We therefore cannot pred ict the exact impact that these increases in soybean and soybean oil prices will have on food prices in general. However, given that projected prices for soybeans and soybean oil fall within the range of recent historical prices,

we do not expect the 1.28 bill gal mandate to cause any significant variations in food prices

.

As noted above, these results assume that 680 mill gal of this mandate is soybean

- based. To the extent that this increment is met with other feedstocks, the overall effe ct of this mandate on the price of soybeans and soybean oil would be smaller. Further, USDA currently predicts a long

- run decline in soybean and soybean oil prices over the next decade. Soybean prices are predicted to decline from the historical peak of $12.36 per bushel in 2011 to $9.36 per bushel by the beginning of 2022 (in 2010 dollars). The price of soybean oil is predicted to decline from a 2010 peak of $0.54 per pound to $0.42 per pound by the beginning of 2022. Our projections fit

within this general decline in prices, further bolstering the assessment that this mandate will not Deleted: EPA projects

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Page 19 of 71 significantly affect food prices. Finally, as part of our analysis for the RFS2 final rule, we estimated that the total impact of the program on food prices from a ll sources would be about $10 per person. 15 Given that the increase of 280 mill gal represents less than 1 percent of the 36 bill gal of biofuels analyzed for that rule, this analysis also indicates that the effects on food prices stemming from this mandate will be minimal

.

5. Other Bio

- oils

Although the modeling we conducted for the RFS2 final rule assumed that the only form

of bio

- oil used to make biomass

- based diesel would be from soybeans, in fact other seed oils
may contr ibute meaningful volumes to the pool. For instance, on September 28, 2010, we approved a RIN

- generating pathway for biodiesel made from canola oil 16 . The volume of biodiesel made from canola oil was 96 mill gallons in 2008 17 . In addition, we are evaluatin g other pathways for the production of biodiesel from oilseeds which could potentially be approved for RIN generation by 2013. On January 5, 2012 we proposed to include oil from camelina as an approved feedstock for producing biodiesel (77 FR 462). Algal oil could also provide additional feedstocks if promising technologies for production are commercialized.

Nevertheless, even if none of these other sources of bio

- oil were available, we believe that the total volume of grease, fats, corn oil, and soyb ean oil would be sufficient to produce 1.28 bill gallons of biomass

- based diesel in 2013.

C. Production Capacity

Total production capacity of the biodiesel industry has exceeded 1.28 bill gallons for a number of years. As of February 2012, total production capacity was more than 2.5 bill gallons for 191 companies 18 . According to the EPA registration database, 216 facilities have registered with the EPA under the RFS2 program as of March 15, 2012. Plants that are currently not registered under RFS 2 are either producing extremely low volumes that fall under the regulatory threshold for RIN generation, are producing products other than biodiesel such as soaps or cosmetics, or have shut down until such time as the demand for biodiesel rises.

While c omments generally did not disagree that sufficient production capacity exists to reach 1.28 bill gallons in 2013, some questioned how quickly idled plants can be brought back online. We note that most of the production capacity exists at plants that are a lready producing some volume, and that many operating biodiesel plants are currently producing at less than their full capacity. As a result, these facilities typically do not need to go through the additional steps that are associated with starting up an idled plant, such as securing new financing, establishing

15 Renewable Fuel Standard Program (RFS2) Regulatory Impact Analysis, Chapter 5: Economic Impacts and Benefits, Section 5.1 Agricultural Impacts, 2010.

16 75 FR 59622

17 EPA memorandum, "Summary of Modeling Input Assumptions for Canola Oil Biodiesel for the Notice of Supplemental Determination for Renewable Fuels Produced Under the Final RFS2 Program," Document # EPA

HQ

- OAR

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- 0133

- 0049

18 Plant list from National Biodie sel Board, 2/7/2012. Deleted: EPA

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Page 20 of 71 contracts with feedstock suppliers and customers, hiring and retraining employees, and testing and proving the equipment. Nevertheless, since many new plants can be built and started within

a year or so 19 , we also believe that pre

- existing but idled plants can be restarted in considerably less than a year. Given the time between release of this action and when the 1.28 bill gal requirement will become effective, there is no reason to believe that i dled plants cannot be restarted in time to contribute meaningfully to total volumes in 2013.

D. Consumption Capacity

Biodiesel is registered with the EPA under 40 CFR Part 79 as a legal fuel for use in highway vehicles. Under this registration, it ca n legally be used at any blend level, from 1% (B1) to 100% (B100) in highway diesel fuel. As there are no equivalent registration requirements for non

- highway fuels, biodiesel can legally be used at any blend level in nonroad diesel and heating oil. Howe ver, other factors typically limit the concentration of biodiesel in conventional diesel fuel. To the extent that the consumption of biodiesel occurs only at lower blend levels, the geographic area where biodiesel must be marketed would correspondingly be greater, impacting both how much biodiesel can be consumed in the U.S. as a whole as well as how the infrastructure may need to change to accommodate 1.28 bill gallons in 2013. As described below, we believe that there are no impediments to consuming an additional 280 mill gal of biodiesel.

Most engine manufacturers have explicit statements in their engine warranties regarding acceptable biodiesel blend levels. Although a few permit B100 to be used in their engines without any adverse impact on their w arranties, most limit biodiesel blends to B20 or less, and of those, about half allow no more than B5 20 . For specific applications where a party knows which engines will be using biodiesel blends, higher concentrations of biodiesel may be possible.

Howeve r, for general distribution such as at retail facilities, these warranty conditions create a disincentive to blend or sell biodiesel at higher concentrations and would tend to drive most blends towards low concentrations of biodiesel such as B5. Those par ties that commented on this issue agreed with this assessment.

Cold weather operability represents another reason for preferential use of B5 and even B2. The most common measure of cold weather operability is the fuel cloud point. The cloud point is th e temperature at which gelling begins (as indicated by solid crystals beginning to form in the fuel), and thus is an indicator of when potential engine filter plugging issues could arise. The higher the cloud point temperature of the fuel, the more likely such problems are to be experienced in cold weather. Biodiesel generally has a higher cloud point than conventional, petroleum

- based diesel fuel, with fat

- based biodiesel such as tallow having a higher cloud point than virgin oil

- based biodiesel such as a fuel made with soybean and canola oil. While cloud point issues with conventional, petroleum

- based diesel are generally mitigated during the winter months through blending with lighter grades (i.e., #1 diesel fuel), the cloud point of biodiesel generall y requires more dramatic interventions such as heated storage tanks, lines, and blending equipment, as well as heating rail cars and tank trucks. However, some of these biodiesel cloud

19 Based on construction times for new plants listed in Biodiesel Magazine from July 2006 through May 2009.

20 "Automaker's' and Engine Manufacturers' Positions of Support for Biodiesel Blends," Biodiesel.org*** E.O. 12866 Review

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Page 21 of 71 point mitigation efforts may be reduced through the use of low biodies el blend levels such as B2 or B5, since cloud point is strongly correlated with biodiesel concentration in the final blend. Insofar as biodiesel is blended into conventional diesel before being transported to its final destination for sale, low biodiesel blend levels may reduce the need for heated equipment at the

final destination.

Based on highway and nonroad diesel consumption projections for 2013 from the EIA, a biodiesel volume of 1.28 bill gallons would represent about 2.9% of all diesel fuel 21 . If all biodiesel were to be blended as B5, almost 60% of the diesel fuel consumed nationwide in 2013 would contain biodiesel. However, today some biodiesel is blended at concentrations higher than B5, and we expect that some blending at these higher concent rations would continue in the future. One commenter disagreed that blends higher than B5 will be marketed in any but niche markets. We agree with this comment. However, since there has been a cost difference between

biodiesel and conventional diesel in the recent past, and yet blends above B5 have in fact been sold, we believe that the existing markets for blends such as B20 are niche markets that will continue into the future. The sale of biodiesel blends higher than B5 will reduce the total amount

of diesel fuel that will contain some biodiesel. Directionally, then, this will also reduce the geographical areas to which biodiesel must be distributed. Based on the number of retail stations offering different biodiesel blend levels in 2010, we estimate that about 30% of biodiesel was sold at retail in blends with biodiesel concentrations as high as 20%. Another 17% of biodiesel

was sold in blends with biodiesel concentrations between 10% and 20%. 22 If the volumes of biodiesel currently sold as B10 and h igher were to continue to be sold in 2013, such blends would account for about one quarter of the 1.28 bill gal mandate, and 45% of the diesel fuel

consumed nationwide in 2013 would contain biodiesel.

Heating oil represents another opportunity for large volumes of biodiesel to be consumed. Moreover, some of the practical issues leading to warranty limits on engines regarding the use of biodiesel are less of a concern when burning biodiesel for home heating purposes. As a result, significant volumes of b iodiesel can be consumed as heating oil and count for compliance purposes under the RFS program.

We believe that distributing and consuming 1.28 bill gallons of biodiesel in 2013 are

achievable. As shown in Table III.D

- 1, a number of states already have mandates for the use of

biodiesel in 2013 23 , and efforts are underway by the production and distribution industries to

meet these mandates.

21 Assumes total diesel volum e consumed in the transportation sector in 2013 is 44.86 bill gal, per Annual Energy Outlook (AEO) 2012 Early Release, Table A2.

22 National Biodiesel Board, Retailing Fueling Sites, as of February 17, 2011. http://biodiesel.org/buyingbiodiesel/retailfueli ngsites/default.shtm

23 As one commenter pointed out, some of these mandates have not yet taken effect as in

- state production volumes have not yet reached specified thresholds. Nevertheless, the state mandates represent incentives within those states

to in crease production.*** E.O. 12866 Review

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Page 22 of 71 Table III.D

- 1

States with Biodiesel Mandates

Minnesota Diesel fuel for use in internal combustion engines must contain at least 5%

biodiesel. Beginning May 1, 2012, during the months of April through October, diesel fuel must contain at least 10% biodiesel (B10). Oregon Diesel fuel sold in the state must be blended with at least 5% biodiesel. Washington At least 2% of all diesel fuel sold in Washington must be biodiesel or renewable

diesel. This requirement will increase to 5% after it is determined that in

- state
feeds tock sources and oil

- seed crushing capacity can meet a 3% requirement. Pennsylvania All diesel fuel sold in Pennsylvania must contain at least 2% biodiesel one year

after in

- state production of biodiesel reaches 40 million gallons. The mandated

biodiese l blend level will increase to 5% biodiesel one year after in

- state production of biodiesel reaches 100 million gallons.

New Mexico After July 1, 2012, all diesel fuel sold to consumers for use in on

- road motor

vehicles must contain at least 5% biodiesel . This requirement may be suspended for up to six months under certain conditions.

Louisiana Within six months following the point at which cumulative monthly production of

biodiesel produced in the state equals or exceeds 10 million gallons, at least 2% of

the total diesel volume must be biodiesel. Source: U.S. Department of Energy, Alternative Fuels and Advanced Vehicles Data Center

Collectively, these states currently account for approximately 13 percent of the nationwide consumption of diesel. Other states that have implemented other forms of incentives are listed in

Table III.D

- 2.

Table III.D

- 2

States with Rebates, Refunds, Reduced Tax Rates, or Credits for Biodiesel Production or Blending

Illinois

Indiana

Kansas Kentucky

Maine Maryland Michigan

Mo ntana
North Dakota

Oklahoma

Rhode Island

South Carolina

South Dakota

Texas Virginia Washington
Source: U.S. Department of Energy, Alternative

Fuels and Advanced Vehicles Data Center

* Conditions and exemptions for all incentive programs vary by state*** E.O. 12866 Review

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Page 23 of 71 Collectively, the states listed in Table III.D

- 2 currently account for approximately 37% of the nationwide consumption of biodiesel. A variety of states also have requirements for the use of biodiesel in state fleets, provisions that allow biodiesel to be used as an alternative to meeting alternative fuel vehicle mandates, and credits/rebates for the installation of biodiesel dispensing and blending equipment. Altogether, therefore, more than half of the states in the U.S. have

mandates and/or incentives that will induce them to address biodiesel infrastructure issues.

One commenter pointed out that state

- specific economic incentives for the production of biodiesel do not necessarily eliminate cost differences between biodiesel and conventional diesel. We agree with this comment. Nevertheless, efforts to incentivize biodiesel production and use in individual states will directionally help the nation to meet a 1.28 bill gal biomass

- based diesel requirement in 2013.

Based on our review of the ability of diesel engines to use diesel blended with biodiesel, and the various state requirements and incentives to use biodiesel, we believe that consumption of 1.28 bill gal of biodiesel will not be problematic.

E. Biomass

- Based Diesel Distribution Infrastru cture

The National Petroleum Refiners Association (NPRA) stated that an analysis of the feasibility of meeting increased biodiesel use requirements should be based on a maximum

biodiesel blend ratio of 5%. 24 This is consistent with our analysis of the a dditional biodiesel distribution infrastructure that will be needed. NPRA commented that the required increase in the use of biodiesel will necessitate numerous installations of biodiesel storage tanks (possibly heated) as well as the installation of biod iesel receiving and blending capacity at the diesel fuel distribution terminals throughout the U.S. markets. This is also consistent with our analysis. In the proposal, we noted that some terminals may be able to avoid or delay the installation of

addit ional biodiesel storage facilities by storing 50/50 biodiesel/diesel fuel blends that are then further blended with diesel fuel to produce a finished fuel. However, we assumed that all biodiesel blending facilities would install segregated (heated and ins ulated) biodiesel storage facilities in our infrastructure analysis. We further noted that some terminals may delay the

installation of biodiesel in

- line blending equipment by splash blending biodiesel. 25 However, we stated that we expect that this approa ch would be temporary due to the heightened concerns over achieving a correct blend ratio and a fully mixed biodiesel blend that accompanies splash blending. We assumed that terminals would install in

- line biodiesel blending equipment in our

infrastructur e analysis.

We proposed finding that there will be sufficient fuel distribution infrastructure available to support the use of 1.28 bill gal of biomass

- based diesel in 2013. NPRA stated that the rapid

24 NPRA acknowledged that higher biodiesel blend ratios are sometimes used but that this would not substantially increase the capacity of the market to absorb additional biodiesel volume. NPRA recently changed its name to the

American Fu el & Petrochemical Manufacturers (AFPM).

25 In

- line blending refers to the process of blending biodiesel into petroleum

- based diesel fuel in the delivery line that feeds into the tank truck from the terminal storage tanks. Splash blending refers to the pro cess of first loading petroleum

- based diesel fuel into a tank truck followed by biodiesel so that the final blend meets the desired blend

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Page 24 of 71 expansion in B5 blending capability in the marketplac e necessary to support the use of the envisioned volumes of biodiesel is unrealistic and unachievable. NPRA did not further support this statement. The National Biodiesel Board (NBB) stated that there will be sufficient biodiesel

distribution infrastruct ure available to facilitate the use of the envisioned volumes of biodiesel. 26
NBB further stated that in most markets, terminals can treat 5% biodiesel blends as a fungible commodity like diesel fuel and that they believe that many terminals may be storing B5 blends. To the extent terminals store a finished B5 blend, it would obviate the need for much of the segregated biodiesel storage and blending capability that is assumed in our infrastructure analysis. The Iowa Biodiesel Board stated that claims that industry cannot accommodate the distribution of the target gallons are baseless and cited various examples of recent biodiesel blending initiatives at Iowa terminals.

We acknowledge that the required expansion of the biodiesel handling capacity at

term inals will represent a significant challenge to industry. However, we continue to believe that industry can respond effectively to this challenge to support the use of the envisioned 2013 biodiesel volume. Industry activities are currently progressing to meet the biomass

- based diesel volume requirement for 2012. We anticipate such efforts will continue to be successful in supporting the required biodiesel volume for 2013.

Our evaluation of the changes to the fuel distribution infrastructure that will be needed to support the use of 1,280 million gallons/yr in 2013 is based on the analysis conducted for the

RFS2 final rule. 27 See Table III.E

- 1.

Table III.E

- 1

Additional Infrastructure Needed to Distribute Biodiesel in 2013

Additional

Distribution Assets

Needed in 2013

Relative to 2012 Total Distribution

Assets Needed to Support 1.28 bill gal

Biodiesel Volume

Petroleum Product

Terminals with Biodiesel Blending Capability a 130 558

Rail Cars 230 984

Tank Trucks 25 108 Barges 7 29

a There are approximately 853 petroleum terminals that offer diesel fuel in the U.S.

The American Trucking Association (ATA) stated that EPA should have provided a discussion of the costs of the infrastructure changes contained in the above table. These c osts were accounted for in the discussion of the overall impacts on transportation fuel price contained in Section IV.B.1.d. The reader was referred to the RFS2 final rule Regulatory Impact Analysis for details on the projected costs of the additional di stribution infrastructure projected to be

26 NBB did not provide an analysis regarding the addition of new biodiesel distribution facilities.

27 Renewab le Fuels Standard Program (RFS2), Regulatory Impact Analysis (RIA), EPA

- 420

- R

- 10

- 006, February 2010. We are projecting that 80 million gallons per year of the biomass

- based diesel standard would be satisfied by

renewable diesel fuel. The distribution of renewable diesel fuel is discussed later in this section.*** E.O. 12866 Review

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Page 25 of 71 needed. The RFS2 final rule projected that a new 8,000 gallon tank truck to transport biodiesel would cost $198,000, a new 25,600 gallon rail car to transport biodiesel would cost $99,000, and a new 10,000 barrel barge to transport biodiesel would cost $1.54 million. The cost to install new segregated biodiesel storage, blending, receipt, and other miscellaneous biodiesel handling equipment was estimated at $1.6 million per terminal. The estimated total cost of t he additional biodiesel distribution assets needed in 2013 relative to 2012 is $246.5 million.

ATA commented that EPA underestimated the number of tank trucks needed to distribute

the additional amount of biodiesel in 2013 relative to volume use d in 2012. ATA stated that the assumed 6 trips per tank truck per day that EPA used in estimating the number of tank trucks that would be needed was unrealistically high. ATA stated that one large ATA member that transports biofuels reports that the aver age length of haul (one way) is 141 miles. Based on this, ATA stated that 2 loads per day would be a more accurate estimate considering loading and unloading times.

ATA assumed a single shift tank truck delivery operation. Our estimated number of tank

t rucks was based on a two shift operation. We continue to believe that a two shift truck delivery model of operation is appropriate to maximize the utilization of distribution system resources. Given time for loading and unloading and lunch breaks for 2 s hifts, our assumed 6 deliveries per day equates to an average one way truck shipping distance of 40 miles. We project that a number of additional biodiesel plants will be brought into production to meet the 2013 biodiesel volume. Biodiesel production pl ants tend to be geographically dispersed. Hence, the opening of additional plants will tend to reduce the average shipping distance from the biodiesel production plant to the terminal compared to today. We also project that the production volume will

inc rease at a number of existing biodiesel plants. This will facilitate the shipment by rail of biodiesel volumes that previously were shipped by truck long distances. Thus, we believe that biodiesel trucking distances will be substantially reduced in the f uture.

Nevertheless, we acknowledge that uncertainty exists regarding what biodiesel shipping distances will be in the future. Therefore, we believe that it is useful to evaluate the potential impacts of longer shipping distances on the number of additio nal tank trucks that will be needed to transport biodiesel. If we were to assume a 141 mile average truck shipping distance per ATA

and a two

- shift operation, this would translate to 4 loads per day per tank truck. At 4 loads per day, 38 additional numbe r of tank trucks would be needed in 2013 relative to 2012 (as opposed to the 25 that we projected). If we were to assume only 2 deliveries per day as ATA did, an additional 75 trucks would be needed for the 2013 case. Even under this extreme case, the

a ddition of 75 tank trucks would represent less than 0.3% of the total U.S. fleet of petroleum products tank trucks (estimated at 27,000). 28 Consequently, that the possibility that biodiesel shipping distances might be longer than we projected would not materially affect our conclusions about the ability to accommodate the additional tank trucks and drivers needed.

In the proposal, we estima ted that a total of 5 tank trucks will be needed to transport 80 mill gallons/yr of renewable diesel that we projected would be used annually in 2012 and 2013 to

28 Department of Transportation, Hazardous Materials, Safety Requirements for External Product Piping on Cargo Tanks Transporting Flammable Liquids, Notice of Proposed Rulemaking, 76 FR 4847, January 27, 2011. http://www.gpo.gov/fdsys/pkg/FR

- 2011

- 01

- 27/pdf/2011

- 1695.pdf*** E.O. 12866 Review

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Page 26 of 71 the locations where it is blended with petroleum

- based diesel fuel. This is based on each tank truck carrying 7,800 gallons of renewable diesel fuel making 6 deliveries per day. We estimate that the production facility that will account for the renewable diesel produced through 2013 will ship its product 20 miles or less by tank truck to facilitie s that produce blends with petroleum

based diesel fuel. Shipment of the projected renewable diesel volume such short distances could likely be achieved by making 6 deliveries during one shift without the need for a second shift. We anticipate that the re newable diesel fuel will be blended directly into storage tanks containing petroleum

- based diesel fuel. Consequently, we continue to believe that the distribution of renewable diesel fuel could be accomplished without undue difficulty.

IV. Impacts of 1 .28 Billion Gallons of Biomass

- Based Diesel

In order to evaluate the impacts of a biomass

- based diesel volume of 1.28 bill gal in the areas required under the statute (see Section II), we first considered what the appropriate

reference would be. Since the statute requires that the biomass

- based diesel volume we set for 2013 be no lower than 1.0 bill gal, we believe that this is an appropriate reference point. Therefore, in the discussion that follows, we have focused on either a volume of 1.28 bill gal

biomass

- based diesel or an increment of 0.28 bill gal biomass

- based diesel, depending on the specific sources of information and analyses available.

The statute requires that we analyze specified environmental and other impacts in deriving an applicable biomass

- based diesel volume for 2013 and other years. These analyses can be conducted for 1.28 bill gal biomass

- based diesel or an increment of 0.28 bill gal. Most of the areas we are required to analyze were covered in the RFS2 final rule in some form, and we believe that we can use this information in satisfying our statutory obligations to analyze specified factors in determining the applicable volume of biomass

- based diesel for 2013.

The statute envisions annual increases in applicable volumes of renewable fuels leading to 36 bill gallons by 2022. In considering potential increases in the applicable volume requirement for biomass

- based diesel, we believe that certain factors that we must consider under the statute are most appropriately analyzed in the longer term, after the full build

- up of renewable fuel production and use envisioned by the statute are in place. Others factors are more appropriately analyzed for the near term, including production capacity, availability of feedstocks, and impac ts on infrastructure. These are factors that could limit the successful implementation of any increment in required applicable volume. We believe that other factors are appropriately considered over a longer term, since full build

- up of the RFS program i s expected to generate benefits over many years, and short

- term considerations should not impede attainment of long term goals and benefits. We believe that greenhouse gas emissions are one factor for which taking a long

- term view is appropriate. Finally , certain factors, such as energy security, may be evaluated for both near

- and long

- term benefits. Thus for this final rule, we have not simply looked at the impacts of the program in any one year with near term implementation, but have also looked at the evolving pattern of impacts through time where it is appropriate to do so.*** E.O. 12866 Review

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Page 27 of 71 Some of the analyses presented in the RFS2 final rule were for the specific case of 1.28 bill gallons in 2013. These analyses included an investigation of the expected annual ra te of commercial production of biomass

- based diesel in 2013, impacts on agricultural commodity supply and price, and the cost to consumers of transportation fuel. Some of these were discussed in Section III above. Most of the analyses in the RFS2 final r ule, however, were conducted to represent full implementation of the RFS2 program in 2022. In these analyses, the biomass

based diesel volume was estimated to be 1.82 bill gallons, which was compared to a reference case biodiesel volume of 380 mill gallon s. These cases are shown in Table IV

- 1.*** E.O. 12866 Review

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Page 28 of 71

### *** E.O. 12866 Review

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Page 29 of 71 Table IV

- 1 Primary 2022 Reference and Control Cases from RFS2 Final Rulemaking (billion gallons)

Advanced Biofuel Non

- Advanced

Biofuel Total

Renewable

Fuel Cellulosic Biofuel Biomass

- Based Diesel Other Advanced Biofuel

Cellulosic

Ethanol Cellulosic

Diesel FAME a



### Biodiesel NCRD b 

### Other

Biodiesel c 

### Imported

Ethanol Corn Ethanol

Reference 0.25 0 0.38 0 0 0.64 12.29 13.56

Control 4.92 6.52 0.85 0.15 0.82 2.24 15.00 30.50

a Fatty acid methyl ester (FAME) biodiesel

b Non

- Co

- processed Renewable Diesel (NCRD)

c Other Biodiesel is biodiesel produced in addition to the amount needed to meet the biomass

- based diesel standard.*** E.O. 12866 Review

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The biomass

- based diesel volume of 1.82 bill gallons analyzed for 2022 in the RFS2 final rule is higher than the 1.28 bill gallons we are required to evaluate for today's final rule for 2013. More importantly, the change in biodiesel production in 2022 du e to the statutory mandates for

biomass

- based diesel plus other diesel anticipated to meet the advanced biofuel volume (a total increase of 1.44 billion gallons compared to the reference case without the EISA mandates) is much larger than the change we are evaluating for 2013 (0.28 billion gallons). The RFS2 final rule analysis considers impacts from the entirety of the renewable fuel mandates, as opposed to impacts resulting solely from the biodiesel portion of the mandates.

In response to the NPRM, t he American Petroleum Institute (API) commented that comparing the analyses conducted in the RFS2 final rule for the fully implemented RFS2 program in 2022 to a biodiesel increment of 0.28 bill gal occurring in 2013 was misleading. They cited the fact tha t the 2022 analysis between the control and reference cases accounts for agricultural and market conditions that develop over multiple years, while the proposed biomass

based diesel requirement of 1.28 bill gallons in 2013 would require those changes to oc cur over a single year. They also cited the fact that the single

- year growth from 2012 to 2013 that would occur under a requirement for 1.28 bill gallons (0.28 bill gallons in one year) is about twice as high as the annualized growth rate in the RFS final rule (1.44 bill gal increase over ten years, or about 0.14 bill gal per year).

As described in Section III, we believe that the industry can increase production to at least 1.28 bill gallons by 2013, that sufficient feedstock will be available, and that the infrastructure will be able to accommodate these higher volumes. Therefore, we do not believe that API's concern about the different annual production growth rates in the RFS2 final rule compared to our proposal for 2013 is warranted.

With regard t o concerns about agricultural and market conditions, we agree that the positive impacts of yield growth and foreign crop production increases that may be reflected in our 2022 analysis, and which develop over multiple years, may not be representative of a single

year increase in biomass

- based diesel of 0.28 bill gallons in 2013. However, the RFS is a

forward

- looking program that focuses on long

- term changes in the fuels sector. For this reason, it is not appropriate to emphasize specific interim year impa cts in cases where these impacts are transient and continually changing. However, in some cases we have been able to analyze a 2013 impact and compare it to the 2022 impact analyzed for the RFS2 final rule. In other cases

we have used trends used to deri ve our 2022 assessments to indicate likely impacts in 2013. Since the NPRM, EPA has conducted a specific analysis of the effects of the 2013 mandate on the biofuels market. This analysis is detailed in Section IV.B of this rulemaking. This analysis

was conducted in response to comment about quantifying some of the costs and benefits of this rule. However, it also addresses API’s concerns by providing a year

- specific analysis.

We recognize that uncertainties remain regarding how markets for soybean s and other crops will react to a mandate of 1.28 bill gallons for biomass

- based diesel. For instance, the volume of soybean oil required to meet the mandate will likely be higher in 2013 than it has been in 2011. As a result, there may be upward pressur e on soybean oil prices, which we consider in*** E.O. 12866 Review

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Section III.B of this rulemaking. Nevertheless, we expect that RIN prices will adjust in the market to provide the economic incentive for the mandate to be met. As described in the rulemaking that established the RFS1 program, the RIN system was designed with this end in

mind.

A. Consideration of Statutory Factors

1. Climate Change

Since biodiesel has a GHG benefit compared to the petroleum

- based diesel it is replacing,

an increase in biomass

- based diese l of 0.28 bill gal from 2012 to 2013 will lead to a displacement of conventional diesel fuel, with corresponding GHG emissions reductions. This

increased use of biomass

- based diesel will contribute to lower climate change impacts in comparison to the petr oleum

- based diesel it is replacing.

One commenter suggested that increased biodiesel use would also reduce GHG emissions compared to sugarcane ethanol, an alternative advanced biofuel that would be used to meet the

mandate. This statement is based on t he specific GHG reductions associated with a gallon of biodiesel produced in 2022 that we estimated in our lifecycle analysis for different biofuels. However, for this rulemaking we are only considering the GHG impacts of the biomass

- based

diesel standard . Therefore, it is outside the scope of this rule to analyze the potential GHG emission impacts of displacing sugarcane ethanol with biodiesel.

One commenter also suggested that by requiring 0.28 bill gallons of biomass

- based diesel above the statutory minimum of 1.0 bill gallons, effectively shifting the biodiesel used for the “other” advanced biofuel category to biomass

‐ based diesel, EPA would actually promote increased volumes of renewable fuels (rather than ethanol

‐ equivalent gallons based on the 1.5 equivalence value), allowing for the greater displacement of fossil fuels. However, this is not the case. Although the requirement for a physical volume of biomass

- based diesel will be 1.28 bill gallons, the contributi on of this volume to compliance with the advanced biofuel requirement is based on energy

- equivalence with respect to ethanol, not physical volumes. Thus there will be no additional quantities of other advanced fuels produced.

EPA estimates the social benefits of regulatory actions that have a small or “marginal” impact on cumulative global CO 2 emissions using the social cost of carbon dioxide (SC

- CO 2 ).

The SC

- CO 2 is an estimate of the net present value of the flow of monetized damages from a one

metri c ton increase in CO 2 emissions in a given year. Alternatively, this represents the benefit to society of reducing CO 2 emissions by one ton. 29 The SC

- CO 2 includes, but is not limited to, climate damages due to changes in net agricultural productivity, hum an health, property damages from flood risk, and ecosystem services.

The SC

- CO 2 estimates currently used by the Agency were developed through an interagency process that included EPA and other executive branch entities and concluded in February 2010. The Technical Support Document: Social Cost of Carbon for Regulatory Impact

29 In the absence of direct model estimates of the social cost of non

- CO 2 GHGs, the social cost of CO 2 can be used to

estimate those benefits on a CO 2 - e basis, as discussed further bel ow.*** E.O. 12866 Review

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Analysis Under Executive Order 12866 for the final joint EPA/Department of Transportation Rulemaking to establish Light

- Duty Vehicle Greenhouse Gas Emission Standards and Corporate Average Fuel Economy Standards provides a complete discussion of the methods used to develop the SC

- CO 2 estimates (Interagency Working Group on Social Cost of Carbon, 2010) (hereafter, “2010 TSD”).

To monetize global social benefits of reduced CO 2 emi ssions, the interagency group

selected four SC

- CO 2 estimates for use in regulatory analysis. In 2013, these are: $6, $24, $39, and $73 per metric ton of CO 2 emissions in 2013 (in 2010 dollars). The first three values are based on the average SC

- CO 2 from three integrated assessment models, at discount rates of 5, 3, and 2.5 percent, respectively. SC

- CO 2 s at several discount rates are included because the

literature shows that the SC

- CO 2 is quite sensitive to assumptions about the discount rate, and

becaus e no consensus exists on the appropriate rate to use in an intergenerational context. The fourth value is the 95th percentile of the SC

- CO 2 from all three models at a 3 percent discount rate. It is included to represent higher

- than

- expected impacts from t emperature change further

out in the tails of the SC

- CO 2 distribution. The “central value” is the average SCC across models at the 3 percent discount rate. For purposes of capturing the uncertainties involved in regulatory impact analysis, we emphasize th e importance and value of considering the full range.

The 2010 interagency SCC technical support report discusses a number of important limitations for which additional research is needed. In particular, the document highlights the incomplete way in which the integrated assessment models capture catastrophic and non

- catastrophic impacts, their incomplete treatment of adaptation and technological change, uncertainty in the extrapolation of damages to high temperatures, and assumpt ions regarding risk aversion. The limited amount of research linking climate impacts to economic damages makes this modeling exercise even

more difficult. The interagency group recommended that the SCC estimates used for regulatory analysis by the Federal government be revisited and continue to evolve with improvements in modeling.

The SC

- CO 2 increases over time because future emissions are expected to produce larger incremental damages as physical and economic systems become more stressed in response to greater climatic change. For example, by 2022 the four estimates increase to $8, $29, $45, and $88 per metric ton of CO 2 emissions (in 2010 dollars). Note that the interagency group estimated the growth rate of the SCC directly using the three integrated assessment models rather than assuming a constant annual growth rate. This helps to ensure that the estimates are internally consistent with other modeling assumptions. The Table below presents the four estimates for the years 2013 through 2022.

Table I V.A.1

- 1 Benefit per Metric Ton CO 2 Reduced

, 2013

- 2051 ($2010) a

Year Discount Rate (Statistic)

5% (Avg) 3% (Avg) 2.5% (Avg) 3% (95th %ile)

2013 $6 $24 $39 $73

2014 $6 $24 $39 $74

2015 $6 $25 $40 $76

2016 $6 $25 $41 $78

2017 $6 $26 $42 $79 Deleted: 2022*** E.O. 12866 Review

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2018 $7 $26 $42 $81

2019 $7 $27 $43 $83

2020 $7 $28 $44 $84

2021 $7 $28 $45 $86

2022 $8 $29 $45 $88

2023 $8 $29 $46 $90

2024 $8 $30 $47 $92

2025 $9 $31 $48 $94

2026 $9 $31 $49 $96

2027 $9 $32 $50 $98

2028 $10 $33 $50 $100

2029 $10 $33 $51 $102

2030 $10 $34 $52 $104

2031 $10 $35 $53 $106

2032 $11 $35 $54 $108

2033 $11 $36 $55 $110

2034 $11 $37 $56 $112

2035 $12 $37 $56 $114

2036 $12 $38 $57 $116

2037 $12 $39 $58 $118

2038 $13 $39 $59 $120

2039 $13 $40 $60 $122

2040 $13 $41 $61 $124

2041 $14 $41 $62 $126

2042 $14 $42 $62 $128

2043 $14 $43 $63 $130

2044 $14 $43 $64 $131

2045 $15 $44 $64 $133

2046 $15 $44 $65 $135

2047 $15 $45 $66 $137

2048 $16 $46 $66 $138

2049 $16 $46 $67 $140

2050 $16 $47 $68 $142

2051 b $16 $47 $68 $142

a The SC

- CO 2 values vary depending on the year of CO 2 emission and are defined in real terms. The change from year to year is not obvious in this table because estimates are rounded to the nearest dollar.

b The Interagency Working Group on Social Cost of Carbon did not estimate SCC

- CO 2 values beyond 2050. However, to estimate the monetized impact of a 30 year stream of emissions beginning in 2022, we must have some estimate for the year 2051. SCC

- CO 2 value s increase incrementally every year under the projections presented above. However, since monetized impacts for the year 2051 have not yet been established by the Interagency Working Group, we assume for the purposes of this analysis that they are equal t o the 2050 impacts to avoid

overestimation.

Today’s rulemaking also analyzes reductions in non

- CO 2 GHGs. The 2010 interagency work group, however, did not directly estimate the social cost of non

- CO 2 GHGs. In the absence*** E.O. 12866 Review

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of direct model estimates from the interagency analysis, EPA has used a “global warming potential (GWP) approach” to estimate the dollar value of this rule’s non

- CO 2 GHG benefits. 30
This approach is consistent with the methodology used in the final RFS2 rulemaking, which was

finalized prior to the 2010 interagency work group process. Specifically, EPA converted

methane and nitrous oxide to CO 2 equivalents using the GWP of these gases, then multiplied

these CO 2 - equivalent emission reductions by the interagency social cost of carbon dio xide estimates. Furthermore, EPA has used the 100

- year GWP estimates from the IPCC Second Assessment Report (SAR) to estimate the methane and nitrous oxide benefits for this rule. The use of the SAR GWP values allows comparability of data collected in th is final rule to the national GHG inventory that EPA compiles annually to meet U.S. commitments to the United Nations Framework Convention on Climate Change (UNFCCC).

As discussed in a recent working paper (Marten and Newbold, 2011) 31 , the GWP

weighted b enefit estimates for methane and nitrous oxide are likely to be lower than those that would be derived using a directly modeled social cost of the non

- CO 2 GHGs for a variety of

reasons. 32 In sum, the authors find that an integrated assessment model produce s higher estimates of the social cost of methane and nitrous oxide than the GWP approach because the model captures the effect of temperature changes on economic output over time, whereas GWP is based only on physical impacts.

EPA established in the RFS2 final rule that a gallon of soybean

- based biodiesel results in an annualized GHG emission reduction of 57 percent compared to the 2005 petroleum baseline (approximately 0.0065 tons of CO 2 equivalent per gallon). This GHG reduction is calculated by estimating the annualized emissions streams over 30 years, starting in 2022 (the year when the RFS2 program will be fully implemented). For this reason, it may not be appropriate to attribute

benefits estimates from GHG reductions to biodiesel production in 2013

. This is not because

EPA believes that the GHG benefits of 2013 biodiesel production will be zero, but rather because it may not be consistent to cite the m for an interim year of the program using lifecycle biofuel assessments based on a 2022 analyses

. 33

To monetize the global SC

- CO 2 value, we use the same stream of emissions for both 2013 and 2022 that were estimated for the RFS2 final rulemaking. We t hen apply the appropriate SC

- CO 2 dollar values to each year (i.e., we apply the 2015 SC

- CO 2 value to a stream

30 For a longer discussion of the GWP approach, see the Regulatory Impact Analysis associated with the New

Source Performance Standards and Amendments to the National Emissions Standards for Hazardous Air Pollutants for the Oil and Natural Gas Industry

, issued on April 17, 2012. See http://www.epa.gov/airquality/oilandgas/actions.html

. 31 Marten, A. and S. Newbold. 2011. “Estimating the Social Cost of Non

- CO 2 GHG Emissions: Methane and
Nitrous Oxide.” NCEE Working Paper Series # 11

- 01. http://yosemite.epa.gov/ee/epa/eed.nsf/WPNumber/2011

- 01?opendocument

32 As discussed in Marten and Newbold, the discount rate influences whether directly modeled social cost e stimates are higher than those estimated with the GWP approach. Methane is a short

- lived gas and therefore direct modeling results in higher social costs at higher discount rates than the GWP approach.

33 We analyzed the GHG benefits of the renewable fue ls in the context of full implementation of the RFS2 program

in 2022

. The 2022 analysis represents a n assumption for the purposes of modeling, to best capture the lifecycle GHG emissions for the required volumes of renewable fuel at full implementation. Emissions in other years will differ; for example, our analysis for 2022 assumes that soybean yields will continue to increase from today’s levels because of technological innovation

. Deleted: include any

Deleted: our

Deleted: calculations.

Deleted: in*** E.O. 12866 Review

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in 2015, the 2028 value to a stream in 2028). These benefits are then totaled, discounted to net present value using the applicable discount rate , and divided by 30 to place the estimate back on a per gallon basis. The resulting estimates are provided in the table below for 2013 and 2022. 34

Table IV.A.1

- 2 Monetized per Gallon CO 2 - e Annualized Benefits of Biomass

- Based Diesel Produced in 2013

and 2022 ($2010) a

Year Annualized

Emissions

Reduction (Tons of CO 2 - eq/ gallon) Benefits

5% (Avg) 3% (Avg) 2.5% (Avg) 3% (95th %ile)

2013 0.0065 $0.02 $0.12 $0.21 $0.37

2022 b 0.0065 $0.03 $0.14 $0.23 $0.43

a Estimates represent the CO 2 - eq estimate of carbon dioxide, methane, and nitrous oxide reductions multiplied by the SCC estimates (“GWP approach”). CO 2 - eq for methane calculated using the GWP of 21 (SAR). These co

- benefit estimates are not the same as would be derived using a social cost of meth ane directly computed from integrated assessment models. See Marten and Newbold (2011) for discussion of the limitations of the GWP approach.

b We estimate monetary values for the years 2022

- 2051 based on the values established by the Interagency Working Group on Social Cost of Carbon. See Table IV.A.1

- 1 for further details.

2. Energy Security

This final standard will assure an increased use of biomass

- based diesel in the U.S. and help to improve U.S. energy security. Reducing U.S. petroleum imports and increasing the diversity of U.S. liquid fuel supplies lowers both t he financial and strategic risks caused by potential sudden disruptions in the supply of imported petroleum to the U.S. The economic value of reductions in these risks provides a measure of improved U.S. energy security. This
section summarizes EPA’s est imates of U.S. oil import reductions and energy security benefits

from this rule

.

In 2010, U.S. petroleum import expenditures represented 14 percent of total U.S. imports of all goods and services. 35 These expenditures rose to 18 percent by April of 20 11. 36 In 2010, the United States imported 49 percent of the petroleum it consumed 37 , and the transportation sector accounted for 71 percent of total U.S. petroleum consumption. This compares to approximately 37 percent of total U.S. petroleum supplied by im ports and 55 percent of U.S. petroleum consumption in the transportation sector in 1975. Requiring higher volumes of renewable fuels to be used in the U.S. is expected to lower U.S. oil imports.

34 Tables IV.A.1

- 1 and IV.A.1

- 2 provide summary details about the global SC

- CO 2 values and emissions streams used in our calculations. Additional details are included in a Memorandum to the Docket, Docket ID XXX, Dated May XX, 2012.

35 http://www.eia.gov/dna v/pet/hist/LeafHandler.ashx?n=PET&s=WTTIMUS2&f=W

36 http://www.eia.gov/dnav/pet/pet_move_impcus_a2_nus_ep00_im0_mbblpd_a.htm

37 http://www.eia.gov/dnav/pet/pet_pri_rac2_dcu_nus_m.htm Deleted: 2022

Deleted: reduce

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This rule will require an additional 280 million gallons of biodiesel to be produced, which equals about 255 million gallons of diesel equivalent. 38 Based on analysis of historical and projected future variation in U.S. petroleum consumption and imports, we estimate that approximately 50 percent of the reductio n in fuel consumption resulting from adopting renewable fuels is likely to be reflected in reduced U.S. imports of refined fuel, while the remaining 50 percent is expected to be reflected in reduced domestic fuel refining. Of this latter figure, 90 percen t is anticipated to reduce U.S. imports of crude petroleum for use as a refinery feedstock, while the remaining 10 percent is expected to reduce U.S. domestic production of crude petroleum. Thus, on balance, each gallon of fuel saved as a consequence of t he renewable fuel standards is anticipated to reduce total U.S. imports of petroleum by 0.95 gallons. 39

Therefore, based on these assumptions, this rule is expected to reduce imports of petroleum by about 242 million gallons. Table IV.A.2

- 1 below compares EPA’s estimates of the reduction in imports of U.S. crude oil and petroleum

- based products from this program to projected total U.S. imports for the years 2013 and 2022

.

T able IV.A.2

- 1 Projected Import Reductions from this Rule and Total U.S. Petroleum

- Based Imports in

2013 and 2022 (Millions of Barrels)

Year U.S. Petroleum

- Based

Import Reductions

from the Rule (million barrels/yr) U.S. Total Petroleum

Based Imports withou t
the Rule (million barrels/yr)

2013 5.8 3,391

2022 5.8 2,964

In order to understand the energy security implications of reducing U.S. petroleum imports, EPA worked with Oak Ridge National Laboratory (ORNL), which has developed approaches for evaluating the economic costs and energy security implications of oil use. The energy security estimates provided below are based upon a methodology developed in a peer

reviewed study entitled, ” The Energy Security Benefits of Reduced Oil Use, 2006

- 2015 ,” completed in March 2008. This study is included as part of the docket for this rule. 40

, 41
When conducting its analysis, ORNL considered the full economic cost of importing petroleum

into the United States.

The economic cost of importing petroleum into the U.S. is defined to include two components in addition to the purchase price of petroleum itself. These are: (1) the higher costs for oil imports resulting from the effect of increasing U.S. import demand on the world oil price and on the market power of the Organization of Petroleum Exporting Countries (i.e., the

38 RFS2 Final Rulemaking

39 This figure is calculated as 0.50 + 0.50*0.9 = 0.5 0 + 0.45 = 0.95.

40 Leiby, Paul N., " Estimating the Energy Security Benefits of Reduced U.S. Oil Imports " Oak Ridge National Laboratory, ORNL/TM

- 2007/028, Final Report, 2008. (Docket EPA

- HQ

- OAR

- 2010

- 0162)

41 The ORNL study “ The Energy Security Benefits of Reduced Oil Use, 2006

- 2015 ," completed in March 2008, is an update version of the approach used for estimating the energy security benefits of U.S. oil import reductions developed in an ORNL 1997 Report by Leiby, Paul N., Donald W. Jones, T. Randall Curlee, and Russell Lee,
entitled “ Oil Imports: An Assessment of Benefits and Costs. " (Docket EPA

- HQ

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- 0162) Deleted: reduces*** E.O. 12866 Review

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“demand” or “monopsony” costs); and (2) the risk of reductions in U.S. economic output and disruption of the U.S. economy caused by sudden disruptions in the supply of imported petroleum to th e U.S. (i.e., “macroeconomic disruption/adjustment costs”).

An often

- identified component of the full economic costs of U.S. oil imports is the cost to U.S. taxpayers of existing U.S. energy security policies. The two primary components of this

cost a re likely to be (1) the expenses associated with maintaining a U.S. military presence

– in part to help secure a stable oil supply

– in potentially unstable regions of the world; and (2) costs for maintaining the U.S. Strategic Petroleum Reserve (SPR). Th e SPR is the largest stockpile of
government

- owned emergency crude oil in the world.

The EPA recognizes that potential national and energy security risks exist due to the possibility of tension over oil supplies. Much of the world’s oil and gas suppli es are located in countries facing social, economic, and demographic challenges, thus making them even more vulnerable to potential local instability. Thus, to the degree to which this final rule increases the diversity of sources of liquid fuel for U.S. consumption and/or reduces reliance upon imported energy supplies that can be deployed by either consumers or the nation’s defense forces, the United States could expect benefits related to national security and increased energy supply. Although the Agency recognizes the clear benefit to the United States from reducing dependence on foreign oil, the Agency has been unable to calculate the monetary benefit that the United States will receive from the improvements in national security expected to result from this

program.

Also, while the costs of building and maintaining the SPR are clearly related to U.S. oil use and imports, these costs have not varied historically in response to U.S. oil import levels. Thus, the costs of maintaining the SPR are excluded from this analysi s. In addition, given the redistributive nature of this monopsony effect from a global perspective, it is excluded in the energy security benefits calculations for this rule. In contrast, the other portion of the energy security premium, the U.S. macroec onomic disruption and adjustment cost that arises from U.S. petroleum imports, does not have offsetting impacts outside of the U.S. and, thus, is included in the energy security benefits estimated for this rule. To summarize, EPA has included only the

mac roeconomic disruption portion of the energy security benefits to estimate the monetary value of the total energy security benefits of this program.

The U.S. is projected to be a net exporter of diesel fuel in 2013. 42 Increased biodiesel produc tion w ould likely result in less domestic consumption of diesel fuel in the U.S. Th e reduced consumption may be reflected in increased exports of diesel from the U.S. However, regardless of the incremental effect of this rule on net imports, i ncreasing the diversi fication of the U.S. and global diesel fuel pools would likely confer some reduction in the severity of a future potential disruption in the world oil market.

The energy security premiums for the year 2013 and 2022 are presented in Table

IV.A.2

- 2 as well as a breakdown of the components of the energy security premiums for those

42 U.S. Energy Information Administration (EIA). “ Short

- Term Energy Outlook”, Table 4a, June 2012

. http://205.254.135.7/forecasts/steo/tables/pdf/4atab.pdf*** E.O. 12866 Review

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years. These energy security premiums are recorded o n a dollar per barrel of oil imported reduced from this rule. On a gallon of biodiesel fuel basis, these translate into a n estimated $0.15/gallon benefit in 2013 and a $0.16/gallon benefit in 2022 for the macroeconomic disruption and adjustment costs comp onent of the energy security premium (in 2010$).

Table IV.A.2

- 2 Energy Security Premiums in 2013 and 2022 (2010$/Barrel) Based on ORNL Methodology

Monopsony Macroeconomic

Disruption/Adjustment Costs Total Mid

- Point

2013 $11.40

($3.83

- $19.40) $7.13 ($3.41

- $10.35) $18.53 ($10.03

- $26.74)

2022 $9.82

($3.27

- $ 16.77) $7.84 ($3.80

- $ 11.30) $17.66 ($9.88

- $ 24.99)

Note: Values in parentheses represent a 90% confidence interval around the central value.

Using EPA’s fuel consumption analysis in conjunction with ORNL’s energy security premium estimates, the agency has developed estimates of the total energy security benefits for the year 2013 and 2022 in Table IV.A.2

- 3.

Table IV.A.2

- 3

Estimated Energy Sec urity Benefits in 2013 and 2022 (2010$)

U.S. Oil Imports

Reduced (million barrels/yr) Benefits

($ Millions)

2013 5.8 $41.2

2022 5.8 $45.5

One commenter suggested that an increase in biodiesel for the mandate is statistically insignificant. EPA interprets this comment to mean that the increase in biodiesel production due to this rule is not a sufficiently large volume that it will add significantly to the energy security position of the U.S. EPA’s analysis of energy security is conducted on a pe r gallon basis, and per gallon estimates are extrapolated upwards to estimate the total energy security benefits

estimate in Table IV.A.2

- 3. Thus, we assume that each extra gallon of biodiesel has an equal energy security benefit regardless of the overal l size of the renewable fuels volume requirement. Thus, total energy security benefits are increasing with this rule.

3. Agricultural Commodities and Food Prices

For the RFS2 rule, we examined the impacts of increased renewable fuels production on commodity prices, food prices and trade in agricultural products. This analysis considered the impacts of all the biofuel feedstock sources anticipated to meet the 2022 biofuel volume requirements, not just biodiesel. For the RFS2, EPA used two primary models for its agricultural economic impacts analysis, the Food and Agriculture Sector Optimization Model (FASOM) and Deleted: a

Deleted:

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the Food and Agricultural Policy Research Institute

- C enter for Agriculture and Rural Development (FAPRI

- CARD) models. The FASOM model is a long

- term economic model of the U.S. forest and agriculture sectors that maximizes the net present value of the sum of producer and consumer surplus across the two secto rs over time subject to market, technology,

and other constraints. The FAPRI

- CARD models are a system of econometric models covering many agricultural commodities in the U.S. and internationally. They are based on historical data analysis, current academ ic research, and a reliance on accepted economic, agronomic, and biological relationships in agricultural production and markets. 43

To meet the RFS2 renewable fuel volumes, a number of price effects on the agricultural

commodities were estimated for 2022 . For instance, FASOM estimated that an increase in renewable fuel volumes to meet the RFS2 will result in an increase in the U.S. soybean prices of $1.02 per bushel (10.3 percent) above the Reference Case price in 2022. FASOM also projected the price of soybean oil will increase by $183 per ton (37.9 percent) over the 2022 Reference Case price (all prices are in 2007$). Most of the additional soybeans needed for increased biodiesel production are diverted from U.S. exports to the rest of the world. In FASOM, soybean exports decrease by 135 million bushels (

- 13.6 percent) in 2022 relative to the AEO2007 Reference Case. This change represents a decrease of $453 million (

- 4.6 percent) in the total value of U.S. soybean exports in 2022. However, these pri ce effects are not attributed to the demand for biodiesel feedstock alone, rather the compounding affect of all changes in feedstock demand estimated to result from the total biofuel mandate in 2022. Since the impact on soybeans due to biodiesel demand wa s only a portion of this total feedstock impact and since the impact in 2013 will be less than considered in 2022 (since the 2013 biodiesel volumes are less than those considered for 2022), the impact on soybean prices and exports from an increase to

1.28 bill gall in 2013 should also be less. See Sections III.B.3 and IV.B.1.a of this rulemaking for further information on the impact on soybean availability and prices.

A recent report by IHS Global Insight 44 also discusses potential agricultural and

econom ic impacts from increasing vegetable oil demand for biodiesel production. According to this study, existing soybean yield technologies are expected to be applied increasingly across the U.S., resulting in roughly a 10% higher growth rate in soybean yields than USDA’s projections

from 2010

- 2016 which were used by EPA in its RFS2 analyses. Similarly, Global Insight predicts these higher yield technologies will be implemented in other large soybean

- producing countries, such as Brazil and Argentina. If highe r yields than modeled for RFS2 indeed are realized, then it is likely that the price increases for soybean oil will be less than estimated for RFS2. Likewise, other price impacts, such as those on food prices, will still move in the same direction (i.e., an increase in price resulting from an increase in demand) but could be smaller than in the RFS2 analysis.

For the analyses performed for the RFS2 final rule, EPA estimated a $10 per person per year increase in food costs due to the total annual impact of the RFS2 program by 2022 compared to a Reference case that assumed no RFS2 renewable fuel requirements. Again, the biodiesel impacts will represent only a small portion of these overall impacts and will likely be

43 CARD Staff, Technical Report: An Analysis of EPA Renewable Fuel Scenarios with the FAPRI

- CARD

International Models , December, 2009. Docket #: EPA

- HQ

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- 2005

- 0161

- 3 177

44 "Biodiesel Production Prospects for the Next Decade," IHS Global Insight, March 11, 2011.*** E.O. 12866 Review

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even smaller in 2013 due to the smaller volume of feedstock required. One commenter suggested that EPA should conduct a more thorough analysis of food price impacts of this rule. EPA has conducted an analysis projecting the amount of soybean oil that will be required to meet

this mandate and the effect this will have on the prices of soybeans and soybean oil. The results of this analysis are discussed in detail in Sections III.B.3 and IV.B.1.a of this rule.

4. Air Quality

As described in the NPRM, we are relying on the analyses of renewa ble fuel impacts conducted in support of the RFS2 rule 45 to qualitatively discuss the expected air quality impacts

of a biomass

- based diesel volume of 1.28 bill gallons. The RFS2 analyses reflect EPA’s most current assumptions regarding biodiesel emission impacts. 46

In the RFS2 rule, we analyzed both changes in pollutant emissions (measured in tons) and changes in ambient air quality associated with the changes in pollutant emissions. The changes in pollutant emissions were calculated by comparing the 202 2 RFS2 renewable fuel

volumes to volumes if the RFS2 mandate were not in place (the reference scenario). 47 The analysis reflected full implementation of the RFS2 program in 2022 and accounted for impacts from multiple types of renewable fuels, of which bio diesel was only one type. Specifically, the RFS2 emissions inventory analysis assumed 1.82 bill gal of biodiesel in the RFS2 scenario compared to 0.38 bill gal of biodiesel in the reference scenario, reflecting a 1.44 bill gal increase

in biodiesel with t he rule in place.

Biodiesel emission impacts from the RFS2 rule emissions inventory analysis are presented in Table IV.A.4

- 1. A complete discussion of the emissions inventory analysis conducted for the RFS2 rule can be found in Chapter 3 of the RFS2 Re gulatory Impact Analysis (RIA). 48 These biomass

- based diesel emission impacts (which reflect a 1.44 bill gal increase in biodiesel) are all less than 1% of the total U.S. emissions inventory for each pollutant. 49 We expect the impacts of the 1.28 bill gal of biomass

- based diesel volume relative to the 1.0 bill gal statutory minimum volume (which reflect a 0.28 bill gal increase) to be smaller.

45 75 FR14670, March 26, 2010

46 U.S. EPA 2010, Renewable Fuel Standard Program (RFS2) Regulatory Impact Analysis. EPA

- 420

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- 006. February 2010. Docket EPA

- HQ

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- 0472

- 11332. Section 3.1.1.2.4

47 In the RFS2 Regulatory Impact Analysis, we analyzed the mandated 2022 RFS2 renewable fuel volumes relative to volumes required by two reference scenarios: RFS1 mandate ( 7.1 billion gallons of renewable fuels) and AEO 2007 ( 13.6 billion gallons of renewable fuels). Both reference scenarios assumed the same volume of biodiesel, so the emission and air quality impacts described in this section are the same for both reference scenarios.

48 U.S. EPA 2010, Renewable Fuel Standard Program (RFS2) Regulatory Impact Analysis. EPA

- 420

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- 006. February 2010. Docket EPA

- HQ

- OAR

- 2009

- 0472

- 11332.

49 While the national

- level emissions and air quality impacts may be small, there may still be local and regional impacts that are l arger in percentage terms. Our analysis is unable to capture this local and regional variability.*** E.O. 12866 Review

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Table IV.A.4

- 1 Biodiesel Emission Impacts of the RFS2 Renewable Fuel Volumes (1.82 bill gal) Relative to the

Ref erence Case (0.38 bill gal)
Biodiesel Impacts of RFS2 Rule Emissions Inventory Analysis (Δ 1.44 bill gal Biodiesel) Percent RFS2

Total U.S. Inventory c Upstream a
(tons) Downstream b

(tons) Total

(tons)

VOC

- 1,049

- 2,422

- 3,471

- 0.03%

CO 913

- 4,104

- 3,191

- 0.01%

NOx

- 290 1,346 1,056 0.01%

PM10 4,268

- 569 3,699 0.10%

PM2.5 632

- 315 317 0.01%

SO2 1,580 0 1,580 0.02%

NH3 4,171 0 4,171 0.10%

Benzene 10

- 30

- 20

- 0.01%

Ethanol 0 0 0 0.00%

1,3

- Butadiene 0

- 16

- 17

- 0.10%
Acetaldehyde 2

- 66

- 65

- 0.14%
Formaldehyde 1

- 182

- 181

- 0.21%
Naphthalene

- 1 0

- 1

- 0.01%

Acrolein 63

- 9 54 0.84%

a U.S. EPA 2010, Renewable Fuel Standard Program (RFS2) Regulatory Impact Analysis.

EPA

- 420

- R

- 10

- 006. February 2010. Docket EPA

- HQ

- OAR

- 2009

- 0472

- 11332. Table 3.2

- 11. Note: units in Table 3.2

- 11 were mislabeled as tons/mmBTU. Actual units are tons.

b U.S. EP A 2010, Renewable Fuel Standard Program (RFS2) Regulatory Impact Analysis.

EPA

- 420

- R

- 10

- 006. February 2010. Docket EPA

- HQ

- OAR

- 2009

- 0472

- 11332. Table 3.2

- 9.

c While the national

- level emissions and air quality impacts may be small, there may still be

local a nd regional impacts that are larger in percentage terms. Our analysis is unable to capture this local and regional variability.

The air quality analysis for the RFS2 rule used photochemical modeling to characterize primary pollutants that are emitted directly into the atmosphere and secondary pollutants that are formed as a result of complex chemical reactions within the atmosphere. Included in the air quality modeling scenarios for the RFS2 rule were large volumes of ethanol as well as other

renewabl e fuels, and the nature of these complex chemical interactions makes it difficult to determine the air quality impacts of biodiesel alone. Specifically, the RFS2 air quality analysis reflects a roughly 21 bill gal increase in ethanol, far outweighing the volume increase in biodiesel (0.43 bill gal). A complete discussion of the RFS2 air quality analysis and its limitations can be found in Chapter 3 of the RFS2 Regulatory Impact Analysis (RIA). 50

50 U.S. EPA 2010, Renewable Fuel Standard Program (RFS2) Regulatory Impact Analysis. EPA

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- HQ

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- 2009

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- 11332.*** E.O. 12866 Review

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The RFS2 air quality analysis was completed earlier than t he final emissions inventory analysis because of the length of time needed to conduct photochemical modeling. 51

, 52 The air quality analysis assumed 0.81 bill gal of biodiesel in the RFS2 scenario compared to 0.38 bill gal

of biodiesel in the reference scena rio, reflecting a 0.43 bill gal increase in biodiesel use with the rule in place. We use the 0.43 bill gal increase in biodiesel assumed in the RFS2 air quality analysis to qualitatively discuss the potential impacts of a 0.28 bill gal increase in biodies el from

this rule.

Given the small emissions impact of a 0.43 bill gal increase in biodiesel on the total U.S. emissions inventory (the basis for our air quality modeling scenarios), we expect the portion of air quality impacts attributable to a move from 1.0 to 1.28 bill gal (a 0.28 bill gal biodiesel increase) to be small enough that on a nationwide basis the air quality impact will likely not be

noticeable.

We note that Clean Air Act section 211(v) requires EPA to analyze and mitigate, to the
greatest extent achievable, adverse air quality impacts of the renewable fuels required by the RFS2 rule. We intend to investigate any potential adverse impacts from increased renewable fuel use through that study and will promulgate appropriate mitigation measur es separate from today's final rule.

5. Deliverability and Transport Costs of Materials, Goods, and Products Other Than

Renewable Fuel

EPA evaluated in the RFS2 final rule the impacts on the U.S. transportation network from

the distribution of the total additional volume of biofuels that will be used to meet the RFS2 standards. Oak Ridge National Laboratory (ORNL) conducted an analysis of biofuel transportation activity from production plants to petroleum terminals by rail, barge, and tank

truck to iden tify potential distribution constraints to help support the assessment in the RFS2

final rule. 53 The ORNL analysis concluded that the increase in biofuel shipments due to the RFS2 standards will have a minimal impact on U.S. transportation infrastructure. The majority of biofuel transportation is projected to be accomplished by rail. Nevertheless, it was estimated that the biofuels transport will constitute only 0.4% of the total freight tonnage for all commodities transported by the rail system through 2 022. 54 Given the small increase in freight

51 Emi ssions serve as inputs to the air quality modeling analysis. However, the final fuel volume assumptions (upon which the emission estimates were based) increased between the time that emissions were estimated to support the air quality modeling analysis an d the time emissions were estimated to reflect the final rulemaking.

52 The RFS2 air quality analysis reflects EPA’s most recent air quality analysis applicable to changes in renewable fuel types and volumes.

53 “Analysis of Fuel Ethanol Transportation Activ ity and Potential Distribution Constraints”, Oak Ridge National Laboratory, March 9, 2009. To simplify the ORNL analysis, biomass

- based diesel volumes were assumed to originate at the same points of production and to be shipped to the same petroleum termi nals as the ethanol projected to be used to meet the RFS2 standards. This may tend to overstate the potential impact on the transportation system from the shipment of biomass

- based diesel fuels since biomass

- based diesel production plants were projected t o be more geographically dispersed than ethanol production facilities. In any event, the simplifying assumption was assessed to have little impact on the results from the analysis given that biomass

- based diesel represented only 8% of the total projected biofuel volumes under the RFS2 final rule.

54 See sections 1.6.4 and 1.6.5 of the RFS2 RIA.*** E.O. 12866 Review

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shipments due to the transport of biofuels to meet the RFS2 standards, we believe that the distribution of biofuels will not adversely impact the deliverability and transport costs of materials, goods, and product s other than renewable fuels. There were no comments on the proposed rule to contradict this assessment.

6. Wetlands, Ecosystems, and Wildlife Habitats

As directed by CAA section 211(o)(2)(B)(ii), in setting the 2013 biodiesel volume requirements, EPA is to consider the impacts of biodiesel production and use on wetlands, ecosystems and wildlife habitat. No specific public comments on these impacts were received, so the following updates the largely qualitative analyses provided in the proposal.

The most complete and up

- to

- date assessment of these impacts is contained in the analysis prepared by EPA in response to the requirements set out in CAA section 204. This report to Congress considers a range of impacts but the focus of the discussion here is on wetlands, ecosystems and wildlife habitats as directed by the CAA amendments. This report does not attempt to quantify the impacts of biofuel production and use as these impacts are dependent on local or regional conditions. Nevertheless the analy ses contained in the report provide qualitative assessments and reasonable expectations of trends which can be used to consider the environmental impacts of increases in biodiesel production and use. These trends are only summarized here while the final r eport provides extensive detail. 55

The assessment focuses on the use of oil from soybeans as the feedstock for biodiesel production. Other oil seed feedstock sources represent a very small portion of biofuel production in 2013 so will be expected to have much less of an impact than soy oil. Corn oil extracted during the ethanol production process is increasing, adding a small increment of supply for biofuel production by 2013 that will offset demands for soy and other oil seed crops, thus reducing po tential agricultural impact of biodiesel production. Corn as a feedstock for biofuel production is driven primarily by the demand for corn ethanol, not the demand for the corn

ethanol co

- product of extracted, non

- food grade corn oil. Therefore the impact of the supply of extracted corn oil is not considered here. Finally, waste fats, oils and greases are expected to have negligible environmental impact as a feedstock since they do not impact agricultural land

use and would otherwise be used for some lowe r value purpose or simply discarded.

Wetlands can be adversely affected by agricultural production through runoff that can result in nutrient loading (particularly from fertilizers) or from sedimentation (from erosion). Soy production tends to use less fertilizer than corn production (the most likely alternative crop) and can reduce the amount of fertilizer required for corn when planted in rotation with corn. However, compared to other crops, erosion can be higher from fields planted in row crops such as corn and soy beans. While the impacts of nutrient loading and erosion tend to be site specific, good farming practices including the optimum fertilizer use and the set aside of sensitive lands via the Conservation Reserve Program (CRP) can significant ly help control these adverse affects. Wetlands can also be adversely affected through diversion of surface and ground water for

55 U.S. EPA (Environmental Protection Agency). February 2012. “Biofuels and the Environment: First Triennial Report to Congress.” Office of Research and Development, Washington, DC. EPA/600/R

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agricultural irrigation. Soybean production less frequently relies on irrigation than corn and some other crops. More discus sion on water usage is included below in the section on water use and water quality impacts.

Ecosystems and wildlife habitat can be adversely affected if CRP lands are converted to crop production, if row crops such as soybeans replace grassy crops and in general if new lands with diverse vegetation are converted to crop production. As explained in the RFS2 final rule, we do not expect the RFS program production to result in an increase in total acres of agricultural land under production in the US com pared to a reference case without the impact of the RFS2 volumes. The relatively small increase of 0.28 bill gall should not appreciably affect the amount of land devoted to oil seed production. Additionally, the USDA commitment to support the CRP progra m should minimize the likelihood of any significant change in the amount of CRP land. Therefore, while some very local changes may result due to individual farmer’s planting decisions, since no new crop land are expected in the U.S. due to this increase

i n the biomass

- based diesel standard and sensitive lands will be protected via programs such as CRP, no measureable impact in aggregate ecosystems or wildlife habitat due to cropland expansion is expected.

Increased water withdrawals for soy biodiesel pro duction can lead to more frequent low

flow conditions that reduce the availability for aquatic habitat. Additionally, waste water from biodiesel production can adversely affect surface water quality if not properly treated.

7. Water Quality and Quantit y

The water quality and quantity impacts of biodiesel are primarily related to the type of feedstock and the production practices used both to produce the feedstock and to convert the feedstock into biodiesel. Soybeans are the principal feedstock used f or biodiesel production and are predicted to account for 600 million gallons of the 1.28 billion gallons evaluated for 2013.

Non

- food grade corn oil extracted during ethanol production, animal fats and recycled fats account for most of the remaining biodi esel feedstock. Since these fats and greases are the byproduct of another use and are not produced specifically for biodiesel manufacture, their production and primary use is not related to the level of biodiesel so their indirect impacts are not

consider ed here. While non

- food grade corn oil is extracted for its use as a feedstock for biodiesel production, it is a by

- product of corn ethanol production. The corn used for biofuel production is primarily grown for the purpose of producing ethanol, not as a source of extracted

non

- food grade oil so the water impacts of corn production are primarily a concern for ethanol produced from the corn starch, not the by

- product of extracted corn oil. Thus, this analysis will focus on soybeans as a primary source of vegetable oil used in biodiesel production. No specific public comments on these impacts were received so the following discussion updates the analyses provided in the proposal.

From a water quality perspective, the primary pollutants of concern from soyb ean production are fertilizers (nitrogen and phosphorus) and sediment. Additional pollutants such as from pesticides have the potential to impact water quality to a lesser degree. There are three major pathways for these potential pollutants to reach wat er from agricultural lands: runoff from*** E.O. 12866 Review

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the land’s surface, subsurface tile drains, or leaching to ground water. Climate, hydrological, and management factors influence the potential for these contaminants to reach water from agricultural lands.

a. Imp acts on Water Quality and Water Quantity Associated with Soybean

Production

After corn, soybeans are the second largest agricultural crop in terms of acreage in the U.S. In 2010, American farmers planted 77.7 million acres of soybeans and harvested 3.4 billion bushels. As with the production of any agricultural crop, the impact on water quality depends on a variety of factors including production practices, use of conservation practices and crop rotations by farmers, and acreage and intensity of tile dr ained lands. Additional factors outside agricultural producers’ control include soil characteristics, climate, and proximity to water

bodies.

Soybeans are typically grown in the same locations as corn since farmers commonly rotate between the two crops. Nutrients are applied to fewer soybean acres than corn and at much lower rates because soybean is a legume. 56 Legumes have associations in their roots with bacteria that can acquire atmospheric nitrogen and convert it into bio

- available forms, reducing

th e need for external addition of nitrogen fertilizer. However, losses of nitrogen and phosphorus from soybeans can occur at quantities that can degrade water quality. 57 In 2006, USDA’s NASS estimated that nitrogen was applied to 18 percent of the 2006 soybe an planted acres in the Program States at an average rate of 16 pounds per acre per year. Phosphate was applied to 23 percent of the planted acres, at an average rate of 46 pounds per acre (NASS, 2007). 58 The quantity of nitrogen fertilizer applied to soy bean fields ranged from 0 to 20 pounds per acre, while the quantity of phosphate ranged from 0 to 80 pounds per acre. As with corn, the conversion of idled acreage to soybeans is estimated to result in losses of nitrogen and phosphorus from the soil throug h cultivation. 59

Agricultural conservation systems can reduce the impact of soybean production on the environment. The systems components include 1) controlled application of nutrients and pesticides through proper rate, timing, and method of application, 2) controlling erosion in the field (i.e., reduced tillage, terraces, or grassed waterways), and 3) trapping losses of soil and fertilizer runoff at the edge of fields or in fields through practices such as cover crops, riparian buffers, controlled draina ge for tile drains, and constructed/restored wetlands. 60

56 U.S. EPA (United States Environmental Protection Agency). Renewable fuel standard program (RFS2) regulatory impact analysis. EPA

- 420

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- 006. Available at: http://www.epa.gov/otaq/renewablefuels/420r10006.pdf

. 57 Dinnes, DL; Karlen, DL; Jaynes, DB; Kaspar, TC; Hatfield, JL; Colvin, TS; Cambardella, CA. 2002. Nitrogen management strategies to reduce nitrate leaching in tile

- drained midwestern soils. Agrono my Journal 94(1): 153

- 171.

58 NASS (United States Department of Agriculture, National Agricultural Statistics Service). 2007. Agricultural chemical usage 2006 field crops summary. Ag Ch 1 (07)a. Available at: http://usda.mannlib.cornell.edu/usda/nass/AgriChemUsFC//2000s/2007/AgriChemUsFC

- 05

- 16

- 2007_revision.pdf

. 59 Simpson, TW; Sharpley, AN; Howarth, RW; Paerl, HW; Mankin, KR. 2008. The new gol d rush: Fueling ethanol production while protecting water quality. Journal of Environmental Quality 37(2): 318

- 324.

60 Dinnes, DL; Karlen, DL; Jaynes, DB; Kaspar, TC; Hatfield, JL; Colvin, TS; Cambardella, CA. 220 2002. Nitrogen management strategies to red uce nitrate leaching in tile

- drained 221 midwestern soils. Agronomy Journal 94(1): 153

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The effectiveness of conservation practices, however, depends upon their adoption. The USDA‘s Conservation Effects Assessment Project (CEAP) quantified the effects of conservation practices used on cultivated cropland in the Upper Mississippi River Basin. It found that, while erosion control practices are commonly used, there is considerably less adoption of proper nutrient management to mitigate nitrogen loss to water bodies. 61 However, as noted ab ove, the relatively low amount of fertilizer used for soy bean production tends to lessen the potential for nitrogen loss to water bodies. Additionally, soybean production can reduce the amount of biomass left on the field compared to a corn case where mu ch of the stover is left to protect the soil and enhance biomass content. In such a case, there could be more soil erosion with soybean production compared to corn production and potentially greater nutrient runoff. Proper soil management can reduce this erosion concern.

Water for soybean cultivation predominately comes from rainfall, although about 11 percent of soybean acres in the U.S. are irrigated. 62 Water use for irrigated soybean production

in the U.S. varies from 0.2 acre

- feet per acre in Pen nsylvania to about 1.4 acre

- feet per acre in Colorado, with a national average of 0.8 acre

- feet of water. 63 Water used for irrigation is at least temporarily not available for other uses and if pumped from deep aquifers, may not return to those aquifers fo r centuries

There is some concern that the demand for corn and soybeans as biofuel feedstocks may lead to high prices of these commodities, inducing farmers with land currently enrolled in USDA’s CRP to return to intensive agricultural production (e.g., Secchi et al., 2009). 64 The CRP provides farmers with financial incentives to set aside a certain portion of their cropland in order to conserve or improve wildlife habitat, reduce erosion, protect water quality, and support other environmental goals. Biomass produced from CRP lands is considered “renewable biomass” as defined under the RFS regulations and is therefore eligible for use in the production of renewable fuel under the RFS program. The Food, Conservation, and Energy Act of 2008 (known as the Farm Bill) cappe d CRP acreage at 32 million acres, reducing enrollment by 7.2 million acres from the 2002 Farm Bill with the potential for making more acreage available for the production of row crops. However, even if the aggregate total of CRP protected lands does

not change significantly , individual farmers have the opportunity to move specific land in and

out o f CRP such that the specific lands in the program do not necessarily remain fixed. Historically, land entering and exiting the CRP program has been more vulnerable to erosion than other cultivated land, but also less productive. 65 So while the conversion of a specific piece

61 U.S. Department of Agriculture, National Resources Conservation Service. 2010. Assessment of the effects of conservation practices on cultivated cropland in the U pper Mississippi River Basin. Available at: http://www.nrcs.usda.gov/technical/NRI/ceap/umrb/index.html

. 62 U.S. Department of Agriculture. 2010. 2007 Census of agriculture, Farm and ranch irrigation survey (2008). http://www.agcensus.usd a.gov/Publications/2007/Online_Highlights/Farm_and_Ranch_Irrigation_Survey/fris08.pdf

63 U. S. Department of Energy. 2006. Energy demands on water resources: Report to Congress on the interdependency of energy and water. Available at: http://www.sandia.gov/energy

- water/docs/121

- RptToCongress

EWwEIAcomments

- FINAL.pdf

64 Secchi, S; Gassman, PW; Williams, JR; Babcock, BA. 2009. Corn

- based ethano l production and environmental quality: A case of Iowa and the conservation reserve program. Environmental Management 44(4): 732

- 744.

65 ERS (United States Department of Agriculture, Economic Research Service). 2008. 2008 farm bill side

- by

- side.

Available a t: http://www.ers.usda.gov/FarmBill/2008/Titles/TitleIIConservation.htm#conservation

. Deleted: As noted earlier,

Deleted: USDA’s position is to support

ma intaining 32 million acres

Deleted: so in aggregate we do

Deleted: expect significant changes in the amount

of land in CRP. However*** E.O. 12866 Review

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of land from CRP to intensive feedstock production is possible, such a land use conversion is less likely than land already in crop production given practical economic and agronomic

considerations

.

b. Impacts on Water Quality and Water Quantity Associated with Biodiesel

Production

Biological oxygen demand (BOD), total suspended solids, and glycerin pose the major water quality concerns in wastewater discharged from biodiesel facilities. Actual impacts depend on a range of factors, incl uding the type of feedstock processed, bio

- refinery technology, effluent controls, and water re

- use/recycling practices, as well as the facility location and source and receiving water. Discharge water quality requirements of local and regional government s can help assure best control practices and reduce water quality concerns.

Despite the existing commercial market for glycerin and the likely expanded uses for glycerin as mentioned in the RFS2 final rule, the rapid development of the biodiesel industry has caused a glut of glycerin production, resulting in many facilities disposing of glycerin. Glycerin disposal may be regulated under several EPA programs, depending on the practice. However, there have been instances of glycerin dumping, including an inc ident in Missouri that resulted in a large fish kill. 66 Some biodiesel facilities discharge their wastewater to municipal wastewater treatment systems for treatment and discharge. There have been several cases of municipal wastewater treatment plant upsets due to high BOD loadings from releases of glycerin. 67 BOD can lead to methane emissions during the water treatment process. To mitigate wastewater issues, some production systems reclaim glycerin from the wastewater. Closed

- loop systems in

which water an d solvents can be recycled and reused can reduce the quantity of water that must be pretreated before discharge. Others employ anaerobic digesters to mitigate the release of methane to the atmosphere.

Biodiesel can also impact water bodies as a result o f spills. However, biodiesel degrades approximately four times faster than petroleum diesel including in aquatic environments. 68
Results of aquatic toxicity testing of biodiesel indicate that it is less toxic than regular diesel. 69

Biodiesel does have a h igh oxygen demand in aquatic environments and can cause fish kills as a result of oxygen depletion. Water quality impacts associated with spills at biodiesel facilities generally result from discharge of glycerin, rather than biodiesel itself.

Biodiesel facilities use much less water than ethanol facilities to produce biofuel. The primary consumptive water use at biodiesel plants is associated with washing and evaporative processes. Water use is variable but is usually less than one gallon of w ater for each gallon of

66 U.S. EPA. 2010b. Renewable fuel standard program (RFS2) regulatory impact analysis. EPA

- 420

- R

- 10

- 006.

Available at: http://www.epa.gov/otaq/renewablefuels/420r10006.pdf

.. 67 U.S. EPA. 2010b. Renewable fuel standard program (RFS2) regulatory impact analysi s. EPA

- 420

- R

- 10

- 006.

Available at: http://www.epa.gov/otaq/renewablefuels/420r10006.pdf

.. 68 Kimble, J. n.d. Biofuels and emerging issues for emergency responders. U.S. EPA. Available at: http://www.epa.gov/oem/docs/oil/fss/fss09/kimblebiofuels.pdf

. 69 Kahn, N; Warith, MA; Luk, G. 2007. A comparison of acute toxicity of biodiesel, biodiesel blends, and diesel on aquatic organisms. Journal of the Air and Waste Management Association 57(3): 286

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biodiesel produced; some facilities recycle wash water, which reduces overall water consumption. 70

8. Job Creation and Rural Economic Development

The Energy Independence and Security Act (EISA) requires analyses of, among other

f actors, the impact of renewable fuel use on “...job creation [and] rural economic development...” to help inform each annual determination of applicable volumes. In the RFS2 final rule, we anticipated employment to increase and income to expand in rural areas and farming communities as a result of the increased use of renewable fuel. Income expansion in rural areas from renewable fuel production will contribute to rural economic development. As mentioned above, industry activities are currently progressing, ramping up biodiesel production from the approximately 0.38 bill gallons estimated to have been used in the U.S. in 2010 to over 1.0 bill gallons that was produced in 2011. This increase in biodiesel production was in large part due to bringing on line ex isting capacity idled due to lack of demand, a trend that we expect

will continue into the near future.

Employment impacts of federal rules are of particular concern in the current economic climate of sizeable unemployment. The recently issued Executi ve Order 13563, “Improving Regulation and Regulatory Review” (January 18, 2011), states, “Our regulatory system must protect public health, welfare, safety, and our environment while promoting economic growth, innovation, competitiveness, and job creation ” (emphasis added). Executive Order 13563 also states that “[i]n applying these principles, each agency is directed to use the best available techniques to quantify anticipated present and future benefits and costs as accurately as possible”
and that “...e ach agency may consider (and discuss qualitatively) values that are difficult or impossible to quantify...” Consistent with the Executive Order, and consistent with recent efforts to characterize the employment effects of economically significant rules, the Agency has provided this analysis to inform the discussion of labor demand and employment impacts in rural areas and farming communities. Estimates of this particular rule’s effects on labor markets beyond the biodiesel production sector are “difficult or impossible to quantify” to an acceptable degree of accuracy using currently available methodologies, Therefore, the Agency has not quantified the rule’s effects on labor in other sectors, including conventional diesel production and sales, nor has the age ncy attempted to estimate the effects induced by changes in workers’ incomes or changes in food and fuel prices.

When the economy is at full employment, an environmental regulation is unlikely to have much impact on net overall U.S. employment; instead, labor would primarily be shifted from one sector to another. These shifts in employment impose an opportunity cost on society, approximated by the wages of the employees, as regulation diverts workers from other activities in the economy. In this situation, any effects on net employment are likely to be transitory as workers change jobs (e.g., some workers may need t o be retrained or require time to search for new jobs, while shortages in some sectors or regions could bid up wages to attract workers).

70 Renewable Fuels Standard Program (RFS2), Regulatory I mpact Analysis (RIA). EPA

- 420

- R

- 10

- 006. Available

at: http://www.epa.gov/otaq/renewablefuels/420r10006.pdf

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On the other hand, if a regulation comes into effect during a period of high unemployment, a change in labor deman d due to regulation may affect net overall U.S. employment because the labor market is not in equilibrium. Schmalansee and Stavins point out that net positive employment effects are possible in the near term when the economy is at less than full employmen t due to the potential hiring of idle labor resources by the regulated sector to meet new requirements (e.g., to install new equipment) and new economic activity in sectors related to the regulated sector. 71 In the longer run, the net effect on employment is more difficult to predict and will depend on the way in which the related industries respond to the regulatory requirements. For this reason, Schmalensee and Stavins urge caution in reporting and interpreting partial employment effects since it can “pa int an inaccurate picture of net employment impacts if not placed in the broader economic context.”

This rule is expected to primarily affect employment in the United States through the biodiesel plants and distributors, and through several related secto rs, specifically, industries that supply inputs in the production of biodiesel. To provide a partial picture of the employment consequences of this rule, EPA investigated the expected consequences for rural areas and farming communities. Assuming the curr ent average of 30 to 40 people to operate a biodiesel plant of 30 million gallons (a typical capacity for a standalone transesterification plant), an expansion of 280 million gallons is the equivalent of adding about 4 plants representing the

addition of a round 350 direct jobs for biodiesel production 72 . Providing soy oil feedstock would require an estimated 120 additional truck trips per day or an addition of 120delivery drivers per day assuming one trip per delivery truck per day to account for driving and loading / unloading time. 73 Expansions to the fuel distribution infrastructure (i.e., more fuel terminals, rail cars, tank trucks, barges etc.) would also be needed to support the use of an additional 280 million gallon increase in the 2013 volume requ irement for biomass

- based diesel. Necessary support to a functioning biodiesel plant such as the delivery of methanol to allow processing of vegetable oil into biodiesel as well as additional handling at biodiesel distribution centers will

also add direct ly to the employment impacts.

Most large biodiesel plants in the U.S. are located in rural communities near feedstock (soybean oil or corn oil) sources. Urban biodiesel plants tend to be smaller with more diffuse feedstock suppliers. In 2011, approxi mately 71 percent of biodiesel producers were located in rural areas, defined as towns of less than 50,000. A 30 million gallon per year (MGY) biodiesel plant will spend nearly $140 million on goods and services with feedstocks accounting for more

than 80 percent of expenditures. 74 The size of the economic impact on the local economy of spending by an individual biodiesel plant will depend on location (e.g., state) and how much feedstock is sourced locally.

In addition to the employment effects from increased biodiesel production, this rule would also result in reductions in conventional diesel fuel use, which could affect employment in

71 Schmalensee, Richard, and Robert N. Stavins. “A Guide to Economic and Policy A nalysis of EPA’s Transport Rule.” White paper commissioned by Excelon Corporation, March 2011 ( Docket EPA

- HQ

- OAR

- 2010

- 0799 ).

72 Presentation from National Biodiesel Board, “Biodiesel Forecasts, Infrastructure, and Economic Impacts”, February 14, 2012.

73 Ib id.

74 Ibid.*** E.O. 12866 Review

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the diesel fuel supply chain. The loss of expenditures to diesel fuel suppliers throughout the diesel fuel supply c hain, from the petroleum refiners to diesel fuel distributors, is likely to result in some loss in employment in these sectors. The potential impacts on the diesel industry and other sectors of the economy are not quantified in this analysis because availa ble data and methodologies are insufficient to support reasonably accurate estimates of the incremental employment effects of this rule.

To summarize, we anticipate that bringing idle biodiesel plants back online and expanding biodiesel distribution infr astructure in the U.S. will increase employment in the renewable fuels and related industries and promote rural economic development. These increases in employment are similar to what we anticipated when we analyzed the volume requirements in RFS2 final r ule. These employment impacts may be offset to some degree by decreases in other sectors and/or locations (e.g., from the reduced production and transport of conventional diesel fuel); however sufficiently reliable data and a satisfactory methodology

supp orting quantitative evaluation of the employment impacts beyond the biodiesel sectors are not currently available.

One commenter raised the issue of the impacts of the potential increased use of animal fats to produce biodiesel under a 1.28 bill gallon r equirement on employment within the oleochemical industry. According to the commenter, with renewable fuel production consuming an increasingly significant amount of the total supply of animal fats produced in the U.S., this may limit the availability of animal fats for oleochemical production. According to the commenter, the price of animal fats recently exceeded the price of Malaysian palm oil. If the oleochemical industry switched to palm oil as a feedstock to make its products and located near palm o il supply, there could be a possible loss of U.S. employment in this industry.

As the commenter pointed out, we cannot prevent any feedstocks from being used to produce RIN

- generating renewable fuel if they meet the regulatory definition of renewable biomass and are otherwise valid. Nevertheless, while Table III.B

- 1 lists grease and fats as one likely source of feedstocks for the production of biomass

- based diesel, we noted in Section III.B

that there could be sufficient sources of other feedstocks to produce 1.28 bill gallons of biomass

based diesel without using any animal fats. The comment implies that feedstock used in the oleochemical industry depends significantly on relative costs which can vary over time in part due to changes in demand. The cost of animal fat is dependent on the general demand for this material which is only in part impacted by its potential use as a biofuel feedstock. The general supply of animal fat is not expected to be impacted significantly by its alternative use as a

b iofuel feedstock or the range of other uses of this material. Thus the choice of feedstock(s) used by the oleochemical industry already depends on market prices of multiple feedstock sources. Since feedstock such as rendered fats or, as suggested by the c ommenter, palm oil are readily marketed and transportable, we do not expect the industry to relocate production every time feedstock market conditions change. Therefore we do not believe production facility location will be significantly impacted by the p otential use of rendered fats as a biofuel feedstock if some portion of the 280 million gallon increase in the biomass

- based diesel standard is produced from

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B. Consideration of Applicable Statutory Economic Factors

The RFS program established by Congress is primarily a long

- term program aimed at replacing substantial volumes of fossil

- based transportation fuels with low GHG renewable fuels

over time. Congress established a list of factors to be considered in setting the annual biomass

diesel mandate, and these factors include consideration of some aspects of economic costs and some aspects of economic benefits (among other impacts and factors), though there is no explicit net benefit criterion required by the statute. In the final rulemaking for the RFS2, EPA assessed the costs and benefits of this program as a whole when the program was fully mature, which we continue to believe is the appropriate approach to examining the costs and benefits of a long term program like the RFS2. However, the annual standard

- setting process is part of the program.

The annual standard

- setting process encourages consideration of the program on a piecemeal (i.e., year to year) basis , which may not reflect the long

- term economic effects of the program.

EPA received comments requesting that we consider costs and benefits for the 1.28 billion gallon biomass

- based diese l mandate in 2013. This mandate is an interim step within the larger RFS program, so any examination of short

- term impacts separate from that larger effort must be kept in context. Further, many of the impacts of this rule are difficult to fully quantify

, which makes any comprehensive consideration of costs and benefits difficult to undertake in the limited timeframe of the RFS annual rule. In spite of these limitations, EPA has analyzed some of the costs and has estimated the monetary value of some of t he benefits of the 2013 biomass

based diesel mandate to provide more information on this rulemaking.

In this section, we provide estimates of some costs and benefits for the year 2022, when the RFS2 legislative requirements will be fully implemented and the program is more mature. We also provide estimates of the costs and benefits of the 1.28 bill gal volume requirement for the year 2013, the year in which we are setting the biomass

- based diesel volume mandate at 1.28 bill gal. The statute is forward

- lo oking in that it created a program whose energy and environmental benefits are intended to grow over time; to evaluate the program on the basis of only one early year’s impacts, as part of near

- term implementation, would be to paint an

unbalanced and incom plete picture. For example, as we examine the costs of the program through time, we see that these costs fall steadily. This is due to two key factors: the cost of petroleum, the basic raw material of diesel fuel, rises through time. Meanwhile, the princ ipal cost of soybean

- based biodiesel, the soybean oil feedstock, tends to fall though time. For example, the AEO 2012 Early Release (AEO12 ER) projects that oil prices rise from roughly $103 per barrel in 2013 to $129 per barrel in 2022, a 25 percent incr ease. 75 The AEO 2011 High Oil Price case (AEO11 HOP), projects that oil prices will increase to about $179 per barrel, a 73 percent increase. 76 According to EPA’s projections performed for this rule and USDA long

- term projections, soy oil prices will decrea se from $0.45/lb in 2013 to $0.42/lb in 2022, a 6 percent

decrease. 77 As a result, the relative cost difference between diesel and biodiesel fuel tends to

75 U.S. Department of Energy, Energy Information Administration. 2012. Annual Energy Outlook 2012 (Early Release). Available at: http://www.eia.gov/forecasts/aeo/er/

. 76 U.S. Department of Ene rgy, Energy Information Administration. 2011. Annual Energy Outlook 2011. Available

at: http://www.eia.gov/forecasts/aeo/data.cfm#enprisec

. 77 U.S. Department of Agriculture, Economic Research Service, Agricultural Long

- Term Projections , February

2012. Deleted: Quantifiable Costs and Benefits

Deleted: instead of a holistic one, though doing so creates an incomplete understanding of the program’s impacts.*** E.O. 12866 Review

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narrow through time as the program reaches maturity. Thus, we do not just look at the impacts

of the program in any one year, but also look at the impacts at a point of greater program maturity.

1. Monetized Quantifiable Costs

Our analysis of costs focuses on the sector most likely to be impacted by an increase in

biomass

- based diesel volumes

– the agricultural commodity market. To assess some of the impacts of the 1.28 billion gallon biodiesel mandate, EPA used a stochastic economic model developed by the Center for Agricultural and Rural Development (CARD) at Iowa State University to conduct this analysis. The CARD stochastic model approximates U.S. and Brazilian biofuel production, consumption, and trade. Using a relatively small set of input assumptions about petroleum prices, commodity yields, and ethanol production, the CARD

model examines wh at the U.S. and Brazilian biofuels markets may look like under different combinations of parameters (e.g., low petroleum prices, low soybean yields, and high Brazilian ethanol production).

The model shows the probability of different outcomes by running 500 different potential scenarios. This modeling approach provides a range of estimates which helps to bound uncertainty about possible impacts on the biofuels sector. Analysis of this range can indicate which outcomes are more likely than others and als o provide a sense of the possible high and low estimates that should be considered for a given variable. The CARD model projects ranges for commodity yields and prices, fuel volumes and prices, and several other variables. For the

biomass

- based diesel st andard, EPA analyzed the cost of mandating an additional 280 million gallons for biodiesel in 2013, going from 1.0 billion gallons of biomass

- based biodiesel to 1.28 billion gallons. For purposes of this analysis, EPA assumed that the additional 280 milli on gallons of biodiesel we are mandating for 2013 will be entirely soybean

- based and would not otherwise be produced. As we outline in Section III.B of this rulemaking, most of the additional 280 million gallons is likely to be soybean

- based, but other so urces are possible. Because soybean oil feedstock is more expensive than corn oil or waste feedstock, the cost impact of the extended volume requirement would decrease if biodiesel production from these other sources expands. We therefore consider the co st projections presented below to be potentially high

estimates.

a. Impact on the Cost of Soybean Oil

One commenter suggested that the biodiesel mandate for 2013 will result in an increase of soybean oil prices. In response to this comment and other re lated comments, EPA modeled the change in soybean oil prices in 2013 using the CARD stochastic model. Assuming that the 280 million gallon increment is met entirely with soybean oil biodiesel in 2013, EPA estimates that the price of soybean oil will be $0 .45 per pound (in 2010$) under this mandate, compared to approximately $0.42 under a 1.0 billion gallon mandate (see Section III.B of this rule for further discussion of feedstock availability and prices). The mandate is estimated to increase feedstock

co sts of soybean

- based biodiesel by about $0.22 per gallon of biodiesel. The effect of this increase on the cost of the additional 280 million gallons is incorporated into the estimates in

section IV.B.1.b.*** E.O. 12866 Review

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Given that the CARD stochastic model is not desi gned to estimate long

- run impacts, we do not attempt to estimate the impacts of the 2013 biomass

- based biodiesel volume requirement on the price of soybean oil in 2022. In Section III.B.3 of this rule, we estimate that this proposed mandate will raise soy bean oil prices by approximately 7 percent in 2013. The international market for vegetable oils is large and diverse, with considerable capacity to absorb short

- term demand increases. It is therefore unlikely that an increase in U.S. demand for soybean o il of this size in 2013 would significantly affect prices nine years in the future. Therefore, in lieu of projecting soybean oil prices in 2022, we are utilizing USDA’s 2012 Long

- Term Agricultural Projections of soybean oil prices. USDA estimates that th e price of soybean oil will be $0.42 per pound (in 2010$) for the 2021/2022 crop year (the last year for which USDA provides estimates in their long

- term projections as of this writing). 78

b. Cost of Displacing Petroleum

- Based Diesel with Soybean

- Based Bio diesel

Producing an additional 280 million gallons of biodiesel will displace approximately 255 million gallons of petroleum

- based diesel. Since biodiesel costs more to produce in the U.S. than diesel, this displacement has associated costs. In this an alysis, we compare the cost of biodiesel and petrodiesel at the wholesale stage, since that is when the two are blended together. Therefore, this analysis does not consider taxes, retail margins, and any other costs and transfers

that occur at or after th e point of blending.

On this basis, EPA estimated the cost of producing and transporting a gallon of biodiesel to the blender. For soybean

- based biodiesel, soybean oil feedstock costs generally represent the majority of the overall cost, usually somewhe re between 70 and 90 percent. The soybean oil price estimates discussed in Section IV.B.1.a of this rule therefore had a strong impact on EPA’s cost estimates, though estimates of distribution and other production costs were also important. Estimating th e cost to produce biodiesel and transport it to the blender presents considerable uncertainties, even in the near term. Unforeseen fluctuations in the prices of oil, for example, could have a very significant effect. Therefore, instead of presenting a p oint estimate, EPA has chosen to present a range of estimates for 2013 and 2022 that reflects uncertainty associated with the oil and feedstock prices at the 1.28 bill gal level that we are finalizing.

After estimating the cost of biodiesel at the wholes ale stage, EPA compared that to what it would cost to consume an equivalent amount of petroleum

- based diesel instead. The Department of Energy’s Energy Information Administration (EIA) publishes two regular reports

that make estimates of wholesale diesel prices in 2013. In 2013, costs are on the low

- end of the range if we use the wholesale diesel estimate from DOE’s most recent Short

- Term Energy Outlook (STEO). 79 The high

- end estimate utilizes DOE’s AEO12 ER wholesale diesel

estimate. 80 Both estimates are relevant for an analysis of fuel prices in 2013. On this basis, we

78 U.S. Department of Agriculture. 2012. USDA Long

- Term Agricultural Projections. Available at: http://usda.mannlib.cornell.edu/MannUsda/viewStaticPage.do?url=http://usda.mannlib.cornell.edu/usda/ers/94005/./

2012/index.html

. 79 U.S. Department of Energy, Energy Information Administration. 2012. Shor t Term Energy Outlook, March

2012. Available at: http://www.eia.gov/forecasts/steo/index.cfm

. 80 U.S. Department of Energy, Energy Information Administration. 2012. Annual Energy Outlook 2012 (Early Release). Available at: http://www.eia.gov/forecasts/aeo/er/

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estimate the increase in the cost of fuel for 280 million gallons of biodiesel will be between $0.91 and $1.36 per gallon in 2013. This translates into total cost estimates of $253 milli on to $381 million from increased fuel cost in 2013.

Table IV.B.1.b

- 1 Estimated Increase in Wholesale Cost of Biodiesel in Comparison to Petrodiesel in 2013 and 2022 (in 2010 dollars)

Estimate for 2013 Estimate for 2022

Petroleum Assumption STEO March

2012 AEO 2012

Early Release AEO 2011

High Oil Price AEO 2012

Early Release

Difference in biodiesel production cost (per gallon) $0.91 $1.36

- $0.70 $0.41

Cost of 280 million gallons $253 million $381 million

- $195 million $116 million

We also present a range of estimates for the year 2022. The upper estimate utilizes the

AEO 2012 ER. The lower estimate utilizes the AEO 2011 High Oil Price (HOP) case’s wholesale diesel estimate. The STEO does not currently provide projections for the year 2022 and the AEO 2012 Early Release does not include the high oil price case (at the time of this writing the full A EO 2012 has not been released). In lieu of these, the AEO 2011 HOP is the best available estimate of a higher diesel cost in 2022. Based this range of data and on USDA’s long

- term projection of soybean oil prices, we estimate the incremental increase in fuel costs associated with this proposed volume requirement will be between

- $0.70 and $0.41 per gallon in

2022. This translates to a cost of

- $195 million to $116 million from increased fuel costs in 2022. The low end of this estimate is negative becaus e with higher oil costs, biodiesel is less expensive than petroleum

- based diesel

.

Consistent with our previous work in this area, EPA’s quantifiable cost methodology is a
“bottom

- up” engineering cost analysis that estimates the cost to produce a gallon of soybean

based biodiesel and then compares that cost to the production cost of an energy

- equivalent gallon of petroleum

- based diesel. In certain situations, it may also be useful to use a “top down” analyses to estimate the potential cost of a program to society. In the case of the biomass

- based diesel standard, one suggestion was to look at the RIN price as a proxy for the societal cost of the

program.

RIN prices reflect the incremental private marginal cost of blending BBD into the diesel fuel pool. As noted by Professor Bruce Babcock, of Iowa State University:

“The market for RINs is an effective and efficient way to enforce the mandates. Motor fuel producers who find that biofuel is too difficult to access or to blend buy RINs

instead. Fuel prod ucers who have ready access to biofuels and find it profitable to blend

biofuels sell their excess RINs. By making RINs tradable, the mandates are met at the lowest possible cost.” 81

81 Babcock, B, Mandates, Tax Credits, and Tariffs: Does the U.S. Biofuels Industry Need Them All? Iowa State University, Center for Agricultural and Rural Development, Policy Brief 10

- PB

- 1, March 2010. p. 4

- 5 Deleted:

- $1.36

Inserted Cells Deleted:

- $0.41

Inserted Cells

Deleted:

- $381

Deleted:

- $116

Deleted: bound of our cost estimates

Deleted: low end of this range*** E.O. 12866 Review

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However, we have concerns with using RIN prices to estimate the costs to society of the

biomass

- based diesel RFS2 requirement. First

, RIN prices are more representative of marginal costs. If producers have different costs of production, as they do in the biodiese l market, using the marginal cost of compliance as a proxy for cost of production will significantly overestimate the cost to society. Second , it is difficult to have confidence in the use of historical RIN price trends as an indicator of future program cost . Key factors limiting EPA’s confidence in RIN price as a proxy measure for social cost include the effect of observed instability and uncertainties in U.S. tax policy, import tariff policies, and other possible inefficiencies in RIN

markets. 82 Finally, other factors, such as the existence of multiple RIN vintages in any given year and the aforementioned uncertainties, can create significant incentives for potential speculation in the RIN markets

. In their 2011 repor t on RINs, USDA observed that this speculation results in RIN prices that are somewhat higher than the cost of biodiesel, though the exact amount of this increment is extremely difficult to quantify. 83

c

. Transportation Fuel Costs

In the NPRM, we cited cost estimates that we had developed in the RFS2 final rule. In response to comment, we have revised ou r methodology for examining the effect of this mandate on the cost of transportation fuel. The estimates described in Section IV.B.1 above represent the quantifiable costs to society as a whole stemming from our increase in the biomass

- based diesel

volume requirement from 1.0 bill gal to 1.28 bill gal. These estimates do not include certain transfers, such as those between buyers and sellers of diesel fuel

. For this reason, the increase in the cost of transportation fuel from a so cietal perspective is different from the increase from the perspective of individual buyers and sellers of fuel. However, these costs do impact the retail price of diesel and associated economic impacts for fuel consumers

.

To estimate the increase in th e cost of transportation fuel associated with today's mandate for 1.28 bill gal in 2013 and 2022, we took our projections for the quantifiable program costs reported in Section IV.B.1.b and compared that to projected fuel consumption. The AEO projects tha t the U.S. will consume 44.9 bill gal of blended diesel in 2013 and 50.3 bill gal in

2022. 84 Averaged over this diesel pool, the quantifiable costs of the 1.28 bill gal mandate translate into a per gallon cost of between $0.006 and $0.008 in 2013 and betwe en

- $0.004 and $0.002 in 2022. 85

Several parties commented that the analysis of the cost impacts of 1.28 bill gallons of

biomass

- based diesel must take into account the biodiesel tax subsidy, which expired at the end

of 2011 . Fuel taxes and tax subsidies function to change the manner in which society pays for transportation fuel through redistribution of costs, but they do not change the total cost to

83 McPhail, L, P Westcott, and H Lutman, The Renewable Identification Number System a nd U.S. Biofuel Mandates

, United States Department of Agriculture, November 2011.

84 U.S. Department of Energy, Energy Information Administration. 2012. Annual Energy Outlook 2012 (Early Release). Available at: http://www.eia.gov/forecasts/aeo/er/

. 85 If current RIN prices were used to gauge social cost in lieu of the bottom

- up engineering cost approach applied herein, the estimate of transportation fuel costs would be higher. Deleted: numerous

Deleted: of all

Deleted: Second, the commodity traded, biomass

based diesel, has one overall price, but has two components (the RIN component and the liquid volume component). The relative magnitude of these two components can vary depending on their individual markets, making it difficult to have confidence in the RIN value as a representation of

the full cost of the biomass

- based diesel fuel. T hird

Deleted: given

Deleted: the level of RFS standard itself.

Deleted: , further undermining confidence in the effectiveness of RIN prices as a proxy for true social costs of the biodiesel program.

Deleted: c. Transfers Occurring as a Result of

This Mandate ¶ ¶ Some general equilibrium effects that will result from this rule are not captured in a partial equilibrium framework such as the CARD stochastic

model. Since the increase in the biomass

- based diesel volume requirement is fairly modest, these impacts will likely be modest and represent various transfers in different markets. For example, the price of soybean oil, both for biodiesel production and in food products, will increase as a result of the demand for an additional 280 mill gal biodiesel. In additi on, as soybean prices increase moderately, soybean growers will likely spend more of their revenues on key inputs such as labor and fertilizers. Increasing payments to labor and fertilizer producers will results in further spending with impacts primarily in rural areas of the U.S. that supply the soybeans. ¶ ¶ On the petroleum side of the market, a modest

decline in diesel fuel demand will result in lower payments to diesel fuel suppliers and to refineries that produce diesel fuel. In turn, diesel fuel sup pliers and refineries will spend less on key inputs such as refinery equipment used to produce diesel fuel. Given the small volumes of diesel fuel involved, it is not likely that there will be discernible impacts on the overall market price for diesel fue l, which is set by a combination of world, national, regional and

local markets and conditions. ¶ ¶

d

Deleted: (see Section IV.B.1.c).*** E.O. 12866 Review

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society. For this reason we generally do not quantify the impact of taxes or tax subsidies on price, but instead focus on the costs to produce and distribute transportation fuel. Moreover, the impact of the biodiesel tax subsidy on the retail price of biodiesel is a complex relationship that

can be difficult to assess. For in stance, Figure IV.B.1. c

- 2 shows the retail price of biodiesel over the period January 2008 through April 2012 . While the biodiesel tax credit was not effective during 2010 or 2012 , the price of biodiesel was not substantially higher during these years than it

was at other times . Moreover, after the tax credit was reinstated for 2011, including retroactive credits for biodiesel produced in 2010, the price of biodiesel in 2011 did not decrease substantially in 2011 compared to 2010. These results illustrate the difficulty in correlating biodiesel price with tax policies, and thus represents an additional reason that we have not made an effort to project biodiesel prices in the future under different tax policy scenarios.

Figure IV.B.1. c

- 2 Nationwide Average Biodiesel Prices at Retail

Source: DOE Alternative Fuels & Advanced Vehicles Data Center, Alternative Fuel Price Report. http://www.afdc.energy.gov/afdc/price_report.html

In their comments on the 2012 Renewable Fuel Standards, the American Trucking Association (ATA) suggested that production of biomass

- based biodiesel from yellow grease and other rendered fats may not be economically practical due to the diffuse nature of the feedstock supply chain. Specifically, ATA argued tha t the cost of collection of often small quantities of this feedstock dispersed over a wide geographic area and their transport to biofuel producers may

be cost

- prohibitive.

The transportation costs associated with the collection of yellow grease and othe r rendered fats are likely greater than the cost of collection for biomass

- based biodiesel feedstock such as soybean oil. However, the actual delivered cost of feedstock for use in producing biodiesel consists of two components: the cost of production and the cost of transportation. For soybean oil, the cost of production ( e.g., planting, fertilizing, harvesting, expelling) is relatively Deleted: d

Deleted: July 2011

Deleted: in 2009

Deleted: d

Deleted: ¶*** E.O. 12866 Review

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large compared to the cost of transportation to centralized biofuel producers. However, the cost of production for yel low grease and other rendered fats is zero, as they are considered wastes or byproducts. When combining both cost components (i.e.

, production and transportation) for each respective feedstock from USDA’s National Weekly Agricultural Energy Round

- Up 86

, the total delivered costs for yellow grease and other rendered fats is consistently less that the total delivered costs for soybean oil. For instance, for the week of March 30, 2012 , crude soybean oil was selling for about 5 3 ¢/lb, while yellow grease was se lling for about 41 ¢/lb. As such, we believe that the ATA concerns regarding the feedstock supply chain are not warranted.

2. Monetized Quantifiable Benefits

Many of the benefits and impacts that Congress asked EPA to examine when evaluating

whether to increase the volume requirement for biomass

- based biodiesel are difficult to fully quantify. In this section, we present a selection of quantifiable benefits from increased biodiesel production, including increased energy security and reduced greenhous e gas emissions. As observed above, it is most appropriate to consider these benefits within the context of full program implementation (i.e., the year 2022). However, we also present benefits for 280 million gallons of additional biodiesel produced in t he year 2013 for comparison purposes.

a. Energy Security

Quantified energy security benefits are taken from the estimates reported in Section IV.A.2 of this final rule. As noted there, EPA considers only the macroeconomic disruption and adjustment eff

ect in its estimates of energy security benefits. Based on application of the ORNL methodology, w e estimate that the energy security benefits of the additional 280 mill gal increment of biodiesel are $0.15 per gallon in 2013 and $0.16 per gallon in 2022. This translates to a total program benefit of about $41 million in 2013 and $45 million in 2022.

b. Air Quality

We discuss air quality impacts qualitatively in Section IV.A.4 of this final rule and expect an additional 280 mill gal of biodiesel (in years 2013 and 2022) will have a relatively small impact on ambient air quality. That said, we do expect the production and combustion of biodiesel to have a slightly different emissions impact relative to petroleum

- based diesel. As presented in Table IV .A.4

- 1, we estimated that in 2022, the increased production of biodiesel related to the RFS2 mandate would impact both downstream and upstream emissions, with increases in some pollutants and decreases in others.

Ideally, the monetized impacts of change s in air quality related to the final rule would be estimated based on changes in ambient pollution concentrations and population exposure, as determined by complete air quality and exposure modeling. However, conducting such detailed modeling was not pos sible within the timeframe for this analysis.

86 USDA Livestock & Grain Mark et News for October 14, 2011. http://www.ams.usda.gov/mnreports/lswagenergy.pdf*** E.O. 12866 Review

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Instead, our analysis of PM 2.5 - related health impacts associated with 280 additional gallons of biodiesel (in both 2013 and 2022) uses a “dollar

- per

- ton” method to estimate selected

PM 2.5 - related health impa cts. These PM 2.5 - related dollar

- per

- ton estimates provide the total monetized human health impacts (the sum of premature mortality and premature morbidity) of reducing one ton of directly emitted PM 2.5 , or one ton of a pollutant that contributes to

second arily

- formed PM 2.5 (such as NOx, and SOx ) from a specified source. 87 The dollar

- per

- ton technique has been used in previous analyses, including the 2012

- 2016 Light

- Duty Greenhouse Gas Rule, 88 the Ozone National Ambient Air Quality Standards (NAAQS) RIA, 89 the Portland Cement National Emissions Standards for Hazardous Air Pollutants (NESHAP) RIA, 90 and the

final NO 2 NAAQS. 91

The analysis of the final 2013 fuel mandate did not estimate the direct emissions impacts to which we could apply the “dollar

- p er

- ton” estimates. Instead, we converted “dollars

- per

- ton”
to “dollars

- per

- gallon” by transferring the biodiesel tons

– to

- emissions relationship observed in the RFS2 analysis to the current analysis (dividing emissions in Table IV.A.4

- 1 by 1.44 bill gallo ns of biodiesel) and multiplying that by each pollutant

- specific dollar

- per

- ton estimate.

The dollar

- per

- ton estimates used to monetize the emissions impacts from each gallon of biodiesel are provided in Table IV.B.2.b

- 1.

Table IV.B.2.b

- 1

PM 2.5 - related Dollar

- per

- ton Values (2010$) a

Year All Sources c Upstream (Non

- EGU)

Sources d Mobile Sources

SO 2 NO X Direct

PM2.5 NO X Direct

PM2.5

Dollar

- per

- ton Derived from American Cancer Society Analysis (Pope et al., 2002) Using a 3

Percent Discount Rate b

2015 $30 ,000 $4,9 00 $230,000 $5,1 00 $280,000

87 Due to analytical limitations, the estimated dollar

- per

- ton values do not include comparable impacts related to reductions in other ambient concentrations of criteria pollutants (such as ozone, NO2 or SO2) or toxic air pollutants, nor do they monetize all of the potential health and welfare effects associated with PM2.5 or the other criteria pollutants.

88 U.S. Environmental Protection Agency (U.S. EPA), 2010. Regulatory Impact Analysis, Final Rulemaking to Establish Light

- Duty Vehicle Greenhouse Gas Emissi on Standards and Corporate Average Fuel Economy Standards. Office of Transportation and Air Quality. April. Available at http://www.epa.gov/otaq/climate/regulations/420r10009.pdf . E PA

- 420

- R

- 10

- 009

89 U.S. Environmental Protection Agency (U.S. EPA). 2008. Regulatory Impact Analysis, 2008 National Ambient Air Quality Standards for Ground

- level Ozone, Chapter 6. Office of Air Quality Planning and Standards, Research Triangle Park, NC. March. Available at <http://www.epa.gov/ttn/ecas/regdata/RIAs/6

- ozoneriachapter6.pdf>.

EPA

- HQ

- OAR

- 2009

- 0472

- 0238

90 U.S. Environmental Protection Agency (U.S. EPA). 2010. Regulatory Impact Analysis: National Emission

Standards for Hazardous Air Pollutan ts from the Portland Cement Manufacturing Industry. Office of Air Quality Planning and Standards, Research Triangle Park, NC. August. Available on the Internet at < http://www.epa.gov/ttn/ecas/regdata/RIAs/portlandcementfinalria.pdf >. EPA

- HQ

- OAR

- 2009

- 0 472

- 0241

91 U.S. Environmental Protection Agency (U.S. EPA). 2010. Final NO2 NAAQS Regulatory Impact Analysis (RIA). Office of Air Quality Planning and Standards, Research Triangle Park, NC. April. Available on the Internet

at http://www.epa.gov/ttn/ecas/regdata/RIAs/FinalNO2RIAfulldocument.pdf . Accessed March 15, 2010. EPA

- HQ

OAR

- 2009

- 0472

- 0237 Deleted: SOx,

Deleted: VOCs

Deleted: Benefits

Deleted: Derived Using the American Cancer Society Cohort Study for PM

- related Premature Mortality (Pope et al., 2002)

Deleted: VOC

Deleted Cells

Deleted: Estimated

Deleted: $1,200

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2020 $33 ,000 $5,4 00 $250,000 $5,6 00 $31 0,000

Dollar

- per

- ton Derived from American Cancer Society Analysis (Pope et al., 2002) Estimated Using a 7 Percent Discount Rate b

2015 $27,000 $4,5 00 $210,000 $4,600 $250,000

2020 $30 ,000 $4,9 00 $23 0,000 $5,1 00 $280,000

Dollar

- per

- ton Derived from Six Cities Analysis (Laden et al., 2006) Estimated Using a 3

Percent Discount Rate b

2015 $73,000 $12,000 $560,000 $12,000 $680,000

2020 $80,000 $13,000 $620,000 $14,000 $750,000

Dollar

- per

- ton Derived from Six Cities Analysis (Laden et al., 2006) Estimated Using a 7

Percent Discount Rate b

2015 $66,000 $11,000 $510,000 $11,000 $620,000

2020 $72,000 $12,000 $560,000 $12,000 $680,000

a Total dollar

- per

- ton estimates include monetized PM2.5

- related premature mortality and morbidity endpoints

. Range of estimates are a function of the estimate of PM2.5

- related premature mortality derived from either the ACS study (Pope et al., 2002 ) or the Six

- Cities study (L aden et al., 2006 ).

b The dollar

- per

- ton estimates presented in this table assume either a 3 percent or 7 percent discount rate in the valuation of premature mortality to account for a twenty

- year segmented cessation lag.

c Note that the dollar

- per

- ton value for SO2 is based on the value for Stationary (Non

- EGU) sources; no SO2 value

was estimated for mobile sources.

d Non

- EGU denotes stationary sources of emissions other than electric generating units (EGUs).

For certain PM 2.5 - related pollutants (such as direct PM 2.5 and NOx), EPA estimates different per

- ton values for reducing mobile source emissions than for reductions in emissions of the same pollutant from stationary sources such as fuel refineries and storage facilities. These reflect differences in the typical geographic distributions of emissions of each pollutant by different sources, their contributions to ambient levels of PM 2.5 , and resulting changes in population exposure. We apply these separate values to estimates of changes in emissions from

vehicle u se and from fuel production and distribution to determine the net change in total economic impacts from emissions of those pollutants. Monetized PM2.5

- related health impacts

associated with the final rule can be found in Table IV .B.2.b

- 2 and per gallon impacts can be

found in Table IV .B.2.b

- 3. Deleted: $1,400

Deleted: $1,100

Deleted Cells

Deleted: $1,200

Deleted: The benefit

Deleted: presented in this table

Deleted: based on an

Deleted: ). If the benefit

- per

- ton estimates were

based on

Deleted: ), the values would be approximately 245% (nearly two

- and

- a

- half times larger).

Deleted: benefit

Deleted: benefit

Deleted: The benefit

- per

- ton value for VOCs was

estimated across all sources.

Deleted: VI

Deleted: VI*** E.O. 12866 Review

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Table VI.B.2.b

- 2

Total Ambient PM2.5

- related Monetiz ed Health Impacts (millions 2010 $) a

2013 Monetized Impacts (7%

Discount Rate

– 3% Discount

Rate) 2022 Monetized Impacts (7%

Disc ount Rate

– 3% Discount

Rate) Using Dollar

- per

- ton Derived from American Cancer Society Analysis (Pope et al., 2002)

Downstream $ 14

- $ 16 $16

- $ 17 Upstream

- $34

- - $ 37

- $37

- - $ 41 Net Impacts

- $19

- - $ 21

- $ 21

- - $23

Using Dollar

- per

- ton Derived from Six Cities Analysis (Laden et al., 2006)

Downstream $35

- $39 $38

- $43 Upstream

- $82

- - $91

- $90

- - $99 Net Impacts

- $47

- - $52

- $51

- - $57

a Note: Negative values indicate disbenefits associated with decrements in ambient air quality.

Table VI.B.2.b

- 3

Per Gallon Ambient PM2.5

- related Monetiz ed Health Impacts (2010 $ per gallon ) a

2013 Monetized Impacts (7%

Discount Rate

– 3% Discount

Rate) 2022 Monetized Impacts (7%

Discount Rate

– 3% Discount

Rate) Using Dollar

- per

- ton Derived from American Cancer Society Analysis (Pope et al., 2002)

Downstream $0.05

- $0.06 $0.06 b

Upstream

- $0.12

- - $0.13

- $0.13

- - $0.14 Net Impacts

- $0.07

- - $0.08

- $0.08 b

Using Dollar

- per

- ton Derived from Six Cities Analysis (Laden et al., 2006)

Downstream $0.12

- $0.14 $0.14

- $0.15 Upstream

- $0.29

- - $0.33

- $0.32

- - $0.35 Net Impacts

- $0. 17

- - $0.19

- $0. 18

- - $0. 20

a Note: Negative values indicate disbenefits associated with decrements in ambient air quality.

b Variation in this category is less than one cent. The method used in this analysis to estimate the monetized PM2.5

- related impacts of an increase in biodiesel production is subject to a number of assumptions and uncertainties.

The method does not reflec t local variability in population density, meteorology, exposure, baseline health incidence rates, or other local factors that might lead to an overestimate or underestimate of the actual benefits of controlling fine particulates in specific locations. Th is is particularly a problem for the monetization of upstream emissions since those have a very specific geographic profile different to that associated with mobile source emissions.

Transferring the biodiesel tons

- to

- emissions relationship derived from t he RFS2 mandate in 2022 to the current analysis (in both 2013 and 2022) assumes that the incremental production of biodiesel associated with the 2013 mandate (of 280 million gallons) will yield the same relative emissions impacts, which we cannot say with certainty. Deleted: $; based on Pope et al., 2002)

Deleted: 15

Deleted: 18

Deleted: 40

Deleted: 20

- - $22

Deleted: ; based on Pope et al., 2002

Deleted: 07 b

Deleted: 07

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This analysis assumes that all fine particles, regardless of their chemical composition, are equally potent in causing premature mortality. PM 2.5 produced via transported precursors emitted from stationary sources may differ significantly

from direct PM 2.5 released from engines and other industrial sources. At the present time, however, no clear scientific grounds exist for supporting differential effects estimates by particle type.

This analysis assumes that the health impact function for f ine particles is linear within the range of ambient concentrations under consideration. Thus, the estimates include health benefits from reducing fine particles in areas with varied

initial concentrations of PM 2.5, including both regions that are in attai nment with fine particle standard and those that do not meet the standard, down to the lowest modeled concentrations. This is an appropriate assumption because the scientific literature provides no evidence of a threshold below which health effects

associ ated with exposure to fine particles

– including premature death

-- would

not occur.

There are several health benefits categories that we are unable to quantify due to limitations associated with using dollars

- per

- ton estimates, several of which could

be substantial. Because NO X and VOC emissions are also precursors to ozone, changes in NO X and VOC would also impact ozone formation and the health effects associated with ozone exposure. Dollars

- per

- ton estimates for ozone do

not exist due to issues assoc iated with the complexity of the atmospheric air chemistry and nonlinearities associated with ozone formation. The PM

- related

benefits

- per

- ton estimates also do not include any human welfare or ecological

benefits.

c. Greenhouse Gas Impacts

EPA estab lished in the RFS2 final rule that a gallon of soybean

- based biodiesel results in an annualized GHG emission reduction of approximately 57 percent compared to the 2005 petroleum baseline. This GHG reduction calculation is based on the annualized emissions stream over a 30 year period, starting in 2022 (the year when the RFS2 program will be fully implemented). As described in Section IV.A.1 of this final rulemaking , it may not be appropriate to include these GHG benefit reductions in our 2013 calculat ions. Again, this is not because EPA believes that the GHG benefits in 2013 will be zero, but rather because it may not be consistent to cite them for an interim year of the program using lifecycle biofuel assessments based on a 2022 analyses. As a sensi tivity, however, if we were to apply the 2022 GHG emissions reductions to the 1.28 bill gal biomass

- based diesel mandate, the monetized GHG benefits of an additional 280 million gallons of biodiesel produced in 2013 would be from $6

million up to $104 mill ion, depending on the assumed discount rate. Also on this basis, we estimate that benefits of an additional 280 million gallons of biodiesel produced in 2022 will be between $9 and $120 million.

3. Quantifiable Benefits and Costs Compared Deleted:

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As we have o bserved above, the cost and benefit categories discussed in this section are not comprehensive. EPA has included estimates for those impacts that we are able to quantify at the present time, but this is not meant to suggest that EPA considers these to be the total costs

and benefits of the 2013 biomass

- based diesel mandate. However, for illustrative purposes, we are providing a range of quantifiable combined cost and benefit estimates for the impact of a 1.28 billion gallon mandate in 2013 and in 2022, ba sed on those impacts that we were able to

monetize.

a. Combined Quantifiable Costs and Benefits for Biodiesel Produced in 2022

EPA’s estimates of quantifiable costs and benefits vary significantly in 2022 due to uncertainty about the value of the SCC, a ir quality impacts, and the price of oil. Table IV.B.3.a

1 presents the range of estimates for the combined quantifiable costs and benefits of an additional 280 million gallons of biodiesel produced in 2013 and 2022, using the SCC discount

rates to deline ate the ranges. Each range also incorporates variations in the discount rate for air quality disbenefits and both estimates of the price of oil and diesel in 2022. The total range

varies from

- $ 119 million to $301 million.

Table IV.B.3.a

- 1

Estimates o f Combined Costs and Benefits of the 1.28 Billion Gallon Biodiesel Mandate in 2022 (in 2010 dollars)

Combined Costs and Benefits Social Cost of Carbon Assumption AEO 2012 Early Release AEO 2011 High Oil Price

5% Discount Rate

- $ 119 to

- $8 2 million $153 to $189 million

3% Discount Rate

- $ 88 to

- $5 1 million $184 to $220 million

2.5% Discount Rate

- $ 62 to

- $2 6 million $209 to $246 million 3% Discount Rate (95 th Percentile)

- $7 to $ 30 million $264 to $301 million

b. Combined Quantifiable Costs and Benefits for Biodiesel Produced in 2013

EPA’s estimates of quantifiable costs and benefits vary significantly in 2013 as well, though this is due to uncertainty about the price of diesel as well as uncertaint y about the value

of air quality impacts and the SC

- CO 2 . Table IV.B.3.b

- 1 presents the range of estimates for the combined quantifiable costs and benefits of an additional 280 million gallons of biodiesel produced in 2013, which varies from

- $ 425 million to

- $159 million.

Table IV.B.3.b

- 1

Estimates of Combined Costs and Benefits of the 1.28 Billion Gallon Biodiesel Mandate in 2013 (in 2010 dollars)

Combined Costs and Benefits Social Cost of Carbon Assumption AEO 2012 Early Release STEO March 2012

No GHG Benefit Monetized

- $425 to

- $39 1 million

- $ 297 to

- $263 million

5% Discount Rate

- $418 to

- $38 4 million

- $ 290 to

- $256 million

3% Discount Rate

- $391 to

- $35 7 million

- $ 263 to

- $229 million

2.5% Discount Rate

- $367 to

- $33 3 million

- $ 240 to

- $206 million 3% Discount Rate (95 th Percentile)

- $321 to

- $28 7 million

- $ 193 to

- $159 million Deleted: 84

Deleted: Combined Costs and Benefits

Inserted Cells

Deleted: 84

Deleted: $189

Deleted: 53

Deleted: $220

Deleted: 28

Deleted: $246

Deleted: $28

Deleted: 301

Deleted: 393

Inserted Cells

Deleted: Combined Estimate

Deleted: Included

Deleted: 393

Deleted: 386

Deleted: 359

Deleted: 335

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The transition from negative combined quantified costs and benefits estimates in 2013 to generally even or positive estimates in 2022 illustrate the importance of considering the RFS program at full implementation. As observed above, oil prices have generally tended to increase in real terms over time, causing the price of diesel to rise, while soybean oil pri ces decrease in real terms due to improving yields, which reduces the cost of biodiesel production. Thus, while quantified costs from the wider use of biomass

- based biodiesel can be greater than quantified benefits in the near term, through time benefits tend to increase and outweigh costs.

Further, as noted at the beginning of this section, this analysis is not intended to serve as a comprehensive quantification of the costs and benefits of this mandate. Rather, it illustrates

those costs and benefits that are quantifiable in response to comments received on the proposed rule. To develop a comprehensive estimate of costs and benefits, one would need to qualitatively balance these estimates against the impacts discussed earlier in this section.

V. Final 2013 Volume for Biomass

- Based Diesel

Through the RFS program, Congress established a schedule of renewable fuel volumes that gradually increases over time. While the schedule in the statute for biomass

- based diesel ends in 2012, the sch edule of increasing volumes for advanced biofuels continues through 2022. For the years between 2012 and 2022, the statute indicates that biomass

- based diesel volumes can increase above the 2012 applicable volume of 1.0 bill gal, but they cannot ever be l ower than 1.0 bill gal. Subject to a consideration of a number of factors as described in Section II, we believe that it is appropriate to consider biomass

- based diesel as playing an increasing role in supplying advanced biofuels to the market between 201 2 and 2022.

As described in Section IV.A.9, increases in the required volume of biomass

- based diesel above 1.0 bill gal will help to support rural economic growth and job creation, will increase energy security, and reduce emissions of GHGs. Our estimates of the quantifiable benefits of an increase of 280 mill gal do not exceed the costs in 2013 . Our estimates of the quantifiable

benefits do exceed costs by 2022 under scenarios assuming the AEO 2011high oil price projections or applying the high SCC value (95 th percentile 3% discount rate) to the AEO 2012 early release reference case oil price. Thus by establishing an applicable volume for biomass

based diesel in 2013 that exceeds the minimum of 1.0 bill gal, we are helping to establish the industry as a substantial contributor to the required volumes of advanced biofuel anticipated after full implementation of the RFS program.

Therefore, based on our review of the factors required in the statute, we are finalizing an

ap plicable volume of 1.28 bill gal biomass

- based diesel for 2013, consistent with our proposal. We received comments both in support of and opposed to an increase above the statutory minimum of 1.0 bill gallons. We have determined that 1.28 bill gallons is achievable in 2013 and is a reasonable exercise of our authority under CAA 211(o)(2)(B)(ii) to bring about the long

term benefits of the RFS program.

We did not propose biomass

- based diesel standards for 2014 and beyond in the NPRM

since we believe we w ill be in a better position in the future to evaluate all of the factors related Deleted: While we ha ve projected that

Deleted: are unlikely to

Deleted:

,
Deleted: will most likely

Deleted:

.

Deleted: To this end, and subject to the factors described in Section II, we envision additional increases in the required volume of biomass

- based diesel throughout the period between 2012 and 2022, though not necessarily every year.*** E.O. 12866 Review

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64

to establishing an applicable volume for 2014 and later years. In response to the NPRM, two parties commented that EPA should set the required volumes of biomass

- based diesel through at least the year 2017. We agree that specifying the required volumes of biomass

- based diesel for more than one compliance year would provide greater certainty for both biofuel producers and obligated parties, stability for future investments and contracts, and could potentially reduce the need to waive a portion of the advanced biofuel requirement in future years. However, one of the factors that we are required to consider when determining the appropriate biomass

- based diesel volume for years a fter 2012 is a review of the implementation of the program during prior years. By determining the applicable volume requirement for biomass

- based diesel only one year in advance, we are able to use the most up

- to

- date information on the implementation of the program in making our determination. This is particularly important in the early years of the

program.*** E.O. 12866 Review

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Page 65 of 71 VI. Public Participation

Many interested parties participated in the rulemaking process that culminates with this final rule. This process provided opportunity for submitting written public comments following the proposal that we published on July 1, 2011 (76 FR 38844), and we considered these comments in developing the final rule. Public commen ts and EPA responses are discussed throughout this preamble, and all comments received are available in EPA docket number EPA

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Page 66 of 71 VII. Statutory and Executive Order Reviews

A. Executive Order 12866: Regulatory Planning and Review and Executive Order 13563: Improving Regulation and Regulatory Review

Under Executive Order 12866 (58 FR 51735, October 4, 1993), this action is a "significant regulatory action” because it raises novel legal or policy issues. Accordingly, EPA submitted this action to the Office of Management and Budget (OMB) for review under Executive Orders 12866 and 13563 (76 FR 3821, January 21, 2011) and any changes made in

resp onse to OMB recommendations have been documented in the docket for this action.

The economic impacts of the RFS2 program on regulated parties, including the impacts of the required volumes of renewable fuel, were already addressed in the RFS2 final rule promulgated on March 26, 2010 (75 FR 14670). This action finalizes the applicable volume of

biomass

- based diesel for 2013. We have been able to quantify some of the economic impacts of

this rule in 2013.

We estimate that soybean prices could increase u p to 3 cents per pound in 2013 if the 2013 biodiesel standard is met solely as a result of increased demand for soy bean oil. Potential use of other less expansive feedstocks would reduce this impact on soy beans. Again assuming the 280 billion gallon in crease in required biomass

- based diesel is met through increased demand for soy oil, we estimate the cost of producing this biomass

- based diesel would range from $253 to $381 million in 2013. Illustrative of the changing analysis over time, the cost of th is amount of soy

- based biodiesel in 2022 would be

- $195 million to $116 million. Adding these estimates of 2013 costs to the fuel pool would result in a diesel fuel cost increase of between

- $0.004 and $0.002 per gallon.

Quantified estimates of benefits and disbenefits include energy security benefits of $0.15 per gallon in 2013 and $0.16 per gallon in 2022, air quality disbenefits of $0.07 per gallon in 2013 and $0.07 to $0.08 per gallon in 2022, and GHG benefits of up to $134 million in 2013 and

betwe en $15 million and $160 million in 2022. Other benefits include both direct and indirect employment benefits in rural areas due to increased biodiesel production. Impacts on water quality, water use, wetlands, ecosystems and wildlife habitats are expecte d to be modest due to both the small impact on crops planted and due to the relatively small impact of soy bean production.

B. Paperwork Reduction Act

This action does not impose any new information collection burden since it onl y specifies the required volume of biomass

- based diesel under the RFS program for 2013. However, the Office of Management and Budget (OMB) has previously approved the information collection requirements contained in the existing regulations at 40 CFR Part 80, Subpart M under the provisions of the Paperwork Reduction Act , 44 U.S.C. 3501 et seq . This would include the following approved information collections (with OMB control numbers and expiration dates listed in parenthesis): “Renewable Fuels Standard Program: Petition and Registration” (OMB*** E.O. 12866 Review

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Page 67 of 71 Control Number 2060

- 0637, expires March 31, 2013); “Renewable Fuels Standard (RFS2)” (OMB Control Number 2060

- 0640, expires July 31, 2013); “Regulations of Fuels and Fuel

Additives: 2011 Renewable Fuels Standard

– Petition for International Aggregate Compliance Approach” OMB Control Number 2060

- 0655, expires February 28, 2014). The OMB control numbers for EPA's regulations in 40 CFR are listed in 40 CFR part 9. Detailed and searchable

information about these and other approved collections may be viewed on the Office of Management and Budget (OMB) Paperwork Reduction Act website, which is accessible at http://www.reginfo.gov/public/do/PRAMain

.

C. Regulator

y Flexibility Act

The Regulatory Flexibility Act (RFA) generally requires an agency to prepare a regulatory flexibility analysis of any rule subject to notice and comment rulemaking requirements under the Administrative Procedure Act or any other statute unless the agency certifies that the rule will not have a significant economic impact on a substantial number of small entities. Small entities include small businesses, small organizations, and small governmental jurisdictions.

For purposes of assessi ng the impacts of today's rule on small entities, small entity is defined as: (1) a small business as defined by the Small Business Administration’s (SBA) regulations at 13 CFR 121.201; (2) a small governmental jurisdiction that is a government of a city, county, town, school district or special district with a population of less than 50,000; and (3) a small organization that is any not

- for

- profit enterprise which is independently owned and operated and is not dominant in its field.

After considering the economic impacts of today’s final rule on small entities, I certify that this action will not have a significant economic impact on a substantial number of small entities. The impacts of the RFS2 program on small entities that are directly regulated under the RFS2 program were already addressed in the RFS2 final rule promulgated on March 26, 2010 (75 FR 14670). This rule simply establishes the applicable volume for biomass

- based diesel for 2013 at a level that is consistent with the analyses in the RFS2 f inal rule. Therefore, this action will not impose any additional requirements on small entities beyond those which have already

been evaluated.

We received a comment suggesting that impacts on truckers of the applicable volume of

biomass

- based diesel for 2013 established in this rule should be evaluated as part of our standard small business impact analysis. In response, we note that such analyses are only required under the Regulatory Flexibility Act for parties directly regulated by a rule and that , in general, truckers are not directly regulated by today's action nor under the regulatory requirements

established in the RFS2 final rule.

D. Unfunded Mandates Reform Act*** E.O. 12866 Review

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Page 68 of 71 This rule does not contain a Federal mandate that may result in expenditures of $100 million or more for State, local, and tribal governments, in the aggregate, or the private sector in any one year. This rule simply establishes the applicable volume for biomass

- based diesel for 2013 at a level that is consistent with the analyses in the RFS2 final rule. Thus, this action is not subject to the requirements of sections 202 or 205 of UMRA.

This action is also not subject to the requirements of section 203 of UMRA because it contains no regulatory requirements that might significant ly or uniquely affect small
governments.

E. Executive Order 13132: Federalism

This action does not have federalism implications. It will not have substantial direct effects on the States, on the relationship between the national government and the S tates, or on the distribution of power and responsibilities among the various levels of government, as specified in Executive Order 13132. This action only applies to gasoline, diesel, and renewable fuel producers, importers, distributors and marketers an d makes relatively minor corrections and modifications to the RFS2 regulations. A summary of the concerns raised, and EPA’s response to those concerns, is provided in this preamble.

F. Executive Order 13175: Consultation and Coordination with Indian T ribal

Governments

This action does not have tribal implications, as specified in Executive Order 13175 (65 FR 67249, November 9, 2000). This rule will be implemented at the Federal level and impose compliance costs only on transportation fuel refiners, blenders, marketers, distributors, importers, exporters, and renewable fuel producers and importers. Tribal governments would be affected only to the extent they purchase and use regulated fuels. Thus, Executive Order 13175 does not apply to this action.

G. Executive Or

der 13045: Protection of Children from Environmental Health Risks and Safety Risks

EPA interprets EO 13045 (62 FR 19885, April 23, 1997) as applying only to those regulatory actions that concern health or safety risks, such that the analysis required und er section 5

- 501 of the EO has the potential to influence the regulation. This action is not subject to EO 13045 because it does not establish an environmental standard intended to mitigate health or safety risks and because it implements specific standar ds established by Congress in statutes.

H. Executive Order 13211: Actions Concerning Regulations That Significantly Affect Energy Supply, Distribution, or Use*** E.O. 12866 Review

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Page 69 of 71 This rule is not a “significant energy action” as defined in Executive Order 13211,
“Actions Concerning Regulations That Significantly Affect Energy Supply, Distribution, or Use” (66 FR 28355 (May 22, 2001)) because it is not likely to have a significant adverse effect on the supply, distribution, or use of energy. This action simply finalizes t he annual standards for

cellulosic biofuels for 2012 and biomass

- based diesel for 2013, provisions for new RIN

generating pathways, and clarifying changes and minor technical amendments to the regulations.

I. National Technology Transfer Advancement Act

Section 12(d) of the National Technology Transfer and Advancement Act of 1995 (‘‘NTTAA’’), Public Law 104

– 113, 12(d) (15 U.S.C. 272 note) directs EPA to use voluntary consensus standards in its regulatory activities unless to do so would be inconsistent with applicable law or otherwise impractical. Voluntary consensus standards are technical standards (e.g., materials specifications, test methods, sampling procedures, and business practices) that are developed or adopted by voluntary consensus standards bodies. NTTAA directs EPA to provide Congress, through OMB, explanations when the Agency decides not to use available and applicable voluntary consensus standards.

This action does not involve technical standards. Therefore, EPA did not consider the

u se of any voluntary consensus standards.

J. Executive Order 12898: Federal Actions to Address Environmental Justice in Minority Populations and Low

- Income Populations

Executive Order (EO) 12898 (59 FR 7629 (Feb. 16, 1994)) establishes federal executiv e policy on environmental justice. Its main provision directs federal agencies, to the greatest extent practicable and permitted by law, to make environmental justice part of their mission by identifying and addressing, as appropriate, disproportionately high and adverse human health or environmental effects of their programs, policies, and activities on minority populations and low

income populations in the United States.

EPA has determined that this final rule will not have disproportionately high and adverse human health or environmental effects on minority or low

- income populations because it does not affect the level of protection provided to human health or the environment. This action

does not relax the control measures on sources regulated by the RFS2 regulations and therefore

will not cause emissions increases from these sources.

K. Congressional Review Act

The Congressional Review Act, 5 U.S.C. 801 et seq., as added by the Small Business Regulatory Enforcement Fairness Act of 1996, generally provides that before a rule may take effect, the agency promulgating the rule must submit a rule report, which includes a copy of the rule, to each House of the Congress and to the Comptroller General of the United States. EPA*** E.O. 12866 Review

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Page 70 of 71 will submit a report containing this rule and other required information to the U.S. Senate, the U.S. House of Representatives, and the Comptroller General of the United States prior to publication of the rule in the Fed eral Register . A major rule cannot take effect until 60 days after it is published in the Federal Register . This action is not a “major rule” as defined by 5 U.S.C. 804(2). This rule will be effective on the date of publication.*** E.O. 12866 Review

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Page 71 of 71 VIII. Statutory Authority

Statutory authority for the rule finalized today can be found in section 211 of the Clean Air Act, 42 U.S.C. 7545. Additional support for the procedural and compliance related aspects of today's rule , including the recordkeeping requirements, come from sections 114, 208, and 301(a) of the Clean Air Act, 42 U.S.C. sections 7414, 7542, and 7601(a).

List of Subjects in 40 CFR Part 80

Environmental protection, Administrative practice and procedure, Air pollution control, Confidential Business Information, Diesel fuel, Fuel additives, Gasoline, Imports, Labeling, Motor vehicle pollution, Penalties, Petroleum, Reporting and recordkeeping requirements.

Dated:

Lisa P. Jackson,

Administrator.