[Federal Register Volume 88, Number 43 (Monday, March 6, 2023)]
[Proposed Rules]
[Pages 13758-13770]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 2023-04375]


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ENVIRONMENTAL PROTECTION AGENCY

40 CFR Part 1090

[EPA-HQ-OAR-2022-0513; FRL-9845-01-OAR]
RIN 2060-AV73


Request From States for Removal of Gasoline Volatility Waiver

AGENCY: Environmental Protection Agency (EPA).

ACTION: Proposed rule.

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SUMMARY: Pursuant to provisions specified by the Clean Air Act (CAA), 
governors of eight states submitted petitions requesting that EPA 
remove the 1-pound per square inch (psi) Reid vapor pressure (RVP) 
waiver for summer gasoline-ethanol blended fuels containing 10 percent 
ethanol (E10). This action acts on those requests from the Governors of 
Illinois, Iowa, Minnesota, Missouri, Nebraska, Ohio, South Dakota, and 
Wisconsin by proposing to remove the 1-psi waiver. EPA also received 
multiple petitions from stakeholders requesting an extension of the 
effective date to the summer of 2024. This action proposes to delay the 
effective date for one year consistent with statutory provisions. Thus, 
we propose an effective date for all states of April 28, 2024. This 
action also proposes a regulatory process by which a state may request 
to reinstate the 1-psi waiver.

DATES: Comments: Comments must be received on or before April 20, 2023.
    Public hearing: EPA will hold a virtual public hearing on March 21, 
2023. Please refer to the SUPPLEMENTARY INFORMATION section for 
additional information on the public hearing.

ADDRESSES: Comments. You may send comments, identified by Docket ID No. 
EPA-HQ-OAR-2022-0513, by any of the following methods:
     Federal eRulemaking Portal: https://www.regulations.gov 
(our preferred method) Follow the online instructions for submitting 
comments.
     Email: [email protected]. Include Docket ID No. EPA-
HQ-OAR-2022-0513 in the subject line of the message.
     Mail: U.S. Environmental Protection Agency, EPA Docket 
Center, Air Docket, Mail Code 28221T, 1200 Pennsylvania Avenue NW, 
Washington, DC 20460.
     Hand Delivery or Courier: EPA Docket Center, WJC West 
Building, Room 3334, 1301 Constitution Avenue NW, Washington, DC 20004. 
The Docket Center's hours of operations are 8:30 a.m.-4:30 p.m., 
Monday-Friday (except Federal Holidays).
    Instructions: All submissions received must include the Docket ID 
No. for this rulemaking. Comments received may be posted without change 
to https://www.regulations.gov, including any personal information 
provided. For the full EPA public comment policy, information about 
confidential business information (CBI) or multimedia submissions, and 
general guidance on making effective comments, please visit https://www.epa.gov/dockets/commenting-epa-dockets.
    Public hearing. The virtual public hearing will be held on March 
21, 2023. The hearing will begin at 9:00 a.m. Eastern Daylight Time 
(EDT) and end when all parties who wish to speak have had an 
opportunity to do so. All hearing attendees (including even those who 
do not intend to provide testimony) should register for the public 
hearing by March 16, 2023. Information on how to register can be found 
at https://www.epa.gov/gasoline-standards. Additional information 
regarding the hearing appears below under SUPPLEMENTARY INFORMATION.

FOR FURTHER INFORMATION CONTACT: For questions regarding this action, 
contact Lauren Michaels, Office of Transportation and Air Quality, 
Compliance Division, Environmental Protection Agency, 2000 Traverwood 
Drive, Ann Arbor, MI 48105; telephone number: (734) 214-4640; email 
address: [email protected]. For questions regarding the public 
hearing, contact Nick Parsons at [email protected].

SUPPLEMENTARY INFORMATION: 

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. Potentially affected 
categories include:

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                                                 Examples of potentially
          Category             NAICS \1\ code       affected entities
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Industry...................              211130  Natural gas liquids
                                                  extraction and
                                                  fractionation.
Industry...................              221210  Natural gas production
                                                  and distribution.
Industry...................              324110  Petroleum refineries
                                                  (including importers).
Industry...................              325110  Butane and pentane
                                                  manufacturers.
Industry...................              325193  Ethyl alcohol
                                                  manufacturing.
Industry...................              325199  Manufacturers of
                                                  gasoline additives.
Industry...................              424710  Petroleum bulk stations
                                                  and terminals.
Industry...................              424720  Petroleum and petroleum
                                                  products wholesalers.
Industry...................      447110, 447190  Fuel retailers.
Industry...................              454310  Other fuel dealers.
Industry...................              486910  Natural gas liquids
                                                  pipelines, refined
                                                  petroleum products
                                                  pipelines.
Industry...................              493190  Other warehousing and
                                                  storage--bulk
                                                  petroleum storage.
------------------------------------------------------------------------
\1\ North American Industry Classification System (NAICS).


[[Page 13759]]

    This table is not intended to be exhaustive, but rather provides a 
guide for readers regarding entities likely to be affected by this 
action. This table lists the types of entities that EPA is now aware 
could potentially be affected by this action. Other types of entities 
not listed in the table could also be affected. To determine whether 
your entity would be affected by this action, you should carefully 
examine the applicability criteria in 40 CFR part 1090. If you have any 
questions regarding the applicability of this action to a particular 
entity, consult the person listed in the FOR FURTHER INFORMATION 
CONTACT section.

Participation in Virtual Public Hearing

    Information on how to register for the hearing can be found at 
https://www.epa.gov/gasoline-standards. The last day to pre-register to 
speak at the hearing will be March 16, 2023.
    Each commenter will have 3 minutes to provide oral testimony. EPA 
may ask clarifying questions during the oral presentations, but will 
not respond to the presentations at that time. Written statements and 
supporting information submitted during the comment period will be 
considered with the same weight as oral comments and supporting 
information presented at the public hearing.
    Please note that any updates made to any aspect of the hearing will 
be posted online at https://www.epa.gov/gasoline-standards. While EPA 
expects the hearing to go forward as set forth above, please monitor 
the website or contact the person listed in the FOR FURTHER INFORMATION 
CONTACT section to determine if there are any updates. EPA does not 
intend to publish a document in the Federal Register announcing 
updates.
    If you require the services of a translator or special 
accommodations such as audio description, please pre-register for the 
hearing and describe your needs by March 16, 2023. EPA may not be able 
to arrange accommodations without advance notice.

Outline of this Preamble

I. Executive Summary
II. Background and History
III. Statutory Authority and Provisions To Remove the 1-psi Waver
IV. Petitions for Removal of the 1-psi Waiver and Supporting 
Documentation
V. MOVES Modeling Results
VI. Evaluation of Petitions for Removal of the 1-psi Waiver
VII. Statutory Provisions on Implementation and Effective Date
VIII. Fuel System Impacts
    A. Production
    B. Distribution
    C. Retail Operations
IX. Cost Impacts
X. Proposed Finding of Insufficient Supply and Delay of Effective 
Date
XI. Associated Regulatory Provisions
XII. Statutory and Executive Order Reviews
    A. Executive Order 12866: Regulatory Planning and Review and 
Executive Order 13563: Improving Regulation and Regulatory Review
    B. Paperwork Reduction Act (PRA)
    C. Regulatory Flexibility Act (RFA)
    D. Unfunded Mandates Reform Act (UMRA)
    E. Executive Order 13132: Federalism
    F. Executive Order 13175: Consultation and Coordination With 
Indian Tribal Governments
    G. Executive Order 13045: Protection of Children From 
Environmental Health Risks and Safety Risks
    H. Executive Order 13211: Actions Concerning Regulations That 
Significantly Affect Energy Supply, Distribution, or Use
    I. National Technology Transfer and Advancement Act (NTTAA) and 
1 CFR Part 51
    J. Executive Order 12898: Federal Actions To Address 
Environmental Justice in Minority Populations and Low-Income 
Populations

I. Executive Summary

    In this action, EPA is responding to requests from eight state 
governors to remove the 1-psi volatility waiver for gasoline-ethanol 
blends containing 10 percent ethanol beginning with the summer of 2023. 
The governors made their requests pursuant to CAA section 211(h)(5), 
which provides that the Administrator shall remove the 1-psi waiver via 
regulation upon a demonstration by a governor that the 1-psi waiver 
increases emissions in their state.
    After review of the modeling results presented by the governors in 
their requests, EPA is proposing to remove the 1-psi waiver in the 
following states: Illinois, Iowa, Nebraska, Minnesota, Missouri, Ohio, 
South Dakota, and Wisconsin.
    We recognize that the initial requests made by the governors of 
many of the states were submitted in the spring of 2022, such that a 
summer of 2023 effective date may have been possible, and seek comment 
on such an effective date. However, we have also received numerous 
petitions to delay the effective date of this action to at least 
2024.\1\ After consideration of the petitions, and given current timing 
considerations, we propose a finding of insufficient supply of gasoline 
in 2023, and therefore also propose an effective date of April 28, 2024 
for removal of the 1-psi waiver in all eight states, as described 
further in Sections IV and X.
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    \1\ We refer to these petitions as ``extension petitions'' 
throughout this proposal.
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II. Background and History

    EPA first took regulatory action to control the volatility of 
gasoline in 1987.\2\ Because higher gasoline volatility leads to higher 
evaporative emissions, EPA regulates the RVP--a measure of fuel 
volatility--of gasoline during summer months in order to reduce 
volatile organic compound (VOC) emissions that contribute to the 
formation of smog (ground-level ozone).\3\ The volatility of fuel 
depends on refineries' decisions in formulating their gasoline. 
Subsequent to EPA's actions, Congress enacted the CAA Amendments of 
1990, which included statutory volatility provisions for summer 
gasoline. These provisions largely codified EPA's regulatory approach, 
including establishing a 9.0 psi RVP standard for gasoline volatility 
in the summer.\4\ Because blending ethanol into gasoline increases the 
volatility of the resulting fuel due to chemical differences between 
ethanol and gasoline, Congress also codified a 1-psi volatility waiver 
for blends of gasoline and 10 percent ethanol (i.e., E10), allowing 
such blends to have a 1.0-psi higher RVP than otherwise allowed for 
gasoline, consistent with EPA's prior regulatory approach.\5\ This 
allowance only applies to gasoline-ethanol blends containing between 9 
and 10 percent ethanol (E10), and does not extend to gasoline-ethanol 
blends

[[Page 13760]]

containing greater than 10 and less than or equal to 15-percent ethanol 
(E15).\6\ The 1-psi waiver also does not apply to reformulated gasoline 
(RFG).
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    \2\ See 52 FR 31274 (August 19, 1987); 54 FR 11868 (March 22, 
1989); 55 FR 23658 (June 11, 1990).
    \3\ Gasoline must have volatility in the proper range to prevent 
driveability, performance, and emissions problems. If the volatility 
is too low, the gasoline will not ignite properly; if the volatility 
is too high, the vehicle may experience vapor lock. Importantly for 
this action, excessively high volatility also leads to increased 
evaporative emissions from the vehicle. Vehicle evaporative emission 
control systems are designed and certified on gasoline with a 
volatility of 9.0 psi RVP. Higher volatility gasoline may overwhelm 
the vehicle's evaporative control system, leading to a condition 
described as ``breakthrough'' of the cannister and mostly 
uncontrolled evaporative emissions.
    \4\ CAA section 211(h)(1); 42 U.S.C. 7545(h)(1). CAA section 
211(h)(1) requires EPA to establish volatility requirements--that 
is, a restriction on RVP--during the high ozone season. To implement 
these requirements, EPA defines ``high ozone season'' or ``summer 
season'' at 40 CFR 1090.80 as ``the period from June 1 through 
September 15 for retailers and wholesale purchaser consumers, and 
May 1 through September 15 for all other persons, or an RVP control 
period specified in a state implementation plan if it is longer.'' 
In general practice by industry and for purposes of this preamble, 
the high ozone season is referred to as the ``summer'' or ``summer 
season'' and gasoline produced to be used during the high ozone 
season is called ``summer gasoline.'' EPA's regulations do not 
impose any volatility requirements on any type of blend of gasoline 
outside of the summer season.
    \5\ CAA section 211(h)(4); 42 U.S.C. 7545(h)(4).
    \6\ See 40 CFR 1090.215(a), codifying the statutory 1-psi 
waiver.
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    This volatility waiver, at the time the provision was enacted, 
applied to a relatively small portion of the gasoline sold in the 
United States. Today, however, almost all gasoline sold is E10, and 
thus the 1-psi waiver increases the volatility of most gasoline.
    On April 28, 2022, eight governors submitted a petition for the 
removal of the 1-psi waiver for E10 in their states beginning in the 
summer of 2023, pursuant to CAA section 211(h)(5). On June 10, 2022, 
the Governor of Ohio also submitted a petition requesting the removal 
of the 1-psi waiver in that state.\7\ On July 21, 2022, the Governor of 
Kansas notified EPA that they were rescinding their request for removal 
of the 1-psi waiver in Kansas.\8\ On October 13, 2022, the Governor of 
North Dakota notified EPA that they were rescinding their request for 
removal of the 1-psi waiver in North Dakota.\9\ On December 21, 2022, 
the Governor of Missouri submitted a petition requesting the removal of 
the 1-psi waiver in that state.\10\ This notice refers to the eight 
remaining states as the ``petitioning states.'' The petitions included 
modeling results indicating reductions in VOCs, nitrogen oxides 
(NOX), and carbon monoxide (CO).
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    \7\ These petitions are available in the docket for this action.
    \8\ ``July 2022 Letter from Governor Laura Kelly,'' available in 
the docket for this action.
    \9\ ``October 2022 Letter from Governor Burgum,'' available in 
the docket for this action.
    \10\ This petition is also available in the docket for this 
action.
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III. Statutory Authority and Provisions To Remove the 1-psi Waver

    We are conducting a rulemaking to modify EPA's fuel quality 
regulations in 40 CFR part 1090 to remove the 1-psi waiver for the 
eight states that have requested it. Specifically, we are proposing to 
remove the 1-psi waiver that is applicable to fuel blends containing 
gasoline and 10 percent ethanol in Illinois, Iowa, Minnesota, Missouri, 
Nebraska, Ohio, South Dakota, and Wisconsin beginning in the summer of 
2024.
    CAA section 211(h)(5) was enacted as part of the Energy Policy Act 
of 2005 (EPAct), and provides that:

    Upon notification by the Governor of a State, with supporting 
documentation, that implementation of the waiver in section 
[211(h)(4)], would increase emissions that contribute to air 
pollution in any area of the state, the Administrator shall, by 
regulation, apply the volatility limit under [section 211(h)(1)].

    CAA section 211(h)(1) requires that gasoline volatility not exceed 
9.0 psi during the high ozone season, and that nonattainment areas have 
a lower (i.e., more stringent) RVP standard. Thus, regulatory action 
under CAA section 211(h)(5) would remove the 1-psi waiver from E10.
    Prior to the April 28, 2022 petition, no governor had ever 
submitted a CAA section 211(h)(5) request to EPA, and thus we are 
interpreting this statutory provision for the first time in this 
action. We find that the use of the prescriptive statutory language 
``shall'' provides limited if any discretion for EPA to consider other 
issues such as economic impacts of removing the 1-psi waiver. Such 
impacts are instead appropriately taken into consideration by a 
governor when deciding whether to submit a petition to EPA.\11\ EPA's 
role in this case is to evaluate the supporting documentation provided 
by the governors.\12\ If EPA concludes that the supporting 
documentation, as required by the statute, demonstrates emissions 
increases with the 1-psi volatility waiver in place, then CAA section 
211(h)(5) requires EPA to promulgate regulations to remove the 1-psi 
waiver.
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    \11\ Considerations like this were cited by the Governors of 
Kansas and North Dakota in rescinding their requests.
    \12\ Legislative history suggests that the supporting 
documentation need not be as stringent as that called for under 
Section 211(c)(4)(c) of the CAA. See Senate Report 106-426 at 12 
(September 28, 2000).
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    Additionally, we do not interpret the CAA as requiring a 
demonstration of a reduction in emissions of all pollutants that 
contribute to air pollution in the requesting states. Such a 
requirement could not have been contemplated by Congress, as lowering 
the volatility of fuel would be expected to have differing impacts on 
different emissions. Congress was silent on what air pollutants EPA 
should consider in responding to petitions for removal of the 1-psi 
waiver. Specifically, under CAA section 211(h)(5), EPA is to remove the 
1-psi waiver if it ``increase[s] emissions that contribute to air 
pollution.'' This contrasts with, for example, CAA section 
110(a)(2)(D)(i), which prohibits sources in a state from emitting ``any 
air pollutant which will contribute significantly to nonattainment'' in 
another state. Air pollution could result from a myriad of sources, 
including listed hazardous air pollutants, criteria pollutants, and 
greenhouse gases, and thus would appear to be a rather expansive term. 
Reducing RVP, however, is a volatility control measure as explained 
earlier in Section II. CAA section 211(h)(1) requires EPA to set RVP 
standards to address ``evaporative emissions.'' Additionally, EPA has 
consistently explained that adding 10 percent ethanol to gasoline 
causes roughly a 1.0 psi RVP increase in the blend's volatility, which 
is the premise for the 1-psi waiver contained in CAA section 211(h)(4) 
and the subject of this action.\13\ EPA is of the view, therefore, that 
it is reasonable to consider ``air pollution'' emanating from such 
emissions and thus, that it may be more appropriate to evaluate the 
impact of the 1-psi waiver on VOC emissions.
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    \13\ See, e.g., 52 FR 31274 at 31292 (August 19, 1987).
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    The U.S. EPA Motor Vehicle Emissions Simulator (MOVES) is an 
appropriate tool to use to model the emission impacts required by the 
statute. The MOVES runs performed by the states compared emissions from 
motor vehicles and nonroad vehicles and equipment with and without the 
1-psi waiver for E10 in each state in the summer. Similar analyses have 
been used to support prior EPA actions in removing federal and state 
fuel programs in the past.\14\
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    \14\ For example, on June 7, 2017, EPA published a final rule to 
relax the federal 7.8 psi RVP standard in the Nashville, TN area (82 
FR 26354) and on March 12, 2021, EPA published two final rules that 
removed approved regulations from the Kansas and Missouri SIPs that 
required the sale of 7.0 psi RVP gasoline in the Kansas City, KS-MO 
area (86 FR 14000 and 86 FR 14007).
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IV. Petitions for Removal of the 1-psi Waiver and Supporting 
Documentation

    During the fall of 2021, EPA received several letters from states 
requesting that EPA engage in a dialogue about mechanisms to provide 
parity between E10 and E15 with respect to gasoline volatility 
standards.\15\ Specifically, the letters referred to CAA section 
211(h)(5) and inquired about what type of ``supporting documentation'' 
should accompany such a request. EPA organized and participated in a 
series of meetings with representatives from various Midwestern states 
that had expressed interest in removing the 1-psi waiver, and in those 
meetings, EPA indicated that MOVES modeling would be an appropriate 
tool to use for this purpose given its ability to model the emissions 
impacts of changes in gasoline volatility and given our past

[[Page 13761]]

reliance on MOVES modeling runs in similar contexts.
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    \15\ See ``Letter from Governor Laura Kelly to Administrator 
Regan,'' October 13, 2021, and ``Letter from Governors Kim Reynolds, 
Pete Ricketts, Doug Burgum, Tim Walz, Michael Parson, Kristi Noem, 
and Tony Evers,'' November 4, 2021, available in the docket for this 
action.
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    On April 28, 2022, the Governors of Illinois, Iowa, Kansas, 
Minnesota, Nebraska, North Dakota, South Dakota, and Wisconsin 
submitted a joint petition to EPA for the removal of the 1-psi waiver 
for E10 in their respective states. The petition specifically requested 
the removal of the 1-psi waiver as a permanent solution to provide 
year-round E15 in those states beginning in the summer of 2023. As 
accompanying documentation, the petition provided quantified reductions 
in VOC, NOX, and CO emissions as a result of removing the 1-
psi waiver in each state based on MOVES modeling. Subsequent to this 
submittal, the Governors of Kansas and North Dakota rescinded their 
requests to remove the 1-psi waiver for E10 in those states.\16\ 
Therefore, we are not proposing to take any action on the 1-psi waiver 
in Kansas and North Dakota in this action.
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    \16\ July 28, 2022, Letter from Governor Kelly of Kansas to EPA, 
available in the docket for this action. October 13, 2022, Letter 
from Governor Burgum of North Dakota to EPA, available in the docket 
for this action.
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    On June 10, 2022, the Governor of Ohio also submitted a petition 
requesting the removal of the 1-psi waiver for E10 beginning in the 
summer of 2023. The petition provided quantified reductions in VOC, 
NOX, and CO emissions in Ohio based on MOVES modeling.
    On December 21, 2022, the Governor of Missouri also submitted a 
petition requesting the removal of the 1-psi waiver for E10 beginning 
in the summer of 2023. The petition provided quantified reductions in 
VOC, NOX, and CO emissions in Missouri based on MOVES 
modeling.
    Subsequent to submission of the petitions, all petitioning states 
except Missouri provided EPA with additional emissions modeling 
documentation, including for particulate matter (PM) and benzene.\17\ 
The original data submitted showed a decrease in VOC, NOX, 
and CO emissions with removal of the 1-psi waiver, while the additional 
data demonstrated an increase in PM for both nonroad and on-road 
emissions with removal of the 1-psi waiver. The benzene results 
demonstrated an increase in benzene on-road emissions, and a decrease 
in benzene nonroad emissions.
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    \17\ See ``Emissions Impacts of the Elimination of the 1-psi RVP 
Waiver for E10,'' May 9, 2022; ``Emissions Impacts of the 
Elimination of the 1-psi RVP Waiver for E10 in Ohio,'' June 10, 
2022, available in the docket for this action. While we have not yet 
received additional information from Missouri about other pollutants 
as we have received from the other petitioning states, we anticipate 
directionally similar trends.
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    All the petitioning states requested removal of the 1-psi waiver in 
all areas within their state for which the limitation under CAA section 
211(h)(1) applies. Therefore, the requests did not include areas within 
the states where RFG is required because the 1-psi waiver does not 
apply to RFG. The petitioning states also requested that the removal of 
the 1-psi waiver should take effect for the 2023 high ozone season, 
without further discussion. The states noted that rescinding the 1-psi 
waiver for E10 would support year-round sales of E15.

V. MOVES Modeling Results

    The petitioning states provided technical documentation with their 
petitions to demonstrate the reduction of emissions with the removal of 
the 1-psi waiver as required by CAA section 211(h)(5) in the form of 
MOVES modeling results.\18\ The results for each state were based on a 
single day in July 2023, which falls within the high ozone season. 
Comparative results demonstrate the change in emissions from the 
current 10.0 psi RVP standard to the alternative 9.0 psi RVP standard 
as contemplated by the statute.\19\ A summary of the emission impacts 
of removing the 1-psi waiver for E10 for each state is provided in 
Table V-1.\20\
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    \18\ EPA developed MOVES to estimate air pollution emissions 
from on-road and nonroad mobile sources.
    \19\ Further information about the MOVES runs, including inputs 
and nonroad data is available in the docket for this action.
    \20\ EPA's evaluation of the MOVES model input data and 
assumptions, and results, can be found in the MOVES Technical 
Support Document for this action.

                             Table V-1--Change of Mobile Source Emissions in 2023 MOVES3.01 Sources From 10.0 psi to 9.0 psi
--------------------------------------------------------------------------------------------------------------------------------------------------------
                                                                                         Pollutant/precursor
                                           -------------------------------------------------------------------------------------------------------------
                   State                        CO          NOX         VOC        PM2.5       PM10       Benzene     Toluene   Ethylbenzene    Xylene
                                             (percent)   (percent)   (percent)   (percent)   (percent)   (percent)   (percent)    (percent)    (percent)
--------------------------------------------------------------------------------------------------------------------------------------------------------
Illinois..................................      -0.19       -0.05        -0.9        0.09        0.10        -0.2        -1.5         -0.9         -0.9
Iowa......................................      -0.44       -0.09        -1.8        0.14        0.15        -0.1        -3.3         -2.1         -2.1
Minnesota.................................      -0.52       -0.09        -2.7        0.15        0.16        -1.3        -4.2         -3.0         -3.1
Missouri..................................      -0.41       -0.14       -0.66         N/A         N/A         N/A         N/A          N/A          N/A
Nebraska..................................      -0.48       -0.09        -2.6        0.17        0.18        -0.6        -4.4         -2.9         -3.0
Ohio......................................      -0.45       -0.13        -1.6        0.30        0.32        0.08        -2.8         -2.0         -2.0
South Dakota..............................      -0.53       -0.06        -2.9        0.08        0.08        -1.1        -4.8         -3.4         -3.3
Wisconsin.................................      -0.44       -0.10        -1.7        0.21        0.22        -0.3        -2.7         -1.8         -1.8
--------------------------------------------------------------------------------------------------------------------------------------------------------

    Each of the petitioning states' submissions demonstrated reductions 
in emissions of CO, NOX, and VOCs within the state upon 
removal of the 1-psi waiver. These demonstrated reductions are 
sufficient to fulfill the statutes' supporting documentation 
requirement. We seek comment on this data.

VI. Evaluation of Petitions for Removal of the 1-psi Waiver

    We have assessed the supporting documentation provided by the 
petitioning states and find that the MOVES modeling results submitted 
to EPA demonstrate a reduction in emissions of multiple pollutants upon 
removal of the 1-psi waiver for E10, as required under CAA section 
211(h)(5). In particular, the modeling demonstrated emissions 
reductions in CO, NOX, and VOCs. Emissions of these 
pollutants contribute to air pollution in the states.\21\ We note that 
the same documentation also shows an increase in emissions of other 
pollutants such as PM. As discussed in Section III, we do not interpret 
the statute as requiring reductions in all pollutants. Documentation of 
reductions in several

[[Page 13762]]

pollutants, including, in particular, VOCs, is sufficient.
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    \21\ Evaporative emissions from gasoline, referred to as 
volatile organic compounds (VOC), are precursors to the formation of 
tropospheric ozone and contribute to the nation's ground-level ozone 
problem. Exposure to ground level ozone can reduce lung function 
(thereby aggravating asthma or other respiratory conditions), 
increase susceptibility to respiratory infection, and may contribute 
to premature death in people with heart and lung disease.
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    Therefore, based on the governors' requests, we are proposing to 
remove the 1-psi waiver in the petitioning states based on the 
supporting documentation provided, as required by the CAA.

VII. Statutory Provisions on Implementation and Effective Date

    Under CAA section 211(h)(5)(C), the regulations removing the 1-psi 
waiver shall take effect on the later of: (1) the first day of the 
first high ozone season for the area that begins after the date of 
receipt of the notification; or (2) 1 year after the date of receipt of 
the notification. The high ozone season is defined in EPA's regulations 
as ``June 1 through September 15 for retailers and [wholesale purchaser 
consumers (WPCs)], and May 1 through September 15 for all other 
persons,'' which includes gasoline distribution terminals.\22\
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    \22\ 40 CFR 1090.80. We note that given the current definition 
of ``high ozone season,'' the later date will always be one year 
after receipt of the request from a governor.
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    Under this language, for the petition dated April 28, 2022, the 
later date is April 28, 2023. Therefore, the earliest date on which the 
removal of the 1-psi waiver for Illinois, Iowa, Nebraska, Minnesota, 
South Dakota, and Wisconsin could be effective is April 28, 2023. This 
date would be in advance of the high ozone season beginning May 1, 
2023. For the petition from Ohio, dated June 10, 2022, the later date 
is June 10, 2023. This would place the effective date within the 2023 
high ozone season (i.e., 10 days after the beginning of the high ozone 
season for retailers and WPCs, and 41 days after the beginning of the 
high ozone season for all other parties). Finally, for the petition 
from Missouri, dated December 21, 2022, the later date is December 21, 
2023.\23\ This would place the effective date after the 2023 high ozone 
season.
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    \23\ We recognize that the Missouri petition requested that the 
removal take effect for the 2023 high ozone season. However, such an 
effective date is not permissible under CAA section 211(h)(5)(C).
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    Further, under CAA section 211(h)(5)(C), the effective date can be 
extended if the Administrator, on his own motion or on petition from 
any person, after consultation with the Secretary of Energy, determines 
there would be an insufficient supply of gasoline in a state that has 
requested the removal of the 1-psi waiver for E10.\24\ The statute 
further provides that the effective date can be extended for not more 
than one year, and that the Administrator may renew the extension for 
two additional periods, each of which shall not exceed 1 year.
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    \24\ CAA section 211(h)(5)(C)(ii).
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    As described above, EPA is allowed to extend the effective date of 
the removal of the 1-psi waiver upon a finding of ``insufficient supply 
of gasoline in the [petitioning] state'' resulting from ``the 
promulgation of the regulations [to remove the 1-psi waiver].'' \25\ 
``Insufficient supply of gasoline'' is not defined in the statute, and 
thus EPA applies its expertise to interpret and apply the phrase in a 
manner that is consistent with the structure of the statute, historical 
application of similar or related provisions, and congressional intent. 
We interpret ``insufficient supply of gasoline'' to require a 
demonstration that gasoline supply disruptions are likely resulting 
from removal of the 1-psi waiver, such that the necessary quantities of 
gasoline may not be available in the states at the time they are 
required. It is particularly appropriate in this case to consider the 
possibility of supply disruptions, and the ability of the fuel to be 
physically produced and transported to the petitioning states because 
this action would call for a different grade of gasoline to be produced 
and transported to the appropriate states. In considering the 
likelihood of supply disruptions, we look to the entire production and 
distribution chain, from the refinery where gasoline is produced, 
through distribution systems such as pipelines and trucking, and 
ultimately to the retail station. This reading is also similar to EPA's 
interpretation of other provisions in section 211 that call for 
consideration of constraints on fuel supply when EPA is acting on 
petitions within the fuels program. For instance, CAA section 
211(k)(6)(A)(ii) allows EPA, after consultation with the Secretary of 
Energy, to extend the effective date for a state that has petitioned to 
opt into the RFG program for a period that is up to one year from the 
date of receipt of the petition upon a finding of insufficient domestic 
capacity to produce RFG. A related provision in CAA section 
211(k)(6)(B)(iii) would allow the Administrator to extend the effective 
date for areas within the ozone transport region established under CAA 
section 184 that opt into RFG, upon a finding of insufficient capacity 
to supply RFG. Like the phrase ``insufficient supply of gasoline'' in 
CAA section 211(h)(5)(C), the statute does not define either 
``insufficient domestic capacity'' or ``insufficient capacity to supply 
RFG.'' But in acting on petitions to opt-into RFG, EPA has explained 
that setting the effective date allows the Administrator to consider 
any sudden and unexpected increases in the demand for RFG on the local 
supply and distribution system that is caused by an opt-in.\26\
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    \25\ CAA section 211(h)(5)(C).
    \26\ 62 FR 30261, 30263 (June 3, 1997)(``Section 211(k)(6)(A) of 
the Act gives the Administrator discretion to ``establish an 
effective date * * * as he deems appropriate* * *.'' EPA interprets 
this provision to mean that it has broad discretion to consider any 
factors reasonably relevant to the timing of the effective date. 
This would include factors that affect industry and the potential 
opt-in area. The factors that affect industry could include 
productive capacity and capability, other markets for RFG, oxygenate 
supply, cost, lead time, supply logistics for the area, potential 
price spikes, and potential disruption to business.'')
---------------------------------------------------------------------------

    In contrast, the phrase ``insufficient supply of gasoline'' differs 
from other sub-provisions of CAA section 211 allowing for waivers of 
applicable requirements as well as implementation delays that use 
language such as ``inadequate domestic supply.'' \27\ The D.C. Circuit 
has provided guidance on the meaning of ``inadequate domestic supply'' 
in CAA section 211(o)(7)(A)(ii), finding that EPA may properly consider 
``supply side factors--such as production and import capacity,'' but 
not downstream effects.\28\ While the analysis supporting such findings 
is likely to be similar for these production factors, we find that 
under CAA section 211(h)(5), the analysis properly should consider 
production factors, as well as the distribution of fuel from the 
refinery, through the distribution chain, including pipelines and 
terminals, to the ultimate endpoint of the gasoline distribution chain, 
the retail station. CAA section 211(h)(5) explicitly contemplates the 
``supply of gasoline in the State,'' whereas CAA section 
211(o)(7)(A)(ii) did not further modify ``supply.'' \29\
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    \27\ See CAA section 211(m)(3)(C), 211(o)(7)(A)(ii).
    \28\ See Americans for Clean Energy v. EPA, 864 F.3d 691, 710 
(2017). Notably CAA section 211(o)(7)(A)(ii) does not specify the 
product that is to be inadequate or to whom the supply is 
inadequate. This is in contrast to 211(h)(5)(C)(ii) which provides 
that it is an insufficient supply of gasoline in the petitioning 
state.
    \29\ CAA section 211(h)(5)(A). [T]he Administrator shall, by 
regulation, apply, in lieu of the Reid vapor pressure limitation 
established by paragraph (4), the Reid vapor pressure limitation 
established by paragraph (1) to all fuel blends containing gasoline 
and 10 percent denatured anhydrous ethanol that are sold, offered 
for sale, dispensed, supplied, offered for supply, transported, or 
introduced into commerce in the area during the high ozone season.
---------------------------------------------------------------------------

    EPA's reading of ``adequate supply'' in CAA section 
211(c)(4)(C)(ii) would also appear to comport with our interpretation 
of CAA section 211(h)(5)(C) given that Congress intended for EPA to act 
within certain unique emergency circumstances to relieve supply 
disruptions within the ``motor fuel distribution system.'' \30\ And

[[Page 13763]]

while ``motor fuel distribution system'' is not defined in the statute, 
EPA's historical practice in granting waivers under section CAA section 
211(c)(4)(C)(ii) has been to consider all stages of the gasoline 
production and distribution system within states that are experiencing 
emergency circumstances.
---------------------------------------------------------------------------

    \30\ CAA section 211(c)(4)(C)(iii)(V).
---------------------------------------------------------------------------

    Finally, we note that consideration of the effective date for this 
action properly considers supply to the ultimate consumer given the 
statutory language ``in the State.'' Therefore, our analysis of 
``insufficient supply of gasoline'' properly considers all stages of 
the gasoline production and distribution system, from the refinery to 
the retail station.

VIII. Fuel System Impacts

    In this section, we discuss the potential impacts of removing the 
1-psi waiver in the petitioning states on the fuel production and 
distribution system, including impacts that would potentially affect 
gasoline refineries, pipelines, fuel terminals, retail stations, and, 
ultimately, consumers. Further detail on this topic is available in the 
``Technical Support Document for the Proposed Removal of the 1-psi 
Waiver.''
    In short, this proposed action would require a lower volatility 
conventional gasoline before oxygenate blending (CBOB) \31\ to be 
produced by refineries and distributed by pipelines and terminals, and, 
for the blended fuel, ultimately sold at retail stations in the 
petitioning states.\32\ For much of the area covered, the new lower RVP 
fuel would simply replace the existing fuel, in which case the impacts 
are primarily associated with the refinery changes needed to produce 
the new fuel. However, in many areas, this would be a new fuel in 
addition to the fuel designed to utilize the 1-psi waiver upon blending 
of 10 percent ethanol (e.g., a terminal or refinery that distributes 
gasoline to states both with and without the 1-psi waiver). In these 
areas, there would be additional impacts associated with fuel 
distribution system changes needed to distribute the additional grades 
(regular and premium) of the new lower RVP blendstocks.
---------------------------------------------------------------------------

    \31\ Gasoline before oxygenate blending (BOB) means gasoline for 
which a gasoline manufacturer has accounted for oxygenate (e.g., 
denatured fuel ethanol) added downstream. See 40 CFR 1090.90. BOB is 
subject to all requirements and standards that apply to gasoline 
under EPA's fuel quality regulations, and refineries typically 
formulate their BOBs with the intent that it will be blended 
downstream with ten percent ethanol content to maintain compliance 
with EPA and industry specifications. Conventional BOB (CBOB) is BOB 
produced or imported for areas outside of RFG areas otherwise known 
as conventional areas.
    \32\ Because the gasoline distribution system has been 
configured to utilize 10 percent ethanol and optimized to utilize 
the octane value of ethanol, we expect ethanol to be blended at 
least at the same levels it is blended today. Thus, we anticipate 
that E10 would continue to be the dominant form of gasoline supplied 
to the region, but would now be blended into a lower volatility 
blendstock produced by the refineries.
---------------------------------------------------------------------------

    We note first that volatility controls for gasoline differ across 
various states and regions within states. Summer gasoline for use in 
the continental U.S. must comply with either the federal RVP standard 
of 9.0 psi or the more stringent RVP standard of 7.8 psi, unless the 
summer gasoline is either for use in an RFG covered area, is subject to 
California's gasoline regulations, or EPA has waived preemption and 
approved a state request to adopt a more stringent RVP standard into a 
State Implementation Plan (SIP). Most of the U.S. utilizes 
``conventional gasoline,'' for which the federal RVP standard is 9.0 
psi, with a 1.0 psi allowance for gasoline blended with 10 percent 
ethanol. There are also areas that utilize conventional gasoline for 
which the federal RVP standard is 7.8 psi, and in such regions, the 1.0 
psi allowance also applies for gasoline blended with 10 percent 
ethanol.\33\ Several states have ``boutique'' low RVP fuel programs or 
SIP programs \34\ that allow the 1-psi waiver for gasoline blended with 
10 percent ethanol.\35\ Some boutique fuel programs, or SIP-approved 
fuel programs, however, disallow the 1-psi waiver for gasoline blended 
with 10 percent ethanol and in those areas, such gasoline must meet the 
applicable state RVP standard of either 9.0 psi, 7.8 psi, or 7.0 
psi.\36\ Additionally, approximately 30 percent of the gasoline sold in 
the U.S. is RFG, which must meet a 7.4 psi RVP standard.\37\ The 1-psi 
waiver does not apply to RFG, and thus E10 gasoline blended with 10 
percent ethanol that is sold in RFG areas must meet the 7.4 psi RVP 
standard. This proposed action would remove the 1-psi waiver only for 
conventional gasoline that is sold in the petitioning states and not 
such gasoline sold in RFG and SIP program areas. However, due to the 
interconnected nature of gasoline distribution, and the changes 
required for a new fuel type, impacts on gasoline quality and supply 
would be expected to extend beyond the petitioning states, as further 
described below.
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    \33\ 40 CFR 1090.215(a)(2), (b)(1).
    \34\ Of particular note for this action, seven counties in 
southeast Michigan that border Ohio have an RVP standard of 7.0 psi 
in the summer, with a 1-psi waiver for E10.
    \35\ See https://www.epa.gov/gasoline-standards/state-fuels.
    \36\ 40 CFR 1090.215(b)(3). See also https://www.epa.gov/gasoline-standards/state-fuels.
    \37\ 40 CFR 1090.215(a)(3). The Chicago and St. Louis areas are 
such RFG areas.
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A. Production

    We begin with a discussion of the necessary modifications to 
refineries to supply a lower volatility gasoline. There are 11 
petroleum refineries located within the petitioning states; that number 
increases to 40 refineries if refineries located in states that border 
the petitioning states are included. However, additional refineries 
outside of the immediate region may modify their operations to provide 
a lower RVP fuel, as currently some of the gasoline supply for the 
petitioning states also comes from refineries located further west, 
east, and south, including refineries in the Gulf Coast.\38\ For 
example, gasoline sold in Iowa is often produced by refineries located 
in Texas and distributed via pipeline. Therefore, this action could 
result in changes at refineries both within and outside of the Midwest 
region. Under EPA's current fuel quality regulations, most refineries 
producing gasoline for use in the petitioning states produce a CBOB 
with an RVP standard of 9.0 psi during the summer season, with the 1-
psi waiver allowing the final gasoline-ethanol blend to meet an RVP 
standard of 10.0 psi when 10 percent ethanol is added downstream. With 
the removal of the 1-psi waiver, refineries that produce CBOB for use 
within the petitioning states would be required to make changes to 
their operations to reduce the volatility of the CBOB distributed to 
these states to approximately (or slightly below) 8.0 psi in order to 
enable the final gasoline-ethanol blend to comply with the 9.0 psi RVP 
standard, which could have corresponding impacts on the supply of 
gasoline. For some refineries, removal of the 1-psi waiver may result 
in the refinery reducing the volatility of all the CBOB they produce. 
For other refineries, it may result in a choice to produce a new 8.0 
psi RVP CBOB for distribution to the petitioning states, while 
continuing to produce the current 9.0 psi RVP CBOB for distribution to 
other states.\39\ At this

[[Page 13764]]

time, we cannot predict which of the refineries that currently produce 
fuel for use in the petitioning states would choose to produce 8.0 psi 
RVP CBOB for use in the petitioning states. Unlike a nationwide change 
to the RVP of CBOB, the regional nature of this action means that not 
all refineries must adjust their refining processes to provide a lower 
RVP CBOB. While it is highly likely that refineries that supply 
gasoline only to the petitioning states would adjust their refinery 
processes to reduce the RVP of their CBOB, these refineries could 
choose to avoid the necessary investments and provide 9.0 psi RVP CBOB 
to non-petitioning states instead.
---------------------------------------------------------------------------

    \38\ According to the Energy Information Administration (EIA), 
64 million barrels of gasoline were shipped from PADD 3 into PADD 2, 
which corresponds to about 8 percent of the volume of gasoline 
consumed in PADD 2. Movements by Pipeline, Tanker, Barge and Rail 
between PAD Districts, PADD 3 to PADD 2; https://www.eia.gov/dnav/pet/pet_move_ptb_dc_R20-R30_mbbl_m.htm.
    \39\ Certain areas within the petitioning states and other 
states already have more stringent RVP standards during the summer. 
Gasoline that refineries produce for these areas would be unaffected 
by this proposed rule. Refineries that produce 7.8 psi RVP CBOB for 
the 7.8 psi RVP areas, or 7.4 psi RVP RBOB for RFG areas could 
expand production of these grades for use in these states rather 
than create a new grade at 8.0 psi RVP. This may reduce distribution 
cost complexity, but in exchange increase refinery production cost 
and lower gasoline production volume.
---------------------------------------------------------------------------

    Throughout the year, refineries must adjust the volatility of their 
gasoline--typically lowering volatility of the gasoline in the summer 
and increasing the volatility in the winter by adjusting the quantity 
of light hydrocarbons in their gasoline. Refineries typically control 
gasoline volatility by adjusting the amount of butane in gasoline, but 
sometimes they need to also modify the amount of pentane in gasoline. 
Refineries providing fuel to the petitioning states would have to 
modify their summertime production operations and potentially add 
capital equipment to accommodate the 1-psi lower RVP standard in the 
summer. A refinery's ability to adapt to the 1-psi lower RVP standard 
and the time that it takes depends on the refinery's structure, 
operations, and the crude slate they run. Further discussion of the 
changes we expect from refiners associated with removal of the 1-psi 
waiver is available in to the ``Technical Support Document for the 
Proposed Removal of the 1-psi Waiver.'' \40\
---------------------------------------------------------------------------

    \40\ Available in the docket for this action.
---------------------------------------------------------------------------

    In addition to contributing to gasoline's volatility, butane also 
contributes to gasoline's octane and volume. Thus, when removing 
butane, refineries must also make other changes to replace the lost 
octane in order to keep the product consistent and in compliance with 
EPA and industry specifications. Refineries could produce more alkylate 
or reformate, which are two high octane gasoline blendstocks, to make 
up the lost octane. We estimate that the amount of butane that would 
have to be removed to produce a gasoline 1 psi lower in RVP amounts to 
about 2 volume percent of the volume of gasoline that would be sold to 
the petitioning states, which will affect the supply of gasoline in 
those states.
    Regardless of how a refinery is modified to lower the RVP of 
gasoline, it will result in additional butane being produced by the 
refinery. If excess onsite butane storage capacity is available, the 
refinery has the option of saving excess butane on-site for use in 
winter gasoline production, which would minimize the cost impact of the 
removal of the 1-psi waiver. However, if excess butane storage is not 
available, the refinery would then need to store it offsite (e.g., in 
caverns), sell it, or export it. This may require additional butane 
rail cars and refinery upgrades for handling rail cars. Refineries may 
also utilize some portion of the butane as a feedstock to their 
alkylation unit. In the near term, the large additional influx of 
excess butane may exceed the existing storage capacity, transport 
capacity, amount desired in the markets, or alkylation unit capacity. 
This could then limit refinery flexibility to produce gasoline, further 
impacting supply and production costs.
    Given the high demand for gasoline in the summer months, refineries 
often begin producing summertime fuel for storage well ahead of the 
upcoming high ozone season. This process can begin as early as December 
of the year prior to the applicable high ozone season, and thus storage 
of a differing volatility of fuel could impact the refinery's ability 
to utilize the fuel the next summer without further modification.

B. Distribution

    As discussed above, this rulemaking would require a new lower RVP 
grade of gasoline to be produced by refineries that distribute gasoline 
to the petitioning states. In some areas, this may mean producing an 
additional grade of gasoline. An additional gasoline grade would 
require parties involved in gasoline distribution to reconfigure their 
pipelines, terminals, and operations in order to accommodate such a 
fuel grade. Such changes are likely to affect distribution both within 
and outside of the petitioning states given the interstate nature of 
gasoline distribution. There are three primary groups within the 
distribution chain that would be impacted: refineries, pipelines (with 
their breakout terminals), and downstream product terminals.
1. Refinery Distribution
    Most refineries have an onsite terminal with numerous product 
storage tanks wherein they accumulate and store the range of products 
that they produce prior to placing the products into the distribution 
system. Once a refinery accumulates a sufficient volume of a gasoline 
type and confirms that it meets the applicable gasoline specifications, 
the refinery then schedules the shipment of that batch of gasoline to 
downstream markets. Shipment can occur via an onsite product terminal 
analogous to that discussed in Section VIII.B.3 where trucks load 
product and deliver to retail stations. However, most gasoline is 
loaded onto product pipelines for delivery to downstream product 
terminals. In some cases, refineries also distribute product by rail or 
barge. For those refineries that distribute all, or even most, of their 
gasoline to the petitioning states, this proposal will have little 
impact on their distribution operations. They can switch over their 
existing product tanks to hold only the lower RVP gasoline blendstock. 
However, for those refineries that produce gasoline for both the 
petitioning states and non-petitioning states, they may need to add 
additional tanks, pipes, manifolds, and control systems to store the 
additional grades of gasoline. The time needed to plan, design, permit, 
and construct additional tankage is typically on the order of two or 
more years. Until this can be accomplished, the refinery may need to 
shift some or all of its production to the lower RVP blendstock.\41\ 
This could then result in a period where the market goes through a 
sorting out process wherein different refineries focus on different 
products and shift their historic markets, perhaps requiring more of 
one product or requiring another product to flow in from outside the 
petitioning states (e.g., from Gulf Coast refineries). All of this can 
have significant impacts on gasoline supply not only on the petitioning 
states, but also on the surrounding states. It may be that, due to 
tankage and logistical limitations, refineries serving both markets may 
all initially shift all of their production to the lower RVP 
blendstock. This would result in lower RVP fuel in the surrounding 
states and compound the overall impact on gasoline supply of butane 
removal.
---------------------------------------------------------------------------

    \41\ Alternatively, some refineries may shift all premium grade 
fuel to the lower RVP, while maintaining production of the lower RVP 
and 9.0 psi RVP CBOBs.
---------------------------------------------------------------------------

     In addition to tankage changes, the refineries would also need to 
adjust their operations and schedules for loading gasoline blendstock 
onto pipelines, barges, or rail in order to split their production into 
separate product streams. These logistical changes would initially take 
some period of time in order to occur smoothly and safely but should 
streamline over time.

[[Page 13765]]

2. Pipelines and Pipeline Breakout Terminals
    The majority of fuel in the U.S. flows from refineries to markets 
via pipeline systems. Because refineries are located throughout the 
Midwest, the pipeline companies must pick up these gasoline batches 
where they are located, which can be at the start, middle, or even near 
the end of the pipeline; the gasoline then moves to its destination 
markets. As discussed in Section VIII.B.1, some portion of gasoline 
produced for use in the petitioning states comes from refineries 
located outside the petitioning states.
    There are a number of pipeline systems serving the petitioning 
states, the vast majority of which serve both the petitioning states as 
well as non-petitioning states.\42\ The pipelines transport a wide 
variety of fuels and other products (e.g., gasoline, diesel, jet fuel, 
heating oil, petroleum blendstocks, etc.), including an array of 
different grades of gasoline (e.g., conventional gasoline, RFG, state 
specific grades, and regular and premium grades of each). Each grade 
and type of gasoline must be segregated from other grades and types to 
preserve the physical properties of each product. Consequently, the 
addition of the new lower RVP gasoline blendstocks required for the 
petitioning states would require significant changes in the operations 
of the pipeline systems. What was one large fuel market would now be 
divided in two, requiring smaller batch sizes, changes in scheduling, 
and in some cases cutting off historic supplies from some sources and 
making changes to find alternative sources of supply. There would thus 
be a period where the pipeline systems go through a planning and 
optimization process in order to adjust to the new fuel requirement. 
Decisions from refineries on whether they will supply a lower RVP CBOB, 
and at what volumes, would be necessary to inform the planning and 
optimization process by pipeline systems. All of this can have 
significant impacts on gasoline supply not only to the petitioning 
states, but also to the surrounding states in the short term. Having 
the wrong fuel grades in the wrong volume can result in an inability 
for the pipeline to move fuel in and out of tankage as needed, which, 
in turn, can result in significant fuel supply disruption not only for 
the gasoline grade in question, but also for all of the fuels shipped 
on the pipeline. For the longer term, due to the bifurcation of the 
market into different grades, some areas in the petitioning states may 
lose redundancy for supply, which may then lead to more frequent 
shortfalls in supply during times of disruption (e.g., refinery fire, 
pipeline outage, hurricane, etc.).
---------------------------------------------------------------------------

    \42\ See, ``Technical Support Document for the Proposed Removal 
of the 1-psi Waiver,'' available in the docket for this action.
---------------------------------------------------------------------------

    The most significant impact on pipeline operations from the 
bifurcation of the gasoline supply caused by a final action on this 
proposal, however, will be on pipeline breakout tankage operations. 
Breakout tankage is required at junctions where pipelines connect with 
differing schedules and flow rates. Thus, the pipelines typically need 
tankage to store every grade of product distributed on the pipeline, 
with the size and configuration of the tankage matched to the product 
and pipeline batch sizes. If new regular and premium grades of the 
lower RVP CBOB needs to be shipped on the pipeline, then it may require 
the addition of new tankage at these breakout tank facilities. The 
planning, permitting, and construction of such additional tankage would 
require two or more years. This is likely to be an issue at a number of 
breakout tankage facilities both inside and outside the petitioning 
states. Until this additional breakout tankage can be brought into 
service, an impacted pipeline serving the area may be restricted to 
distributing either the higher or lower RVP gasoline, limiting gasoline 
supply to either the petitioning states or the other surrounding 
states, and in turn restricting what the refineries shipping on the 
pipeline are able to produce if the pipeline restrictions do not allow 
for the distribution of a particular type of gasoline. Some pipelines 
may opt to carry one fuel grade and some the other, limiting the 
product offerings at the various downstream product terminals. As with 
the refineries, it may be that due to tankage and logistical 
limitations, pipelines currently serving both markets may initially 
shift all of their production to the lower RVP blendstock. This would 
result in lower RVP fuel in the surrounding states and compound the 
impact on supply of butane removal. Pipelines would have the option to 
blend in butane during gasoline transport to the states with the 1-psi 
waiver that are located at the end of the pipeline systems (e.g., North 
Dakota and Michigan). This would alleviate some of the excess butane 
produced from refineries in the affected states and could reduce 
consumer costs in the border states by blending up to 9.0 psi RVP 
gasoline. This method could ease some of the fungible pipeline 
bifurcation issues by allowing more of the lower RVP gasoline to be 
produced. However, similar to refineries, not all pipeline and terminal 
facilities currently have the existing infrastructure to utilize butane 
blending. Additional tankage and equipment may be needed to maximize 
the potential of this opportunity.
    Some pipeline companies operate a fungible distribution system. 
This allows them to collect a standard grade of gasoline from 
refineries into their system and ``transport'' the barrels quickly to 
their destination. The barrels delivered are not actually the purchased 
barrels from the refinery, but rather the same product meeting the same 
specifications from another refinery. An additional grade of gasoline 
would disrupt their ability to function as efficiently using the 
fungible system. This increases the complexity associated with ensuring 
products are able to be distributed to locations in the time frame 
needed to ensure supply to the market.
3. Product Terminals
    Moving gasoline to market also involves the downstream product 
terminals and bulk plants. The product terminals and bulk plants 
accumulate gasoline from pipelines and other bulk distribution systems 
and distribute the gasoline to retail outlets via tank trucks loaded at 
racks at the terminal. Each rack has the ability to load several 
different grades of gasoline depending on how they were constructed; 
all racks can load premium and regular gasoline, but some racks have 
added additional changes to accommodate additional grades of gasoline 
at the same time. The potential impact on product terminals varies 
depending on whether the terminals provide gasoline only in the 
petitioning states, or in non-petitioning states as well. Those 
terminals that only provide gasoline to the petitioning states would be 
little impacted, as they would simply take delivery of replacement 
grades of lower RVP CBOB beginning in the spring leading into the 
summer season. They would not have to contend with adding additional 
fuel grades and the tankage and logistics associated with them. This 
would most likely not be the case for terminals that serve areas both 
within and outside the petitioning states. If such terminals do not 
have sufficient onsite tankage capacity to handle the additional 
regular and premium grades of lower RVP CBOB, then they would need to 
either add the tankage or choose to focus on one market or the other. 
The decision to focus on a particular market or fuel type may also be 
dictated by a fuel marketer on the retail side. Both of these options 
could have fuel supply, cost, and price

[[Page 13766]]

impacts both within the petitioning states and in the surrounding areas 
the terminals serve. Approximately 75 such terminals are located close 
to the borders (i.e., 30 miles) between petitioning states and non-
petitioning states. These terminals are more likely to provide gasoline 
to both types of states and would need to change their gasoline 
distribution patterns if they lack extra tankage to handle the 
additional lower RVP gasoline grades.\43\ Since terminals can serve 
gasoline markets up to 200 miles away, the number of terminals impacted 
could be significantly greater.
---------------------------------------------------------------------------

    \43\ EIA. U.S. Energy Atlas--Oil and Natural Gas Maps. https://www.eia.gov/maps.
---------------------------------------------------------------------------

    Regardless of whether the terminals serve only the petitioning 
states, or also other states, the terminals would all be impacted to 
some degree by a somewhat more challenging transition in the spring 
from winter gasoline to summer gasoline, particularly in the first 
year. While this transition occurs every year as the terminals blend 
down the volatility of the gasoline they have in storage from the 
higher RVP of winter gasoline to the lower RVP of summer grades, the 
change of having to blend down to ~8.0 psi RVP CBOB instead of ~9.0 psi 
RVP CBOB would require additional time and incur additional cost. Due 
to blending realities, pipelines and terminals would request lower RVP 
fuel to blend down to a fuel that meets the RVP specifications; to 
achieve an ~8.0 psi RVP CBOB, blending of gasoline with an RVP as low 
as 6.0 psi is likely to be necessary. Terminals additionally would 
likely take steps to ensure tanks are drained as low as possible prior 
to receiving a lower RVP gasoline, which could add to timing 
constraints. This would likely occur more frequently at terminals near 
the border of the petitioning states.
4. Tank Trucks
    Moving gasoline to market also involves tank trucks that deliver 
the gasoline to the retail stations. In some respects, their operations 
should be little impacted by the lower RVP standard for gasoline in the 
petitioning states; they would simply pick up a different grade of 
gasoline from the product terminal than they did before. However, 
depending on the changes in product offering at the terminals, there 
may still be considerable stress put on their operations. If some 
refineries, pipelines, or terminals limit their product offering to 
either the lower or higher RVP grades, especially in the near term, 
then the tank trucks would need to shift their operations accordingly. 
In some cases, this would be expected to increase the distances 
traveled, which may in turn require the purchase of additional tank 
trucks and hiring of additional drivers. As with the rest of the 
distribution system, this can all be accomplished, but would take some 
time for the market to respond and optimize around the new norms.

C. Retail Operations

    The proposed removal of the 1-psi waiver and resulting transition 
from 10.0 psi RVP gasoline to 9.0 psi RVP gasoline received from the 
terminal should be minor for the retail stations--they would simply 
take delivery of the lower volatility gasoline from the terminal. The 
most noticeable effects would be seen at retail stations near the 
borders of states maintaining the 1-psi waiver, as the cost of 9.0 psi 
RVP gasoline within the petitioning states is likely to be higher than 
that of 10.0 psi RVP gasoline across the border in the other states. 
The retailers within the petitioning states may have to charge higher 
prices to recoup this cost, which could result in consumers 
preferentially choosing to refill at stations across the border when 
possible.\44\ The retail operations located near state lines on the 
border of petitioning and non-petitioning states may have issues 
scheduling gasoline shipments to their retail outlets if tank trucks 
are shipping their gasoline from terminals located further away and if 
there is an initial shortage of tank truck operators, particularly at 
the beginning of the transition to the new lower RVP fuel.
---------------------------------------------------------------------------

    \44\ This phenomenon is observed today in SIP and RFG regions.
---------------------------------------------------------------------------

IX. Cost Impacts

    There are associated costs with the changes to the refining and 
distribution systems described in Section VIII. Part of the cost would 
be incurred by the refining sector, while another portion would be 
incurred by the gasoline distribution system. This is discussed briefly 
below with a more in-depth discussion in the ``Technical Support 
Document for the Proposed Removal of the 1-psi waiver.''
    The refining sector would incur a cost in several different ways. 
The largest portion of the cost is the lost opportunity cost for having 
to sell the removed butane at market prices for butane instead of 
blending it into high value summer gasoline. There are also additional 
capital and operating costs as described in Section VIII.A that would 
need to be recouped over time. Two separate refinery modeling studies 
conducted by Mathpro examined the long-term refining cost for removing 
the 1-psi waiver--one conducted for the Renewable Fuels Association 
(RFA) \45\ and another conducted for the International Council on Clean 
Transportation (ICCT).\46\
---------------------------------------------------------------------------

    \45\ ``Assessment of a 1-psi reduction in the RVP of 
Conventional Gasoline Blendstock (CBOB) in the Summer Gasoline 
Season,'' prepared for Renewable Fuels Association by Mathpro, 
December 1, 2021.
    \46\ Refining Economics of a National Low Sulfur, Low RVP 
Gasoline Standard; prepared for the International Council for Clean 
Transportation.
---------------------------------------------------------------------------

    Both Mathpro studies estimated refining costs to be about 2 cents 
per gallon, but their analysis assumed three years of lead time and 
assumed that the entire nationwide conventional gasoline pool would be 
converted over to the lower RVP gasoline. We seek comment on whether 
these costs might be different if EPA were to use different 
assumptions, including a shorter lead time and only regional 
application to the petitioning states, as opposed to analysis of the 
change nationwide. Mathpro did not assess or quantify the additional 
costs that would likely be incurred by the fuels distribution system to 
distribute 8.0 psi RVP CBOB in addition to the present slate of 
gasoline grades currently being provided. As described in Section 
VIII.B, the need to distribute an additional grade of gasoline would 
require changes in the operations of pipeline, terminals, and tank 
trucks, and in some cases would be expected to require an additional 
set of gasoline storage tanks or tank trucks. There likely would be 
other costs associated with distributing an additional grade of 
gasoline. Since conventional gasoline consumed in the Midwest would be 
divided between the two different gasoline grades, gasoline batch sizes 
would be smaller in many cases, which would increase the cost of 
distributing both gasoline grades. Furthermore, if refineries serving 
the Midwest only produce one of the two gasoline grades, it could mean 
that other refineries would have to produce a portion of the gasoline 
previously served by that refinery, and the gasoline sold by both of 
those refineries would likely need to be moved further distances than 
before, increasing the distribution cost for both refineries' gasoline. 
Similarly, if downstream terminals decide to only sell one of the two 
gasoline grades, which requires that they sell solely into petitioning 
states or non-petitioning states, it likely would require that the 
trucks that distribute the gasoline from that terminal would have to 
travel further distance than they currently do.
    The cost estimates detailed in the ``Technical Support Document for

[[Page 13767]]

Proposed Removal of the 1-psi Waiver'' reflect cost impacts assuming 
the fuels market has had the chance to make the necessary investments 
to accommodate the change. In the near term, while the market is going 
through the iterative process of deciding what parties produce and 
distribute which fuels for which markets and before the necessary 
capital has been invested, constructed, and put into service, the 
impacts on supply could have a substantially higher impact on the 
gasoline prices consumers pay. The current gasoline supply shortfall in 
the Midwest may provide one indication of what supply-induced gasoline 
price impacts may be. As further described in the ``Technical Support 
Document for Proposed Removal of the 1-psi Waiver,'' in late summer the 
low volume of gasoline storage in the Midwest grew to about 8 percent 
lower than the five-year minimum levels due to a supply shortfall 
there. This may explain why regular grade conventional gasoline was 
priced about 28[cent] per gallon higher in the Midwest than Gulf Coast 
prices compared to previous years. This low gasoline inventory in the 
Midwest may be the cause of even larger impact on RFG pricing. Such 
large price impacts due to short term supply circumstances, 
particularly as compared to cost impacts, are possible should a drop in 
supply occur as a result of the removal of the 1-psi waiver in 2024.

X. Proposed Finding of Insufficient Supply and Delay of Effective Date

    In this action, we are proposing an effective date of April 28, 
2024, for all petitioning states. After consideration of the extension 
petitions, we are proposing a 2024 effective date after determining 
that a 2023 implementation would result in insufficient supply of 
gasoline in the petitioning states.\47\ Our finding of insufficient 
supply is based on an assessment of three potential supply constraints: 
(1) The already low gasoline inventories; (2) The need for early 
coordination between various parties to make the necessary physical 
changes to the gasoline production and distribution infrastructure and 
the associated lead time required; and (3) The physical loss of supply 
necessary to produce a lower RVP gasoline. We believe that these 
constraints are likely to lead to supply disruptions in the petitioning 
states.
---------------------------------------------------------------------------

    \47\ While the statute contemplates extensions of up to one 
year, with opportunity to renew the extension for an additional two 
years, the ``renew'' language indicates a need for EPA to do so in a 
subsequent, separate action.
---------------------------------------------------------------------------

    Gasoline inventories in the Midwest are currently well below the 
five-year average minimum levels, and at the end of January 2022, were 
the lowest recorded since 1990 which the earliest year data is 
available.\48\ An emergency refinery closure in the Midwest has reduced 
the volume of gasoline available in the region, and as of February 2023 
the refinery has remained shuttered. The gasoline inventories typically 
recover over the winter in the Midwest; however, they have remained low 
and this could lead to a shortfall in supply when gasoline demand 
increases in the summer of 2023. EIA estimates a further increase in 
gasoline demand in 2023 compared to 2022.\49\ If realized, this 
increased demand may be difficult to meet even without a change to the 
gasoline volatility standard.
---------------------------------------------------------------------------

    \48\ Total Motor Gasoline Stocks, Weekly Stocks; Petroleum and 
Other Liquids, US Energy Information Administration; https://www.eia.gov/dnav/pet/pet_stoc_wstk_dcu_nus_w.htm.
    \49\ EIA. Short Term Energy Outlook (STEO). October 2022.
---------------------------------------------------------------------------

    Second, timing considerations to supply a new lower RVP CBOB would 
require coordinated investments, planning, and actions between 
refineries, pipelines and other fuel distribution companies, terminals, 
and retail outlets. Typically, this coordination occurs before winter 
to provide the fuel system a chance to make the proper preparations. We 
are now past the point in the calendar (late fall of the prior year) 
when such coordination typically occurs. We are also entering into the 
timeframe when refineries already have to begin producing fuel for use 
in the summer months. As such, refineries would not have sufficient and 
appropriate notice to begin modifying their fuel supply for the 2023 
summer season.
    Third, a reduction in supply is likely to occur simply as a result 
of the changes necessary to refine and distribute the lower RVP 
gasoline to the petitioning states. The removal of the light 
hydrocarbons to produce the lower RVP gasoline is estimated to reduce 
gasoline supply to the petitioning states by two percent, if refineries 
have the necessary equipment to remove, store, or sell the removed 
light hydrocarbons. It is likely that this necessary equipment would 
not be available for all refineries in the summer of 2023, thus 
complicating the process, and requiring an additional reduction in 
supply. The distribution system is likely to need additional fuel 
storage capacity to store and distribute the new fuel. These changes 
are also unlikely to be accommodated ahead of the 2023 summer season. 
At this time, we cannot quantify the gasoline supply impacts as a 
result of distribution issues; we seek input on such potential impacts.
    Reductions in gasoline supply due to lowering the RVP of CBOB at 
the refinery could be made up through additional supply from other 
refineries in areas such as the Gulf Coast, or through additional 
production from Midwest refineries. However, without appropriate notice 
of this change, such reductions are not possible for the 2023 summer 
season. Additionally, the distribution infrastructure, including 
pipelines, terminals, and tank trucks, could allow for the distribution 
of lower RVP CBOB to the petitioning states. However, for such changes 
to mitigate any supply concerns, various market participants would 
require significant notice--first to the refineries at the beginning of 
the distribution chain, and then to each party downstream. Inherent in 
requiring a different grade of gasoline is a reduction in the 
fungibility of the gasoline supply system, thus increasing the 
likelihood of supply disruptions due to intermittent disruptions such 
as natural disasters and unanticipated refinery or pipeline shutdowns.
    Based on the above assessment, EPA finds that the removal of the 1-
psi waiver in petitioning states, if it were to take effect for the 
2023 high ozone season, would result in an insufficient supply of 
gasoline in those states. As a result, EPA is proposing to delay the 
effective date of the removal of the 1-psi wavier by one year to April 
28, 2024. This is the latest possible date for the initial petitions 
from Illinois, Iowa, Minnesota, Nebraska, South Dakota, and Wisconsin. 
We find it appropriate to have a single effective date for all 
petitioning states.
    We seek comment on this proposed effective date, including whether 
this effective date provides sufficient notice to affected parties, and 
whether any necessary changes could be made in this timeframe to 
accommodate a summer 2024 effective date, or whether a renewal of the 
extension may be necessary.

XI. Associated Regulatory Provisions

    We are proposing a new designation and associated product transfer 
document (PTD) language for summer CBOB in states where the 1-psi 
waiver for E10 has been removed under CAA section 211(h)(5).\50\ 
Designations and PTD language requirements help ensure that batches of 
fuel are distributed and used in a manner consistent with EPA's fuel 
quality requirements. Without

[[Page 13768]]

proper designation, summer gasolines with different volatilities 
intended for use in different areas may get commingled in a fungible 
system, causing the introduction and use of non-compliant gasoline in 
areas that require lower volatility fuels in the summer. Similarly, PTD 
language serves to ensure that parties in the fuel distribution chain 
are aware of the designation of the fuel and accompanying Federal 
requirements for the distribution and use of the fuel. Because we are 
proposing requirements for new grade of summer CBOB in this action, we 
need to create a new designation and accompanying PTD language to 
ensure that the new CBOB is distributed and used consistent with the 
RVP requirements.
---------------------------------------------------------------------------

    \50\ The designation and PTD language requirements for gasoline 
are located at 40 CFR 1090.1010 and 1090.1110, respectively.
---------------------------------------------------------------------------

    We are proposing that gasoline manufacturers would designate summer 
CBOB for use in states where we have removed the 1-psi waiver as ``Low-
RVP Summer CBOB.'' We are also proposing related changes to the PTD 
language requirements so that gasoline manufacturers that produce Low-
RVP Summer CBOB could accurately and consistently describe the fuel 
designation. All other designation and PTD provisions would still apply 
(e.g., those designations related to the blending of ethanol). We 
believe this approach is the most straight-forward method for updating 
the designation and PTD requirements for Low-RVP Summer CBOB, and we 
seek comment on the new designation and related PTD language.
    Based on discussions with affected stakeholders, we also considered 
whether it would be possible to use the existing designations of ``7.8 
Summer CBOB'' for 9.0 psi RVP areas or the ``SIP-controlled Summer 
CBOB'' designation. The potential advantage of using existing 
designations is that the fuel distribution system would not have to 
adjust to the new product designation. However, we believe that there 
are potential disadvantages to using existing designations for low-RVP 
CBOB. First, we believe that most CBOB manufacturers would wish to 
target an RVP level of slightly higher than 7.8 psi to meet the 9.0 psi 
RVP standard. This could result in a CBOB that simultaneously could not 
lawfully use the 7.8 psi RVP designation because the RVP was too high 
or use the 9.0 psi RVP designation because the CBOB may be treated 
fungibly with other CBOBs that are intended for the 1.0-psi waiver for 
E10. Second, in the case of SIP-controlled Summer CBOB, the designation 
is not intuitive because this action is not part of any SIP and may 
result in confusion on the part of parties that distribute such CBOB. 
Because we believe that a new designation would much more effectively 
communicate to parties in the distribution chain how the low-RVP CBOB 
could lawfully be used more effectively than the existing designations, 
the use of the existing designations for such CBOB is not appropriate 
and are proposing a new designation as discussed above. Nevertheless, 
we seek comment on whether and how we could use the existing 
designations for this CBOB instead of creating a new designation.
    In addition to proposing regulatory changes to effectuate the 
removal of the 1-psi waiver in the petitioning states, we are also 
proposing a regulatory mechanism for states to request the 
reinstatement of the 1-psi waiver under CAA section 211(h)(5). This 
would be available for the petitioning states, as well as any other 
state for which EPA removes the 1-psi waiver upon a request under CAA 
section 211(h)(5) in the future. During discussions with states and 
stakeholders, parties inquired whether such a provision could be 
included in this action. Regulations associated with such a request 
would provide all states with criteria under which such a request could 
be made and granted. We are proposing regulations allowing for the 
reinstatement of the 1-psi waiver that are modeled on the existing 
regulations in 40 CFR part 1090.295 that allow for the removal of 7.8 
psi low-RVP fuels programs.\51\ Removal of federal 7.8 psi low-RVP fuel 
programs is appropriately conditioned on either the ability of a state 
to demonstrate continued maintenance of the relevant ozone national 
ambient air quality standard (NAAQS) in an area (i.e., the state may 
have included emission reductions from the federal 7.8 psi low-RVP fuel 
in its plan for the area to maintain the relevant ozone NAAQS) or the 
ability of the state to demonstrate that removing the requirement for 
the federal 7.8 psi low-RVP fuel in a nonattainment area would not 
interfere with any applicable requirement for attainment or reasonable 
further progress or any other applicable requirement of the CAA (i.e., 
the state may have included emission reductions from the federal 7.8 
psi low-RVP fuel in its plan for the area to attain the relevant ozone 
NAAQS).\52\ We are proposing to only require a state to request the 
reinstatement of the 1-psi waiver in order for EPA to reinstate it, 
however, if the state has relied on the 1-psi waiver removal in a SIP, 
either pending or approved, the disposition of that SIP would need to 
be resolved prior to reinstatement of the 1-psi waiver. We are also 
proposing that, to provide appropriate notice and lead time for 
corresponding changes to fuel supply, we would again revise our 
regulations through a notice-and-comment rulemaking process to fully 
implement the request. We seek comment on this approach.
---------------------------------------------------------------------------

    \51\ In this action we are not reopening the regulations 
associated with removal of a federal 7.8 psi low-RVP program in a 
given area (40 CFR 1090.295) or the regulations that allow states to 
opt-out of the federal RFG program (40 CFR 1090.290). Any comments 
related to these provisions will be treated as beyond the scope of 
this action.
    \52\ See CAA section 110(l).
---------------------------------------------------------------------------

XII. Statutory and Executive Order Reviews

    Additional information about these statutes and Executive Orders 
can be found at http://www.epa.gov/laws-regulations/laws-and-executive-orders.

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

    This action is a significant regulatory action that was submitted 
to the Office of Management and Budget (OMB) for review. Any changes 
made at the suggestion or recommendation of OMB have been documented in 
the docket.

B. Paperwork Reduction Act (PRA)

    This action does not impose any new information collection burden 
under the PRA. OMB has previously approved the information collection 
activities contained in the existing regulations and has assigned OMB 
control number 2060-0731. This action proposes the removal of the 1-psi 
waiver in eight states. It does not alter practices used by the 
existing recordkeeping and reporting requirements, nor does it change 
the number or type of respondents and the manner in which they satisfy 
the fuel designation and PTD requirements.

C. Regulatory Flexibility Act (RFA)

    I certify that this action will not have a significant economic 
impact on a substantial number of small entities under the RFA. In 
making this determination, EPA concludes that the impact of concern for 
this rule is any significant adverse economic impact on small entities 
and that the agency is certifying that this rule will not have a 
significant economic impact on a substantial number of small entities 
because the proposed rule has no net burden on the small entities 
subject to the rule.
    Small entities that will be subject to this action include small 
refiners (which are defined at 13 CFR 121.201) that produce or 
distribute gasoline in

[[Page 13769]]

Illinois, Iowa, Minnesota, Missouri, Nebraska, Ohio, South Dakota, or 
Wisconsin. This action proposes to remove the 1-psi waiver for E10 in 
these states and EPA is not aware of any small refiners that produce or 
distribute gasoline or diesel fuel in these states. Thus, there would 
be no burden from this action on any small refiner. Furthermore, the 
removal of the 1-psi waiver in these states does not substantively 
alter the regulatory requirements on parties that make and distribute 
gasoline. We have therefore concluded that this action will have no net 
regulatory burden for all directly regulated small entities.

D. Unfunded Mandates Reform Act (UMRA)

    This action does not contain an unfunded mandate of $100 million or 
more as described in UMRA, 2 U.S.C. 1531-1538, and does not 
significantly or uniquely affect small governments. This action 
implements mandates specifically and explicitly set forth in CAA 
section 211(h)(5) and we believe that this action represents the least 
costly, most cost-effective approach to achieve the statutory 
requirements.

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 states, or on the distribution of power 
and responsibilities among the various levels of government.

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

    This action does not have tribal implications as specified in 
Executive Order 13175. This action will be implemented at the state 
level and would affect gasoline refiners, blenders, marketers, 
distributors, and importers. Tribal governments would be affected only 
to the extent they produce, purchase, and use gasoline. Thus, Executive 
Order 13175 does not apply to this action.

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

    EPA interprets Executive Order 13045 as applying only to those 
regulatory actions that concern environmental health or safety risks 
that the EPA has reason to believe may disproportionately affect 
children, per the definition of ``covered regulatory action'' in 
section 2-202 of the Executive Order. This action is not subject to 
Executive Order 13045 because it implements specific standards 
established by Congress in statutes.

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

    This action is not a ``significant energy action'' because it is 
not likely to have a significant adverse effect on the supply, 
distribution, or use of energy. This action proposes the removal of the 
1-psi waiver for eight states. As discussed in Section VIII, it will 
require changes to the production and distribution of gasoline, which 
is expected to have some short- and long- term impacts on gasoline 
supply and cost in the affected areas, but we believe the market will 
be able to accommodate the change without any significant disruption.

I. National Technology Transfer and Advancement Act (NTTAA) and 1 CFR 
Part 51

    This action does not involve technical standards.

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

    Executive Order 12898 (59 FR 7629, February 16, 1994) 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 (people of color and/or Indigenous 
peoples) and low-income populations.
    EPA believes that this action does not have disproportionately high 
and adverse human health or environmental effects on communities with 
environmental justice concerns. This action proposes the removal of the 
1-psi waiver in eight states, which could result in the reduction of 
several pollutants, including VOCs, NOX, and benzene as 
modeled through MOVES. Other pollutants may increase, such as PM.

List of Subjects in 40 CFR Part 1090

    Environmental protection, Administrative practice and procedure, 
Air pollution control, Fuel additives, Gasoline, Petroleum, Renewable 
fuel.

Michael S. Regan,
Administrator.

    For the reasons set forth in the preamble, EPA proposes to amend 40 
CFR part 1090 as follows:

PART 1090--REGULATION OF FUELS, FUEL ADDITIVES, AND REGULATED 
BLENDSTOCKS

0
1. The authority citation for part 1090 continues to read as follows:

    Authority:  42 U.S.C. 7414, 7521, 7522-7525, 7541, 7542, 7543, 
7545, 7547, 7550, and 7601.

Subpart C--Gasoline Standards

0
2. Amend Sec.  1090.215 by revising paragraph (b)(3) to read as 
follows:


Sec.  1090.215  Gasoline RVP Standards.

* * * * *
    (b) * * *
    (3)(i) RFG and SIP-controlled gasoline that does not allow for the 
ethanol 1.0 psi waiver does not qualify for the special regulatory 
treatment specified in paragraph (b)(1) of this section.
    (ii) Gasoline subject to the 9.0 psi maximum RVP per-gallon 
standard in paragraph (a)(1) of this section in the following areas is 
excluded from the special regulatory treatment specified in paragraph 
(b)(1) of this section:

Table 1 to Paragraph (b)(3)(ii)--Areas Excluded From the Ethanol 1.0 psi
                                 Waiver
------------------------------------------------------------------------
             State                  Counties          Effective date
------------------------------------------------------------------------
Illinois......................  All............  April 28, 2024.
Iowa..........................  All............  April 28, 2024.
Minnesota.....................  All............  April 28, 2024.
Missouri......................  All............  April 28, 2024.
Nebraska......................  All............  April 28, 2024.
Ohio..........................  All............  April 28, 2024.
South Dakota..................  All............  April 28, 2024.
Wisconsin.....................  All............  April 28, 2024.
------------------------------------------------------------------------

* * * * *
0
3. Add Sec.  1090.297 to read as follows:


Sec.  1090.297  Procedures for reinstating the 1.0 psi RVP allowance 
for E10.

    (a) EPA may approve a request from a state asking to reinstate the 
ethanol 1.0 psi waiver specified in Sec.  1090.215(b)(1) for any area 
(or portion of an area) specified in Sec.  1090.215(b)(3)(ii) if it 
meets the requirements of paragraph (b) of this section. If EPA 
approves such a request, an effective date will be set as specified in 
paragraph (c) of this section. EPA will notify the state in writing of 
EPA's action on the request

[[Page 13770]]

and the effective date of the reinstatement upon approval of the 
request.
    (b) The request must be signed by the governor of the state, or the 
governor's authorized representative, and must include all the 
following:
    (1) A geographic description of each area (or portion of such area) 
that is covered by the request.
    (2) A description of all the means in which emissions reduction 
from the removal of the ethanol 1.0 psi waiver are relied upon in any 
approved SIP or in any submitted SIP that has not yet been approved by 
EPA, if applicable.
    (3) For any area covered by the request where emissions reductions 
from the removal of the ethanol 1.0 psi waiver are relied upon as 
specified in paragraph (b)(2) of this section, the request must include 
the following information:
    (i) Identify whether the state is withdrawing any submitted SIP 
that has not yet been approved.
    (ii)(A) Identify whether the state intends to submit a SIP revision 
to any approved SIP or any submitted SIP that has not yet been 
approved, which relies on emissions reductions from the removal of the 
ethanol 1.0 psi waiver, and describe any control measures that the 
state plans to submit to EPA for approval to replace the emissions 
reductions from the removal of the ethanol 1.0 psi waiver.
    (B) A description of the state's plans and schedule for adopting 
and submitting any revision to any approved SIP or any submitted SIP 
that has not yet been approved.
    (iii) If the state is not withdrawing any submitted SIP that has 
not yet been approved and does not intend to submit a revision to any 
approved SIP or any submitted SIP that has not yet been approved, 
describe why no revision is necessary.
    (4) The governor of a state, or the governor's authorized 
representative, must submit additional information needed to administer 
the reinstatement of the ethanol 1.0 psi waiver upon request by EPA.
    (c)(1) Except as specified in paragraph (c)(2) of this section, EPA 
will set an effective date of the reinstatement of the ethanol 1.0 psi 
waiver as requested by the governor, or the governor's authorized 
representative, but no less than 90 days from EPA's written 
notification to the state approving the reinstatement request.
    (2) Where emissions reductions from the removal of the ethanol 1.0 
psi waiver are included in an approved SIP or any submitted SIP that 
has not yet been approved, EPA will set an effective date of the 
reinstatement of the ethanol 1.0 psi waiver as requested by the 
governor, or the governor's authorized representative, but no less than 
90 days from the effective date of EPA approval of the SIP revision 
that removes the emissions reductions from the ethanol 1.0 psi waiver, 
and, if necessary, provides emissions reductions to make up for those 
from the ethanol 1.0 psi waiver reinstatement.
    (d) EPA will publish a notice in the Federal Register announcing 
the approval of any ethanol 1.0 psi waiver reinstatement request and 
its effective date.
    (e) Upon the effective date for the reinstatement of the ethanol 
1.0 psi waiver in a subject area (or portion of a subject area) 
included in an approved request, the ethanol 1.0 psi waiver will apply 
in such subject area.
0
4. Amend Sec.  1090.1010 by redesignating paragraph (a)(2)(iii) as 
(a)(2)(iv) and adding a new paragraph (a)(2)(iii) to read as follows:


Sec.  1090.1010  Designation requirements for gasoline and regulated 
blendstocks.

    (a) * * *
    (2) * * *
    (iii) If the CBOB is excluded from the special regulatory treatment 
for ethanol under Sec.  1090.215(b)(3)(ii), Low-RVP Summer CBOB.
* * * * *
0
5. Amend Sec.  1090.1110 by redesignating paragraph (b)(2)(i)(C) as 
(b)(2)(i)(D) and adding a new paragraph (b)(2)(i)(C) to read as 
follows:


Sec.  1090.1110  PTD requirements for gasoline, gasoline additives, and 
gasoline regulated blendstocks.

* * * * *
    (b) * * *
    (2) * * *
    (i) * * *
    (C) ``Low-RVP CBOB. This product does not meet the requirements for 
summer reformulated gasoline.''
* * * * *
[FR Doc. 2023-04375 Filed 3-3-23; 8:45 am]
BILLING CODE 6560-50-P