[Federal Register Volume 66, Number 12 (Thursday, January 18, 2001)]
[Rules and Regulations]
[Pages 5002-5193]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 01-2]



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Part V





Environmental Protection Agency





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40 CFR Parts 69, 80, and 86



Control of Air Pollution From New Motor Vehicles: Heavy-Duty Engine and 
Vehicle Standards and Highway Diesel Fuel Sulfur Control Requirements; 
Final Rule

  Federal Register / Vol. 66, No. 12 / Thursday, January 18, 2001 / 
Rules and Regulations  

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ENVIRONMENTAL PROTECTION AGENCY

40 CFR Parts 69, 80, and 86

[AMS-FRL-6923-7]
RIN 2060-AI69


Control of Air Pollution from New Motor Vehicles: Heavy-Duty 
Engine and Vehicle Standards and Highway Diesel Fuel Sulfur Control 
Requirements

AGENCY: Environmental Protection Agency.

ACTION: Final rule.

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SUMMARY: The pollution emitted by diesel engines contributes greatly to 
our nation's continuing air quality problems. Even with more stringent 
heavy-duty highway engine standards set to take effect in 2004, these 
engines will continue to emit large amounts of nitrogen oxides and 
particulate matter, both of which contribute to serious public health 
problems in the United States. These problems include premature 
mortality, aggravation of respiratory and cardiovascular disease, 
aggravation of existing asthma, acute respiratory symptoms, chronic 
bronchitis, and decreased lung function. Numerous studies also link 
diesel exhaust to increased incidence of lung cancer. We believe that 
diesel exhaust is likely to be carcinogenic to humans by inhalation and 
that this cancer hazard exists for occupational and environmental 
levels of exposure.
    We are establishing a comprehensive national control program that 
will regulate the heavy-duty vehicle and its fuel as a single system. 
As part of this program, new emission standards will begin to take 
effect in model year 2007, and will apply to heavy-duty highway engines 
and vehicles. These standards are based on the use of high-efficiency 
catalytic exhaust emission control devices or comparably effective 
advanced technologies. Because these devices are damaged by sulfur, we 
are also reducing the level of sulfur in highway diesel fuel 
significantly by mid-2006. The program provides substantial flexibility 
for refiners, especially small refiners, and for manufacturers of 
engines and vehicles. These options will ensure that there is 
widespread availability and supply of the low sulfur diesel fuel from 
the very beginning of the program, and will provide engine 
manufacturers with the lead time needed to efficiently phase-in the 
exhaust emission control technology that will be used to achieve the 
emissions benefits of the new standards.
    We estimate that heavy-duty trucks and buses today account for 
about one-third of nitrogen oxides emissions and one-quarter of 
particulate matter emissions from mobile sources. In some urban areas, 
the contribution is even greater. This program will reduce particulate 
matter and oxides of nitrogen emissions from heavy duty engines by 90 
percent and 95 percent below current standard levels, respectively. In 
order to meet these more stringent standards for diesel engines, the 
program calls for a 97 percent reduction in the sulfur content of 
diesel fuel. As a result, diesel vehicles will achieve gasoline-like 
exhaust emission levels. We are also finalizing more stringent 
standards for heavy-duty gasoline vehicles, based in part on the use of 
the low sulfur gasoline that will be available when the standards go 
into effect.
    The clean air impact of this program will be dramatic when fully 
implemented. By 2030, this program will reduce annual emissions of 
nitrogen oxides, nonmethane hydrocarbons, and particulate matter by a 
projected 2.6 million, 115,000 and 109,000 tons, respectively. We 
project that these reductions and the resulting significant 
environmental benefits of this program will come at an average cost 
increase of about $2,000 to $3,200 per new vehicle in the near term and 
about $1,200 to $1,900 per new vehicle in the long term, depending on 
the vehicle size. In comparison, new vehicle prices today can range 
well over $100,000 for larger heavy-duty vehicles. We estimate that 
when fully implemented the sulfur reduction requirement will increase 
the cost of producing and distributing diesel fuel by about five cents 
per gallon.

DATES: This rule will become effective March 19, 2001. The 
incorporation by reference of certain publications listed in this rule 
is approved by the Director of the Office of Federal Register as of 
March 19, 2001.

ADDRESSES: Comments: All comments and materials relevant to today's 
action have been placed in Public Docket No. A-99-06 at the following 
address: U.S. Environmental Protection Agency (EPA), Air Docket (6102), 
Room M-1500, 401 M Street, SW, Washington, DC 20460 (on the ground 
floor in Waterside Mall) from 8:00 a.m. to 5:30 p.m., Monday through 
Friday, except on government holidays. You can reach the Air Docket by 
telephone at (202) 260-7548 and by facsimile at (202) 260-4400. We may 
charge a reasonable fee for copying docket materials, as provided in 40 
CFR part 2.

FOR FURTHER INFORMATION CONTACT: Margaret Borushko, U.S. EPA, National 
Vehicle and Fuel Emissions Laboratory, 2000 Traverwood, Ann Arbor MI 
48105; Telephone (734) 214-4334, FAX (734) 214-4816, E-mail 
[email protected]

SUPPLEMENTARY INFORMATION:

Regulated Entities

    This action will affect you if you produce or import new heavy-duty 
engines which are intended for use in highway vehicles such as trucks 
and buses, or produce or import such highway vehicles, or convert 
heavy-duty vehicles or heavy-duty engines used in highway vehicles to 
use alternative fuels, or produce or import light-duty highway diesel 
vehicles. It will also affect you if you produce, import, distribute, 
or sell highway diesel fuel, or sell nonroad diesel fuel.
    The following table gives some examples of entities that may have 
to follow the regulations. But because these are only examples, you 
should carefully examine the regulations in 40 CFR parts 69, 80, and 
86. If you have questions, call the person listed in the FOR FURTHER 
INFORMATION CONTACT section of this preamble:

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                                     NAICS
            Category                Codes a     SIC  Codes       Examples of potentially regulated entities
----------------------------------------------------b-----------------------------------------------------------
Industry........................       336112         3711  Engine and Truck Manufacturers
                                       336120
Industry........................       811112         7533  Commercial Importers of Vehicles and
                                       811198         7549  Vehicle Components
Industry........................       324110         2911  Petroleum Refiners
Industry........................       422710         5171  Diesel Fuel Marketers and Distributors
                                       422720         5172
industry........................       484220         4212  Diesel Fuel Carriers

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                                       484230        4213
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a North American Industry Classifications System (NAICS).
b Standard Industrial Classification (SIC) system code.

Access to Rulemaking Documents Through the Internet

    Today's final rule is available electronically on the day of 
publication from the Environmental Protection Agency Internet Web site 
listed below. Electronic copies of the preamble, regulatory language, 
Regulatory Impact Analysis, and other documents associated with today's 
final rule are available from the EPA Office of Transportation and Air 
Quality (formerly the Office of Mobile Sources) Web site listed below 
shortly after the rule is signed by the Administrator. This service is 
free of charge, except any cost that you incur for connecting to the 
Internet.
    Environmental Protection Agency Web Site: http://www.epa.gov/fedrgstr/ (Either select a desired date or use the Search feature.)
    Office of Transportation and Air Quality (OTAQ) Web Site: http://www.epa.gov/otaq/ (Look in ``What's New'' or under the ``Heavy Trucks/
Busses'' topic.)
    Please note that due to differences between the software used to 
develop the document and the software into which document may be 
downloaded, changes in format, page length, etc. may occur.

Table of Contents

I. Overview
    A. What Requirements Are Being Set?
    1. Heavy-Duty Emission Standards
    2. Fuel Quality Standards
    B. Why is EPA Taking This Action?
    1. Heavy-Duty Vehicles Contribute to Serious Air Pollution 
Problems
    2. Technology-Based Solutions
    3. Basis for Action Under the Clean Air Act
    C. Putting This Rule in Perspective
    1. Diesel Popularity
    2. Past Progress and New Developments
    3. Tier 2 Emissions Standards
    4. Mobile Source Air Toxics Rulemaking
    5. Nonroad Engine Standards and Fuel
    6. State Initiatives
    7. Retrofit Programs
    8. Actions in Other Countries
II. The Air Quality Need and Projected Benefits
    A. Overview
    B. Public Health and Welfare Concerns
    1. Health and Welfare Concerns Raised During Public Hearings
    2. Ozone and its Precursors
    a. Health and Welfare Effects From Short-Term Exposures to Ozone
    b. Current and Future Nonattainment Status With the 1-Hour Ozone 
NAAQS
    c. Public Health and Welfare Concerns from Prolonged and 
Repeated Exposures to Ozone
    3. Particulate Matter
    a. Health and Welfare Effects
    b. Attainment and Maintenance of the PM10 NAAQS
    c. Public Health and Welfare Concerns from Exposure to Fine PM
    d. Other Welfare Effects Associated with PM
    e. Conclusions Regarding PM
    4. Diesel Exhaust
    a. Potential Cancer Effects of Diesel Exhaust
    b. Noncancer Effects of Diesel Exhaust
    5. Other Criteria Pollutants
    6. Other Air Toxics
    a. Benzene
    b. 1,3-Butadiene
    c. Formaldehyde
    d. Acetaldehyde
    e. Acrolein
    f. Dioxins
    7. Other Welfare and Environmental Effects
    a. Acid Deposition
    b. Eutrophication and Nitrification
    c. Polycyclic Organic Matter Deposition
    d. Visibility and Regional Haze
    C. Contribution From Heavy-Duty Vehicles
    1. NOX Emissions
    2. PM Emissions
    3. Environmental Justice
    D. Anticipated Emissions Benefits
    1. NOX Reductions
    2. PM Reductions
    3. NMHC Reductions
    4. Additional Emissions Benefits
    a. CO Reductions
    b. SOX Reductions
    c. Air Toxics Reductions
    E. Clean Heavy-Duty Vehicles and Low-Sulfur Diesel Fuel are 
Critically Important for Improving Human Health and Welfare
III. Heavy-Duty Engine and Vehicle Standards
    A. Why Are We Setting New Heavy-Duty Standards?
    B. Emission Control Technologies for Heavy-Duty Vehicles and 
Engines
    C. What Engine and Vehicle Standards are We Finalizing?
    1. Heavy-Duty Engine Exhaust Emissions Standards
    a. FTP Standards
    b. Supplemental Provisions for HD Diesel Engines (SET & NTE)
    c. Crankcase Emissions Control
    d. On-Board Diagnostics (OBD)
    2. Heavy-Duty Vehicle Exhaust Emissions Standards
    a. FTP Standards
    b. Supplemental Federal Test Procedure
    c. On-Board Diagnostics (OBD)
    3. Heavy-Duty Evaporative Emission Standards
    D. Incentives for Early Introduction of Clean Engines and 
Vehicles
    E. Feasibility of the New Engine and Vehicle Standards
    1. Feasibility of Stringent Standards for Heavy-Duty Diesel
    a. Meeting the PM Standard
    b. Meeting the NOX Standard
    c. Meeting the NMHC Standard
    d. Meeting the Crankcase Emissions Requirements
    e. The Complete System
    2. Feasibility of Stringent Standards for Heavy-Duty Gasoline
    3. Feasibility of the New Evaporative Emission Standards
    F. Need for Low Sulfur Diesel Fuel
    1. Catalyzed Diesel Particulate Filters and the Need for Low 
Sulfur Fuel
    a. Inhibition of Trap Regeneration Due to Sulfur
    b. Loss of PM Control Effectiveness
    c. Increased Maintenance Cost for Diesel Particulate Filters Due 
to Sulfur
    2. Diesel NOX Catalysts and the Need for Low Sulfur 
Fuel
    a. Sulfur Poisoning (Sulfate Storage) on NOX 
Adsorbers
    b. Sulfate Particulate Production and Sulfur Impacts on 
Effectiveness of NOX Control Technologies
    3. What About Sulfur in Engine Lubricating Oils?
    G. Fuel Economy Impact of High Efficiency Control Technologies
    1. Diesel Particulate Filters and Fuel Economy
    2. NOX Control Technologies and Fuel Economy
    3. Emission Control Systems for 2007 and Net Fuel Economy 
Impacts
    H. Review of the Status of Heavy-Duty Diesel NOX 
Emission Control Technology
IV. Our Program for Controlling Highway Diesel Sulfur
    A. Highway Diesel Sulfur Standards for Refiners and Importers
    1. Standards and Deadlines that Refiners and Importers Must Meet
    2. Temporary Compliance Option for Refiners and Importers
    a. Generating Credits
    b. Using Credits
    c. How Long Will Credits Last?
    d. Additional Limitations on Credit Trading for Some States
    3. What Information Must Refiners/Importers Submit to Us?
    4. Impacts of the Highway Diesel Fuel Program
    a. Ensures Adequate Supplies of Highway Diesel Fuel
    b. Ensures Widespread Availability of Low Sulfur Diesel Fuel
    c. Provides Lower Costs to Refineries
    d. Misfueling Concerns Should Be Minimized

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    e. Summary
    B. What Provisions Apply in the Geographic Phase-in Area?
    1. What Is the Geographic Phase-in Area and How Was it 
Established?
    2. Highway Diesel Provisions for GPA Refiners
    3. How Do Refiners Apply for an Extension of the GPA Gasoline 
Program?
    4. Required Reporting for GPA Refiners
    C. Hardship Provisions for Qualifying Refiners
    1. Hardship Provisions for Qualifying Small Refiners
    a. Qualifying Small Refiners
    b. How Do We Define Small Refiners?
    c. What Options Are Available for Small Refiners?
    d. How Do Small Refiners Apply for Small Refiner Status?
    2. Farmer Cooperative Refiners Will Benefit From the Flexible 
Provisions Available to Other Refiners
    3. General Hardship Provisions
    a. Temporary Waivers from Low Sulfur Diesel Requirements in 
Extreme Unforseen Circumstances
    b. Temporary Waivers Based on Extreme Hardship Circumstances
    D. Technological Feasibility of the Low Sulfur Diesel Fuel 
Program
    1. What Technology Will Refiners Use?
    2. Have These Technologies Been Commercially Demonstrated?
    3. Feasibility of Distributing Low Sulfur Highway Diesel Fuel
    E. What Are the Potential Impacts of the Low Sulfur Diesel 
Program on Lubricity and Other Fuel Properties?
    1. What Is Lubricity and Why Might It Be a Concern?
    2. Today's Action on Lubricity: a Voluntary Approach
    3. What Are Today's Actions on Fuel Properties Other than 
Sulfur?
    F. How Are State Programs Affected by the Low Sulfur Diesel 
Program?
    1. State Preemption
    2. What Provisions Apply in Alaska?
    a. Today's Action Regarding the 500 ppm Standard in Alaska
    b. Why Are We Treating Alaska Uniquely?
    3. What Provisions Apply in American Samoa, Guam, and the 
Commonwealth of Northern Mariana Islands?
    a. Today's Action Regarding the Highway Diesel Fuel Standard in 
the Territories
    b. Why Are We Treating These Territories Uniquely?
    G. Refinery Air Permitting
V. Economic Impact
    A. Cost for Diesel Vehicles to Meet Emissions Standards
    1. Summary of New System and Operating Costs
    2. New System Costs for NOX and PM Emission Control
    3. Operating Costs Associated With NOX and PM Control
    B. Cost for Gasoline Vehicles to Meet the New Emissions 
Standards
    1. Summary of New System Costs
    2. Operating Costs Associated With Meeting the Heavy-Duty 
Gasoline Standard
    C. Cost of Fuel Change
    1. Refinery Costs
    2. Highway Diesel Fuel Supply
    3. Cost of Lubricity Additives
    4. Distribution Costs
    a. Distribution Costs Under the Fully Implemented Program
    b. Distribution Costs During the Initial Years
    5. Benefits of Low-sulfur Diesel Fuel for the Existing Diesel 
Fleet
    D. Aggregate Costs
    E. Cost Effectiveness
    1. What Is the Cost Effectiveness of This Program?
    2. Comparison With Other Means of Reducing Emissions
    F. Does the Value of the Benefits Outweigh the Cost of the 
Standards?
    1. What Was Our Overall Approach to the Benefit-Cost Analysis?
    2. What Are the Significant Limitations of the Benefit-Cost 
Analysis?
    3. How Has the Benefit-Cost Analysis Changed from Proposal?
    4. What Are the Benefits in the Years Leading up to 2030?
    5. What Were the Results of the Benefit-Cost Analysis?
VI. Requirements for Engine and Vehicle Manufacturers
    A. Compliance with Standards and Enforcement
    1. Allowable Maintenance
    2. Emission Data Waivers
    3. Crankcase Emissions
    4. Non-Conformance Penalties
    5. Idle CO Standards
    B. Compliance With Phase-in Schedules
    C. Averaging, Banking, and Trading
    D. FTP Changes to Accommodate Regeneration of Exhaust Emission 
Controls
    E. Improvements to the Test Procedures
    F. Certification Fuel
    G. Misfueling Concerns for Light-and Heavy-duty Diesel Vehicles
    H. In-Use Compliance Levels During the Transition Years to New 
Technologies
VII. Highway Diesel Fuel Program: Compliance, Enforcement and 
Downstream Provisions
    A. General Provisions
    1. Definition of Diesel Fuel Covered by This Program
    2. Relationship to Highway Diesel Standards
    B. What Are the Requirements for Refiners and Importers?
    1. General Requirements
    2. Refiner and Importer Temporary Compliance Option Provisions 
and the Credit Trading Program
    a. Early Credits Program
    b. Credit Use in a Credit Deficit Situation
    c. Resolving Issues of Invalid Credits
    d. Compliance Provisions
    e. Additional Provisions for Importers of Diesel Fuel and for 
Foreign Refiners Subject to the Temporary Compliance Option and 
Hardship Provisions
    3. Refiner Hardship Provisions
    a. General Refiner Hardship Provisions
    b. Small Refiner Hardship Provisions
    c. Relief for Refiners Supplying Gasoline to the Tier 2 
Geographic Phase-In Area (GPA)
    C. What Requirements Apply Downstream of the Refinery or Import 
Facility?
    1. Downstream Enforcement of the Standards
    2. Other Provisions
    a. Implementation Dates
    b. Product Segregation and Contamination
    c. Diesel Fuel Pump Labeling
    3. Use of Used Motor Oil in New Diesel Vehicles
    4. Use of Kerosene in Diesel Fuel
    5. Use of Diesel Fuel Additives
    D. What Are the Testing and Sampling Methods and Requirements?
    1. Diesel Fuel Testing Requirements and Test Methods
    2. Diesel Fuel Sampling Methods
    E. What Are the Recordkeeping, Reporting and Product Transfer 
Document Requirements?
    1. Registration of Refiners and Importers
    a. All Refiners and Importers
    b. Prospective Small Refiners
    c. Refiners Seeking an Extension of the GPA Gasoline Sulfur 
Standards
    2. Pre-Compliance Reports
    a. All Refiners
    b. Small Refiners
    c. GPA Refiners
    3. Annual Compliance Reports
    a. All Refiners
    b. Small Refiners
    4. Initial Confirmation of 15 ppm Fuel Production
    5. Product Transfer Documents (PTDs)
    a. Diesel Fuel
    b. Additives
    6. Recordkeeping Requirements
    7. Record Retention
    F. Are There Any Exemptions From the Highway Diesel Fuel 
Requirements?
    1. Research and Development
    2. Racing Vehicles
    3. Military Fuel
    G. Liability and Penalty Provisions for Noncompliance
    1. General
    2. What Is the Liability That Additive Manufacturers and 
Distributors, and Parties That Blend Additives into Diesel Fuel, Are 
Subject To?
    a. General
    b. Liability When the Additive Is Designated as Complying with 
the 15 ppm Sulfur Standard
    c. Liability When the Additive Is Designated as Having a 
Possible Sulfur Content Greater than 15 ppm
    H. How Will Compliance With the Sulfur Standards Be Determined?
VIII.Standards and Fuel for Nonroad Diesel Engines
IX. Public Participation
X. Administrative Requirements
    A. Administrative Designation and Regulatory Analysis
    B. Regulatory Flexibility Analysis
    1. Need for and Objectives of the Rule
    2. Summary of Significant Public Comments on the IRFA
    3. Types and Number of Small Entities
    4. Reporting, Recordkeeping and Other Compliance Requirements
    5. Regulatory Alternatives To Minimize Impact on Small Entities
    C. Paperwork Reduction Act

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    D. Intergovernmental Relations
    1. Unfunded Mandates Reform Act
    2. Executive Order 13084: Consultation and Coordination with 
Indian Tribal Governments
    E. National Technology Transfer and Advancement Act
    F. Executive Order 13045: Children's Health Protection
    G. Executive Order 13132: Federalism
    H. Congressional Review Act
XI. Statutory Provisions and Legal Authority

I. Overview

    This rule covers the second of two phases in a comprehensive 
nationwide program for controlling emissions from heavy-duty engines 
(HDEs) and vehicles. It builds upon the phase 1 program we recently 
finalized (65 FR 59896, October 6, 2000). That action affirmed the 50 
percent reduction in emissions of oxides of nitrogen ( NOX) 
from 2004 model year highway diesel engines, set in 1997 (62 FR 54693, 
October 21, 1997), and set new emission standards for heavy-duty 
gasoline-fueled engines and vehicles for 2005.
    This second phase of the program looks beyond 2004, based on the 
use of high-efficiency exhaust emission control devices and the 
consideration of the vehicle and its fuel as a single system. In 
developing this rule, we took into consideration comments received in 
response to the advance notice of proposed rulemaking (64 FR 26142, May 
13, 1999) and the notice of proposed rulemaking (NPRM) (65 FR 35430, 
June 2, 2000), including comments provided at five public hearings last 
June.
    This program will result in particulate matter (PM) and 
NOX emission levels that are 90 percent and 95 percent below 
the standard levels in effect today, respectively. In order to meet 
these more stringent standards for diesel engines, the rule mandates a 
97 percent reduction in the sulfur content of diesel fuel. The heavy-
duty engine standards will be effective starting in the 2007 model year 
and the low sulfur diesel fuel needed to facilitate the standards will 
be widely available in September 2006. As a result, diesel vehicles 
will achieve gasoline-like exhaust emission levels, in addition to 
their inherent advantages over gasoline vehicles with respect to fuel 
economy, lower greenhouse gas emissions, and lower evaporative 
hydrocarbon emissions. The rule also includes more stringent standards 
for heavy-duty gasoline vehicles. In addition to its impact on heavy-
duty vehicle emissions, this rule will make clean diesel fuel available 
in time for implementation of the light-duty Tier 2 standards.
    The standards will result in substantial benefits to public health 
and welfare and the environment through significant reductions in 
emissions of NOX, PM, nonmethane hydrocarbons (NMHC), carbon 
monoxide (CO), sulfur oxides (SOX), and air toxics. We 
project that by 2030, this phase 2 program will reduce annual emissions 
of NOX, NMHC, and PM by 2.6 million, 115,000 and 109,000 
tons, respectively. These emission reductions will prevent 8,300 
premature deaths, over 9,500 hospitalizations, and 1.5 million work 
days lost. All told the benefits of this rule equal $70.3 billion. A 
sizeable part of the benefits in the early years of this program come 
from large reductions in the amount of direct and secondary PM caused 
by the existing fleet of heavy-duty vehicles. These reductions are due 
to the use of the higher quality diesel fuel in these vehicles.

A. What Requirements Are Being Set?

    There are two basic parts to this program: (1) New exhaust emission 
standards for heavy-duty highway engines and vehicles, and (2) new 
quality standards for highway diesel fuel. The systems approach of 
combining the engine and fuel standards into a single program is 
critical to the success of our overall efforts to reduce emissions, 
because the emission standards will not be feasible without the fuel 
change. The feasibility of the emission standards is based on the use 
of high-efficiency exhaust emission control devices that would be 
damaged by sulfur in the fuel. This rule, by providing extremely low 
sulfur diesel fuel, will also enable cleaner diesel passenger vehicles 
and light-duty trucks. This is because the same pool of highway diesel 
fuel also services these light-duty diesel vehicles, and these vehicles 
can employ technologies similar to the high-efficiency heavy-duty 
exhaust emission control technologies that will be enabled by the fuel 
change. We believe these technologies are needed for diesel vehicles to 
comply with our Tier 2 emissions standards for light-duty highway 
vehicles (65 FR 6698, February 10, 2000).
    We believe that this systems approach is a comprehensive way to 
enable effective new technologies for clean diesel, affecting all sizes 
of highway diesel engines, and may translate to future reductions from 
diesel engines used in nonroad applications too. The fuel change, in 
addition to enabling new technologies, will also produce emissions and 
maintenance benefits in the existing fleet of highway diesel vehicles. 
These benefits will include reduced sulfate PM and sulfur oxides 
emissions, reduced engine wear and less frequent oil changes, and 
longer-lasting exhaust gas recirculation (EGR) components on engines 
equipped with EGR. Heavy-duty gasoline vehicles will also be expected 
to have much lower emissions due to the transfer of recent technology 
developments for light-duty applications, and the recent action taken 
to reduce sulfur in gasoline as part of the Tier 2 rule.
    The basic elements of the rule are outlined below. Detailed 
provisions and justifications for our rule are discussed in subsequent 
sections.
1. Heavy-Duty Emission Standards
    We are finalizing a PM emissions standard for new heavy-duty 
engines of 0.01 grams per brake-horsepower-hour (g/bhp-hr), to take 
full effect for diesels in the 2007 model year.1 We are also 
finalizing standards for NOX and NMHC of 0.20 g/bhp-hr and 
0.14 g/bhp-hr, respectively. These NOX and NMHC standards 
will be phased in together between 2007 and 2010, for diesel engines. 
The phase-in will be on a percent-of-sales basis: 50 percent from 2007 
to 2009 and 100 percent in 2010. This phase-in schedule differs 
somewhat from the proposed schedule for reasons explained in Section 
III. Gasoline engines will be subject to these standards based on a 
phase-in requiring 50 percent compliance in the 2008 model year and 100 
percent compliance in the 2009 model year. This phase-in schedule also 
differs from that proposed for reasons explained in Section III. In 
addition, we are finalizing our proposal to include turbocharged 
diesels in the existing crankcase emissions prohibition, effective in 
2007.
---------------------------------------------------------------------------

    \1\ Note that throughout this preamble we refer to diesel and 
gasoline vehicles and engines. We tend to use those terms given the 
preponderance of vehicles using diesel fuel or gasoline fuel in the 
U.S. heavy-duty highway market. However, when we refer to a diesel 
engine, we generally mean any engine using the diesel cycle. When we 
refer to a gasoline engine or vehicle, we generally mean any Otto-
cycle vehicle or engine. Therefore, the emission standards discussed 
throughout this preamble apply equally to engines and vehicles 
fueled by alternative fuels, unless otherwise specified in the 
regulatory text accompanying today's rule.
---------------------------------------------------------------------------

    Standards for complete HDVs will be implemented on the same 
schedule as for gasoline engine standards. For certification of 
complete vehicles between 8500 and 10,000 pounds gross vehicle weight 
rating (GVWR), the standards are 0.2 grams per mile (g/mi) for 
NOX, 0.02 g/mi for PM, 0.195 g/mi for NMHC, and 0.032 g/mi 
for formaldehyde.2 For vehicles between

[[Page 5006]]

10,000 and 14,000 pounds, the standards are 0.4 g/mi for 
NOX, 0.02 g/mi for PM, 0.230 g/mi for NMHC, and 0.040 g/mi 
for formaldehyde. These standards levels are roughly comparable to the 
engine-based standards in these size ranges. Note that these standards 
will not apply to vehicles above 8500 pounds that we classify as 
medium-duty passenger vehicles as part of our Tier 2 program.
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    \2\ Vehicle weight ratings in this rule refer to GVWR (the curb 
weight of the vehicle plus its maximum recommended load of 
passengers and cargo) unless noted otherwise.
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    Finally, we are adopting new evaporative emissions standards for 
heavy-duty engines and vehicles, effective on the same schedule as the 
gasoline engine and vehicle exhaust emission standards. The new 
standards for 8500 to 14,000 pound vehicles are 1.4 and 1.75 grams per 
test for the 3-day diurnal and supplemental 2-day diurnal tests, 
respectively. Standards levels of 1.9 and 2.3 grams per test will apply 
for vehicles over 14,000 pounds. These standards represent more than a 
50 percent reduction in the numerical standards as they exist today.
    The program includes flexibility provisions to facilitate the 
transition to the new standards and to encourage the early introduction 
of clean technologies, and adjustments to various testing and 
compliance requirements to address differences between the new 
technologies and existing engine-based technologies. These provisions 
are described in Sections III and VI.
2. Fuel Quality Standards
    This rule specifies that, beginning June 1, 2006, refiners must 
begin producing highway diesel fuel that meets a maximum sulfur 
standard of 15 parts per million (ppm). All 2007 and later model year 
diesel-fueled vehicles must be refueled with this new low sulfur diesel 
fuel. This sulfur standard is based on our assessment of the impact of 
sulfur on advanced exhaust emission control technologies, and a 
corresponding assessment of the feasibility of low sulfur fuel 
production and distribution.
    Today's program includes a combination of flexibilities available 
to refiners to ensure a smooth transition to low sulfur highway diesel 
fuel. First, refiners can take advantage of a temporary compliance 
option, including an averaging, banking and trading component, 
beginning in June 2006 and lasting through 2009, with credit given for 
early compliance before June 2006. Under this temporary compliance 
option, up to 20 percent of highway diesel fuel may continue to be 
produced at the existing 500 ppm sulfur maximum standard. Highway 
diesel fuel marketed as complying with the 500 ppm sulfur standard must 
be segregated from 15 ppm fuel in the distribution system, and may only 
be used in pre-2007 model year heavy-duty vehicles. Second, we are 
providing additional hardship provisions for small refiners to minimize 
their economic burden in complying with the 15 ppm sulfur standard. 
Third, we are providing additional flexibility to refiners subject to 
the Geographic Phase-in Area (GPA) provisions of the Tier 2 gasoline 
sulfur program, which will allow them the option of staggering their 
gasoline and diesel investments. Finally, we are adopting a general 
hardship provision for which any refiner may apply on a case-by-case 
basis under certain conditions. These hardship provisions, coupled with 
the temporary compliance option, will provide a ``safety valve'' 
allowing up to 25 percent of highway diesel fuel produced to remain at 
500 ppm for these transitional years to minimize any potential for 
highway diesel fuel supply problems.
    In addition, today's program includes unique provisions for 
implementing the low sulfur diesel fuel program in the State of Alaska, 
given that it is exempt from the current 500 ppm standard. Certain U.S. 
territories are excluded from both the new engine standards and highway 
diesel fuel standards.
    The compliance provisions for ensuring diesel fuel quality are 
essentially consistent with those that have been in effect since 1993 
under the existing 500 ppm sulfur standard (55 FR 34120, August 21, 
1990). Additional compliance provisions have been established primarily 
during the transition years of the program to verify refiners' 
compliance with the temporary compliance option to ensure the two 
grades of highway diesel fuel remain segregated, and to discourage 
misfueling of model year 2007 and later diesel vehicles.

B. Why is EPA Taking This Action?

1. Heavy-Duty Vehicles Contribute to Serious Air Pollution Problems
    As discussed in detail in Section II, emissions from heavy-duty 
vehicles contribute greatly to a number of serious air pollution 
problems, and would have continued to do so into the future absent 
further controls to reduce these emissions. First, heavy-duty vehicles 
contribute to the health and welfare effects of ozone, PM, 
NOX, SOX, and volatile organic compounds (VOCs), 
including toxic compounds such as formaldehyde. These adverse effects 
include premature mortality, aggravation of respiratory and 
cardiovascular disease (as indicated by increased hospital admissions 
and emergency room visits, school absences, work loss days, and 
restricted activity days), changes in lung function and increased 
respiratory symptoms, changes to lung tissues and structures, altered 
respiratory defense mechanisms, chronic bronchitis, and decreased lung 
function. Ozone also causes crop and forestry losses, and PM causes 
damage to materials and soiling of commonly used building materials and 
culturally important items such as statues and works of art. Second, 
NOX, SOX and PM contribute to substantial 
visibility impairment in many parts of the U.S. Third, NOX 
emissions from heavy-duty trucks contribute to the acidification, 
nitrification and eutrophication of water bodies. Fourth, the Agency 
has concluded, and the Clean Air Scientific Advisory Committee has 
approved in public session, that diesel exhaust is likely to be 
carcinogenic to humans.
    Millions of Americans live in areas with unhealthful air quality 
that currently endangers public health and welfare. Without emission 
reductions from the standards for heavy-duty vehicles, there is a 
significant risk that an appreciable number of 45 areas with 128 
million people across the country will violate the 1-hour ozone 
national ambient air quality standard (NAAQS) during the period when 
these standards will take effect. Furthermore, our analysis shows that 
PM10 concentrations in 10 areas with a population of 28 
million people face a significant risk of exceeding the PM10 
NAAQS without significant additional controls between 2007 and 2030. 
Under the mandates and authorities in the Clean Air Act, Federal, 
state, and local governments are working to bring ozone and particulate 
levels into compliance with the 1-hour ozone and PM10 NAAQS 
through State Implementation Plan (SIP) attainment and maintenance 
plans, and to ensure that future air quality reaches and continues to 
achieve these health-based standards. The reductions in this rulemaking 
will play a critical part in these important efforts to attain and 
maintain the NAAQS. In addition, reductions from this action will also 
reduce public health and welfare effects associated with ozone and fine 
PM at concentrations that do not constitute a violation of the 1-hour 
ozone and PM10 NAAQS.
    Emissions from heavy-duty vehicles account for substantial portions 
of the country's ambient PM and NOX levels. ( NOX 
is a key precursor to ozone formation). By 2007, we estimate that 
heavy-duty vehicles will account for 28 percent of mobile source 
NOX emissions and 20 percent of mobile source PM emissions. 
These proportions are even

[[Page 5007]]

higher in some urban areas, such as in Sacramento, Atlanta, and 
Washington, DC, where HDVs contribute over 34 percent of the mobile 
source NOX emissions, and in Santa Fe, Los Angeles, and 
Hartford, where heavy-duty vehicle PM emissions account for 38, 25 and 
30 percent of the mobile source PM emissions inventory, respectively. 
Over time, the relative contribution of diesel engines to air quality 
problems will go even higher if diesel-equipped light-duty vehicles 
become more popular, as is expected by some automobile manufacturers. 
The PM and NOX standards for heavy-duty vehicles in this 
rule will have a substantial impact on emissions. By 2030, 
NOX emissions from heavy-duty vehicles under today's 
standards will be reduced by 2.6 million tons, and PM emissions will 
decline by about 109,000 tons, dramatically reducing this source of 
NOX and PM emissions. Urban areas, which include many poorer 
neighborhoods, can be disproportionately impacted by HDV emissions, and 
these neighborhoods will thus receive a relatively larger portion of 
the benefits expected from new HDV emissions controls.
    In addition to its contribution to PM inventories, diesel exhaust 
PM is of special concern because it has been implicated in an increased 
risk of lung cancer and respiratory disease. The EPA draft Health 
Assessment Document for Diesel Exhaust (Draft Assessment) was reviewed 
in public session by the Clean Air Scientific Advisory Committee 
(CASAC) on October 12-13, 2000.3 The Agency has concluded, 
and the CASAC approved at this session, that diesel exhaust is likely 
to be carcinogenic to humans. State and local governments, in their 
efforts to protect the health of their citizens and comply with 
requirements of the Clean Air Act (CAA or ``the Act''), have recognized 
the need to achieve major reductions in diesel PM emissions, and have 
been seeking Agency action in setting stringent new standards to bring 
this about.4
---------------------------------------------------------------------------

    \3\ EPA (2000) Review of EPA's Health Assessment Document for 
Diesel Exhaust (EPA 600/8-90/057E). Review by the Clean Air 
Scientific Advisory Committee (CASAC) December 2000. EPA-SAB-CASAC-
01-003.
    \4\ For example, see letter dated July 13, 1999 from John Elston 
and Richard Baldwin on behalf of the State and Territorial Air 
Pollution Program Administrators and the Association of Local Air 
Pollution Control Officials (docket A-99-06, item II-D-78).
---------------------------------------------------------------------------

2. Technology-Based Solutions
    Although the air quality problems caused by diesel exhaust are 
challenging, we believe they can be resolved through the application of 
high-efficiency emissions control technologies. As discussed in detail 
in Section III, the development of diesel emissions control technology 
has advanced in recent years so that very large emission reductions (in 
excess of 90 percent) are possible, especially through the use of 
catalytic emission control devices installed in the vehicle's exhaust 
system and integrated with the engine controls. These devices are often 
referred to as ``exhaust emission control'' or ``aftertreatment'' 
devices. Exhaust emission control devices, in the form of the well-
known catalytic converter, have been used in gasoline-fueled 
automobiles for 25 years, but have had only limited application in 
diesel vehicles.
    Based on the Clean Air Act requirements discussed in Section I.B.3, 
we are setting stringent new emission standards that will result in the 
use of these diesel exhaust emission control devices (see Section III). 
We are also finalizing changes to diesel fuel quality standards in 
order to enable these high-efficiency technologies (Section IV). Heavy-
duty gasoline engines will also be able to reach the significantly 
lower emission levels envisioned in this rule by relying on the 
transfer of recent technology developments for light-duty applications, 
given the recent action taken to reduce sulfur in gasoline (65 FR 6698, 
February 10, 2000).
    To meet the new standards, application of high-efficiency exhaust 
emission controls for both PM and NOX will be needed. High-
efficiency PM exhaust emission control technology has been available 
for several years, although engine manufacturers have generally not 
needed this technology in order to meet our PM emission standards. This 
technology has continued to improve over the years, especially with 
respect to durability and robust operation in use. It has also proven 
extremely effective in reducing exhaust hydrocarbon emissions. 
Thousands of such systems are now in use in fleet programs, especially 
in Europe. However, as discussed in detail in Section III, these 
systems are very sensitive to sulfur in the fuel. For the technology to 
be viable and capable of meeting the standards, we believe that it will 
require diesel fuel with sulfur content capped at the 15 ppm level.
    Similarly, high-efficiency NOX exhaust emission control 
technology will be needed if heavy-duty vehicles are to attain the new 
standards. We believe this technology, like the PM technology, is 
dependent on the 15 ppm maximum diesel fuel sulfur levels being adopted 
in this rule to be feasible and capable of achieving the standards. 
Similar high-efficiency NOX exhaust emission control 
technology has been quite successful in gasoline direct injection 
engines that operate with an exhaust composition fairly similar to 
diesel exhaust. However, as discussed in Section III, application of 
this technology to diesels has some additional engineering challenges. 
In that section we discuss the current status of this technology. We 
also discuss the major development issues still to be addressed and the 
development steps that can be taken to address these issues. With the 
lead time available and the certainty of low-sulfur diesel fuel 
established by today's action, the evidence leaves us confident that 
the application of this technology to diesels will proceed at a 
reasonable rate of progress and will result in systems capable of 
achieving the standards.
    The need to reduce the sulfur in diesel fuel is driven by the 
requirements of the exhaust emission control technology that we project 
will be needed to meet the standards. The challenge in accomplishing 
the sulfur reduction is driven by the feasibility of needed refinery 
modifications, and by the costs of making the modifications and running 
the equipment. Today, a number of refiners are acting to provide low 
sulfur diesel to some markets. In consideration of the impacts that 
sulfur has on the efficiency, reliability, and fuel economy impact of 
diesel engine exhaust emission control devices, we believe that 
controlling the sulfur content of highway diesel fuel to the 15 ppm 
level is necessary and feasible, and, in the context of this rule's 
overall program, cost effective.
3. Basis For Action Under the Clean Air Act
    Section 202(a)(1) of the Act directs us to establish standards 
regulating the emission of any air pollutant from any class or classes 
of new motor vehicles or engines that, in the Administrator's judgment, 
cause or contribute to air pollution which may reasonably be 
anticipated to endanger public health or welfare. Section 202(a)(3) 
requires that EPA set standards for heavy-duty trucks that reflect the 
greatest degree of emission reduction achievable through the 
application of technology which we determine will be available for the 
model year to which the standards apply. We are to give appropriate 
consideration to cost, energy, and safety factors associated with the 
application of such technology. We may revise such technology-based 
standards, taking costs into account, on the basis of information 
concerning the effects of air pollution from heavy-duty vehicles or 
engines and other sources of mobile source related

[[Page 5008]]

pollutants on the public health and welfare. Section 202(a)(3)(C) 
requires that promulgated standards apply for no less than three years 
and go into effect no less than 4 years after promulgation. This rule 
conforms with these statutory requirements.
    We believe the evidence provided in Section III and the Regulatory 
Impact Analysis (RIA) indicates that the stringent emission standards 
finalized today are feasible and reflect the greatest degree of 
emission reduction achievable in the model years to which they apply. 
We have given appropriate consideration to costs in choosing these 
standards. Our review of the costs and cost-effectiveness of these 
standards indicate that they will be reasonable and comparable to the 
cost-effectiveness of other emission reduction strategies that have 
been required or could be required in the future. We have also reviewed 
and given appropriate consideration to the energy factors of this rule 
in terms of fuel efficiency and effects on diesel fuel supply, 
production, and distribution, as discussed below, as well as any safety 
factors associated with these standards.
    The information regarding air quality and the contribution of 
heavy-duty engines to air pollution in Section II and the RIA provides 
strong evidence that emissions from such engines significantly and 
adversely impact public health or welfare. First, there is a 
significant risk that several areas will fail to attain or maintain 
compliance with the NAAQS for 1-hour ozone concentrations or 
PM10 concentrations during the period that these new vehicle 
and engine standards will be phased into the vehicle population, and 
that heavy-duty engines contribute to such concentrations, as well as 
to concentrations of other NAAQS-related pollutants. This risk will be 
significantly reduced by the standards adopted today; however, the 
evidence indicates that some risk remains even after the reductions 
achieved by these new controls on heavy-duty vehicles and diesel fuel. 
Second, EPA believes that diesel exhaust is likely to be carcinogenic 
to humans. The risk associated with exposure to diesel exhaust includes 
the particulate and gaseous components. Some of the toxic air 
pollutants associated with emissions from heavy-duty vehicles and 
engines include benzene, formaldehyde, acetaldehyde, dioxin, acrolein, 
and 1,3-butadiene. Third, emissions from heavy-duty engines contribute 
to regional haze and impaired visibility across the nation, as well as 
acid deposition, POM deposition, eutrophication and nitrification, all 
of which are serious environmental welfare problems.
    Based on this evidence, EPA believes that, for purposes of section 
202(a)(1), emissions of NOX, VOCs, SOx and PM 
from heavy-duty trucks can reasonably be anticipated to endanger the 
public health or welfare. In addition, this evidence indicates that it 
will not be appropriate to modify the technology-based standards 
pursuant to section 202(a)(3)(B). EPA believes that it is required 
under section 202(a)(3)(A) to set technology-based standards that meet 
the criteria of that provision, and is not required to make an 
affirmative determination under section 202(a)(1). Instead EPA is 
authorized to take air quality into consideration under section 
202(a)(3)(B) in deciding whether to modify or not set standard under 
section 202(a)(3)(A). In this case, however, EPA believes the evidence 
fully supports a determination under section 202(a)(1) to set 
standards, and a determination not to modify such standards under 
section 202(a)(3)(B).
    In addition, there is significant evidence that emissions from 
heavy-duty trucks contribute to levels of ozone such that large 
segments of the national population are expected to experience 
prolonged exposure over several hours at levels that present serious 
concern for the public health and welfare. The same is true for 
exposure to fine PM. These public health and welfare problems are 
expected to occur in many parts of the country, including areas that 
are in compliance with the 1-hour ozone and PM10 NAAQS 
(PM10 is particulate matter that is 10 microns or smaller). 
This evidence is an additional reason why the controls finalized today 
are justified and appropriate under the Act. While EPA sees this as 
additional support for this action, EPA also believes that the evidence 
of air pollution problems summarized above and described in greater 
detail elsewhere is an adequate justification for this rule independent 
of concern over prolonged exposure to ozone and fine PM levels.
    Section 211(c) of the CAA allows us to regulate fuels where 
emission products of the fuel either: (1) Cause or contribute to air 
pollution that reasonably may be anticipated to endanger public health 
or welfare, or (2) will impair to a significant degree the performance 
of any emission control device or system which is in general use, or 
which the Administrator finds has been developed to a point where in a 
reasonable time it will be in general use were such a regulation to be 
promulgated. This rule meets each of these criteria. The discussion of 
the first test is substantially the same as the above discussion for 
the heavy-duty engine standards, because SOx and sulfate PM 
emissions from heavy-duty diesel vehicles are due to sulfur in diesel 
fuel. The substantial adverse effect of high diesel sulfur levels on 
diesel control devices or systems expected to be used to meet the 
heavy-duty standards is discussed in depth in Section III.F and in the 
RIA. In addition, our authority under section 211(c) is discussed in 
more detail in Appendix A to the RIA.

C. Putting This Rule In Perspective

    There are several helpful perspectives to establish in 
understanding the context for this rule: the growing popularity of 
diesel engines, past progress and new developments in diesel emissions 
control, Tier 2 light-duty emission standards and other related EPA 
initiatives (besides the above-discussed rulemaking for highway heavy-
duty engine emission standards in 2004), and recent actions and plans 
to control diesel emissions by the States and in other countries.
1. Diesel Popularity
    The diesel engine is increasingly becoming a vital workhorse in the 
United States, moving much of the nation's freight, and carrying out 
much of its farm, construction, and other labor. Diesel engine sales 
have grown significantly over the last decade, so that now about a 
million new diesel engines are put to work in the U.S. every year. 
Unfortunately, these diesel engines emit large quantities of harmful 
pollutants annually.
    Furthermore, although diesel emissions in this country come mostly 
from heavy-duty trucks and nonroad equipment, an additional source may 
grow out of auto manufacturers' plans to greatly increase the sales of 
diesel-powered light-duty vehicles (LDVs) and especially of light-duty 
trucks (LDTs), a category that includes the fast-selling sport-utility 
vehicles, minivans, and pickup trucks. These plans reflect the 
continuation of an ongoing dieselization trend, a trend recently most 
evident in the growing popularity of diesel-powered light heavy-duty 
trucks (8500 to 19,500 pounds). Diesel market penetration is working 
its way from larger to smaller highway applications and to a broader 
array of nonroad equipment applications. Finally, especially in Europe 
where diesels have already gained a broad consumer acceptance, the 
diesel engine is increasingly viewed as an attractive technology option 
for reducing emissions of gases that contribute to

[[Page 5009]]

global warming, because it has greater operating efficiency than a 
gasoline engine.
2. Past Progress and New Developments
    Since the 1970's, highway diesel engine designers have employed 
numerous strategies to meet our emissions standards, beginning with 
smoke controls, and focusing in the 1990's on increasingly stringent 
NOX, hydrocarbon, and PM standards. These strategies have 
generally focused on reducing engine-out emissions and not on exhaust 
emission controls, although relatively low-efficiency oxidation 
catalysts have been applied in some designs to reduce PM, with the 
recognition that their effectiveness is limited by sulfur in the fuel. 
On the fuel side, we set quality standards that provided emissions 
benefits by limiting the amount of sulfur and aromatics in highway 
diesel fuel beginning in 1993 (55 FR 34120, August 21, 1990). Our most 
recent round of standard setting for heavy-duty highway diesels 
occurred in 1997 (62 FR 54693, October 21, 1997), effective with the 
2004 model year. These standards were recently reviewed in a final 
rulemaking (65 FR 59896, October 6, 2000). These actions will result in 
engines that emit only a fraction of the NOX, hydrocarbons, 
and PM produced by engines manufactured just a decade ago. We consider 
this an important first phase of our current initiative to reconcile 
the diesel engine with the environment.
    Nevertheless, certain characteristics inherent in the way diesel 
fuel combustion occurs have prevented achievement of emission levels 
comparable to those of today's gasoline-fueled vehicles. Although 
diesel engines provide advantages in terms of fuel economy, durability, 
and evaporative emissions, and have inherently low exhaust emissions of 
hydrocarbons and carbon monoxide, controlling NOX emissions 
is a greater challenge for diesel engines than for gasoline engines, 
primarily because of the ineffectiveness of three-way catalysis in the 
oxygen-rich and relatively cool diesel exhaust environment. Similarly, 
PM emissions, which are inherently low for properly operating gasoline 
engines, are more difficult to control in diesel engines, because the 
diesel combustion process tends to form soot particles. The challenge 
is somewhat complicated by the fact that historical diesel 
NOX control approaches tend to increase PM, and vice versa, 
but both are harmful pollutants that need to be controlled.
    Considering the air quality impacts of diesel engines and the 
potential for growth of diesels in the lighter-duty portion of the 
market, it is imperative that progress in diesel emissions control 
continue. Significant progress has already been made in the design of 
exhaust emission control devices for diesel applications, driven in 
part by the challenge presented by the stringent Tier 2 standards for 
light-duty vehicles. As discussed in detail in Section III, new exhaust 
emission control technologies for NOX, PM, and hydrocarbon 
reduction will allow a major advancement in diesel emissions control of 
a magnitude comparable to that ushered in by the automotive catalytic 
converter in the 1970's. However, changes in diesel fuel quality will 
be needed to enable these high-efficiency exhaust emission control 
devices.
3. Tier 2 Emissions Standards
    Auto manufacturers' design plans for new light-duty diesel vehicle 
models will be greatly affected by our recent adoption of stringent new 
emission standards for light-duty highway vehicles (referred to as 
``Tier 2'' standards) that will phase in between 2004 and 2009. These 
Tier 2 standards will require significant improvements in electronic 
engine controls and catalysts on gasoline vehicles. We anticipate that 
these advances will be transferred over to heavy-duty gasoline vehicles 
in meeting the standards finalized in this rule. The Tier 2 
NOX and PM standards, that apply equally to gasoline and 
diesel vehicles, will also require the use of high-efficiency emission 
control technologies on light-duty diesel vehicles. The low sulfur 
highway diesel fuel brought about by this rule will make it possible 
for designers to employ these high-efficiency exhaust emission control 
technologies in these light-duty applications. The timing of the fuel 
change provides for the use of these devices in time to satisfy Tier 2 
phase-in requirements.
    The Tier 2 program phases in interim and final standards over a 
number of years, providing manufacturers the option of delaying some of 
their production of final Tier 2 designs until later in the phase-in. 
For vehicles up to 6000 lbs GVWR (LDVs) and light light-duty trucks 
(LLDTs)), the interim standards begin in 2004 and phase out by 2007, as 
they are replaced by the final Tier 2 standards. For vehicles between 
6000 and 8500 lbs ( heavy light-duty trucks (HLDTs)), the interim 
standards begin in 2004 and phase out by 2009 as they are replaced by 
the final Tier 2 standards. A new category of vehicles between 8,500 
and 10,000 lbs, medium-duty passenger vehicles (MDPVs), will follow the 
same phase-in schedule as HLDTs.
    Our assessment in the Tier 2 final rule is that the interim 
standards are feasible for diesel vehicles without a need for fuel 
quality changes. Manufacturers can take advantage of the flexibilities 
provided in the Tier 2 program to delay the need for light-duty diesels 
to meet the final Tier 2 levels until late in the phase-in period (as 
late as 2007 for LDVs and LLDTs, and 2009 for HLDTs and MDPVs). 
However, low sulfur fuel is expected to be needed for diesel vehicles 
designed to meet the final NOX and PM standards, because 
these vehicles are likely to employ light-duty versions of the sulfur-
sensitive exhaust emission control technologies discussed in Section 
III. The gasoline quality changes and light-duty gasoline engine 
developments that will result from the Tier 2 rule will also help make 
it feasible for heavy-duty gasoline engines to meet the standards in 
this rule.
4. Mobile Source Air Toxics Rulemaking
    Passenger cars, on-highway trucks, and nonroad equipment emit 
hundreds of different compounds and elements. Several of these are 
considered to be known, likely, or possible human carcinogens. These 
include diesel exhaust, plus several VOCs such as acetaldehyde, 
benzene, 1,3-butadiene, formaldehyde, and acrolein. Trace metals may 
also be present in heavy-duty diesel engine emissions, resulting from 
metals in fuels and lubricating oil, and from engine wear. Several of 
these metals have carcinogenic and mutagenic effects.
    Important reductions in these and other mobile source air toxics 
have occurred under existing programs established under Clean Air Act 
Sections 202(a) (on-highway engine requirements), 211 (the fuel 
requirements), and 213 (nonroad engine requirements). Although these 
programs are primarily designed for control of criteria pollutants, 
especially ozone and PM10, they also achieve important 
reductions in diesel PM and gaseous air toxics through VOC and 
hydrocarbon controls.
    In addition to these programs, Section 202(l)(2) of the Act directs 
us to consider additional controls to reduce emissions of hazardous air 
pollutants from motor vehicles, their fuels, or both. Those standards 
are to reflect the greatest degree of emission reduction achievable 
through the application of technology which will be available, taking 
into account existing standards, costs, noise, energy, and safety 
factors. We published a proposed rule on mobile source air toxics on 
August 4,

[[Page 5010]]

2000 (65 FR 48058). This MSAT final rule was signed on December 20, 
2000. Interested parties should refer to the final rule if interested 
in the ultimate form of the regulation.
    The mobile source air toxics (MSATs) rule consists of four parts. 
First, we identify a list of 21 MSATs that are known to be emitted from 
motor vehicles or their fuels and are considered by the Agency to pose 
potential adverse human health risks. Diesel exhaust is included on 
this MSAT list because, as discussed in Section II, human 
epidemiological studies have suggested that diesel exhaust is 
associated with increased risk of adverse respiratory effects and lung 
cancer. Second, the MSAT rule considers the contribution of mobile 
sources to the nation's air toxics inventory and evaluates the toxics 
benefits of existing mobile source emission control programs. The 
benefits of the program as proposed are included in this analysis. 
Third, the MSAT final rule considers whether additional controls are 
appropriate at this time, given technological feasibility, cost, and 
the other criteria specified in the Act. The final rule includes a 
toxics performance standard applicable to reformulated gasoline and 
anti-dumping standards that apply to conventional gasoline. With regard 
to additional vehicle-based controls, we proposed that it is not 
appropriate at this time to set more stringent standards than the 
technology forcing standards found in this rule and our recently 
adopted Tier 2 rulemaking. Finally, because of our concern about the 
potential future health impacts of exposure to the public of air toxics 
from the remaining emissions from mobile sources in the future, we 
continue our toxics-related research activities and to conduct a future 
rulemaking to evaluate whether, based on the additional data, 
additional mobile source air toxics controls should be adopted. This 
rulemaking would be completed no later than 2004.
    EPA also intends to rely on today's rule to satisfy in part its 
obligations under section 202(l) of the Clean Air Act. In the mobile 
source air toxics NPRM, the Agency proposed a list of mobile source air 
toxics, including diesel exhaust, as well as a number of specific 
constituents of heavy-duty vehicle exhaust (gasoline and 
diesel).5 The emissions standards established in today's 
action result in the greatest achievable reductions of diesel PM and 
heavy-duty vehicle NMHC. The Agency is scheduled to finalize the mobile 
source air toxics rulemaking on or before December 20, 2000.
---------------------------------------------------------------------------

    \5\ 65 FR 48058, August 4, 2000.
---------------------------------------------------------------------------

5. Nonroad Engine Standards and Fuel
    Although this rule covers only highway diesel engines and fuel, it 
is clear that potential requirements for nonroad diesel engines and 
fuel are related. It is expected that nonroad diesel fuel quality, 
currently unregulated, may need to be controlled in the future in order 
to reduce the large contribution of nonroad engines to NOX 
and PM inventories. Refiners, fuel distributors, states, environmental 
organizations, and others have asked that we provide as much 
information as possible about the future specifications for both types 
of fuel as early as possible.
    We do plan to give further consideration to additional control of 
nonroad engine emissions. As discussed below in Section VIII, an 
effective control program for these engines requires the resolution of 
several major issues relating to engine emission control technologies 
and how they are affected by fuel sulfur content. The many issues 
connected with any rulemaking for nonroad engines and fuel warrant 
serious attention, and we believe it is premature for us to take any 
action on this initiative in this rule. We plan to initiate action in 
the future to formulate proposals that would address both nonroad 
diesel fuel and engines.
6. State Initiatives
    The California Air Resources Board (ARB) and local air quality 
management districts within California are also pursuing measures to 
better control diesel emissions. Key among these efforts is work 
resulting from the Board's designation of particulate emissions from 
diesel-fueled engines as a toxic air contaminant (TAC) on August 27, 
1998. TACs are air pollutants that may cause or contribute to an 
increase in death or serious illness or may pose a present or future 
hazard to human health. The TAC designation was based on research 
studies showing that emissions from diesel-fueled engines may cause 
cancer in animals and humans, and that workers exposed to higher levels 
of emissions from diesel-fueled engines are more likely to develop lung 
cancer.
    In September 2000 the ARB approved a Diesel Risk Reduction Plan 
developed by its staff following an extensive public 
process.6 This plan includes several California measures 
related to highway diesel vehicles, including the major elements of the 
program we are establishing on a nationwide basis in this final rule. 
Because truck travel from other states has a large effect on 
California's air quality, the plan and the Board's resolution further 
encourages the EPA adopt this nationwide program, as well as other 
diesel-related emissions reduction programs.
---------------------------------------------------------------------------

    \6\ State of California Air Resources Board Resolution 00-30, 
September 28, 2000.
---------------------------------------------------------------------------

    The ARB has also adopted stringent new emission requirements for 
urban transit buses and is considering similar requirements for school 
buses.7 This program is aimed at encouraging the use of 
clean alternative fuels and high-efficiency diesel emission control 
technologies. Their program includes requirements for zero-emissions 
buses, fleet average NOX levels, and retrofits for PM 
control, as well as model year 2007 NOX and PM standards 
levels of 0.2 and 0.01 g/bhp-hr, respectively (equal to the levels 
finalized in this rule). It also requires that all diesel fuel used by 
transit agencies after July 1, 2002 must meet a cap of 15 ppm sulfur. 
This is a much earlier schedule than that finalized in this rule, to 
support the ARB's proposed transit bus fleet program.
---------------------------------------------------------------------------

    \7\ ``Notice of Public Hearing To Consider the Adoption of a 
Public Transit Bus Fleet Rule and Emission Standards For New Urban 
Buses'', California ARB, November 30, 1999, and ARB Resolution 00-2, 
dated February 24, 2000.
---------------------------------------------------------------------------

    Other states, most notably Texas, have taken steps toward adopting 
programs for cleaner diesel fuel and cleaner diesel engines. On 
December 6, 2000, the Texas Natural Resource Conservation Commission 
adopted a program that, among other things, would require the capping 
of diesel fuel sulfur levels in many counties to 15 ppm by June 
2006.8 This proposal exemplifies the importance that states 
with air quality problems have attached to clean diesel fuel, and 
specifically to the 15 ppm maximum sulfur requirement in 2006 being set 
in this rule
---------------------------------------------------------------------------

    \8\ Title 30, Texas Administrative Code, Chapter 114, Subchapter 
H, Division 2. Also see Texas Natural Resource Conservation 
Commission website www.tnrcc.state.tx.us..
---------------------------------------------------------------------------

7. Retrofit Programs
    Many States facing air quality improvement challenges have 
expressed strong interest in programs that will reduce emissions from 
existing highway and nonroad diesel engines through the retrofitting of 
these engines with improved emission control devices. The urban transit 
bus program adopted by the California ARB includes such a retrofit 
requirement as one of its major components (see Section I.C.6). In 
March 2000 we announced our own Diesel Retrofit Initiative to support 
and

[[Page 5011]]

encourage fleet operators, air quality planners, and retrofit 
manufacturers in creating effective retrofit programs. These programs 
are appealing because the slow turnover of the diesel fleet to the new 
low-emitting engines makes it difficult to achieve near-term air 
quality goals through new engine programs alone. Some of the exhaust 
emission control technologies discussed in this rule are especially 
appealing for use in retrofits because they can be fitted to an 
existing vehicle as add-on devices without major engine modifications, 
although some of the more sophisticated systems that require careful 
control of engine parameters may be more challenging.
    Because of the uncertainty at this time in how and when such 
programs may be implemented, our analysis for today's rule does not 
calculate any benefits from them. Nevertheless, we believe that this 
program can enable the viability of these retrofit technologies. We 
expect that large emission benefits from the existing fleet could be 
realized as a result of the fuel changes we are finalizing here, 
combined with retrofit versions of the technologies that will be 
developed in response to the finalized engine standards. These benefits 
will be especially important in the early years of the program when new 
vehicles standards are just beginning to have an impact, and when 
States and local areas need to gain large reductions to attain air 
quality goals.
8. Actions In Other Countries
    There is substantial activity taking place in many countries 
related to the regulation of diesel fuel and engines. The large light-
duty vehicle market share enjoyed by diesels in many European countries 
has helped to stir innovation in dealing with diesel emissions 
problems. Advanced emissions control technologies are being evaluated 
there in the in-use fleet and experience gained from these trials is 
helping to inform the diesel emissions control discussion in the U.S. 
In addition, several European countries have low sulfur diesel fuel, 
with maximum sulfur levels varying from 10 to 50 ppm, and so experience 
gained from the use of these fuels, though not completely transferable 
to the U.S. situation, also provides valuable experience. European 
Union countries will limit sulfur in diesel fuel to 50 ppm by 2005, and 
even more aggressive plans are being discussed or implemented. The 
United Kingdom made a rapid conversion to 50 ppm maximum sulfur diesel 
fuel in 1999 by offering tax incentives. This change occurred with much 
smaller refinery investments than had been predicted, and some refinery 
production there is actually at levels well below the 50 ppm cap. 
Germany is moving forward with plans to introduce a 10 ppm sulfur cap 
for diesel fuel by 2003, also via tax incentives, and is attempting to 
get the 50 ppm specification that was adopted by the European 
Commission revised downward to the 10 ppm cap level. The Commission is 
reviewing the implications of moving to this level.
    One European country has had extensive experience with the 
transition to low sulfur diesel fuel. In the early 1990's, Sweden 
decided to take advantage of the environmental benefits of 10 ppm 
sulfur/low aromatics fuel by introducing it with a reduction in the 
diesel fuel tax. The program has been quite successful, and in excess 
of 90 percent of the highway diesel fuel used there is of this 10 ppm 
maximum sulfur class.9
---------------------------------------------------------------------------

    \9\ Memo from Thomas M. Baines to Docket A-99-06, October 29, 
1999, Docket #A-99-06, Item II-G-12.
---------------------------------------------------------------------------

    The government of Canada has expressed its intent to harmonize its 
fuel regulations with the U.S. fuels standards being adopted 
today.10 This would simplify the operation of new-technology 
vehicles that cross the U.S-Canada border. However, the success of the 
U.S. program does not depend on harmonized diesel fuel standards, and 
Section VI.H discusses how differences between the future fuel 
specifications in the U.S. and those in Canada and Mexico may be 
accommodated.
---------------------------------------------------------------------------

    \10\ ``Process Begins to Develop Long term Agenda to Reduce Air 
Pollution from Vehicles and Fuels'', Environment Canada press 
release, May 26, 2000.
---------------------------------------------------------------------------

II. The Air Quality Need and Projected Benefits

A. Overview

    Heavy-duty vehicle emissions contribute to air pollution with a 
wide range of adverse health and welfare impacts. Emissions of VOC, CO, 
NOX, SOx, and PM from HD vehicles contribute a 
substantial percentage of the precursors or direct components of 
ambient concentrations of ozone, PM, sulfur and nitrogen compounds, 
aldehydes, and substances known or considered likely to be carcinogens. 
Emissions of VOCs include some specific substances known or suspected 
to cause cancer. Of particular concern is human epidemiological 
evidence linking diesel exhaust to an increased risk of lung cancer, 
and the Agency is also concerned about the noncancer health effects of 
diesel exhaust We have finalized on December 20, 2000 a rule which 
lists diesel particulate matter and diesel exhaust organic gases as a 
mobile source air toxic under section 202(l) of the Clean Air Act, and 
the particulate matter standard finalized today reflects the greatest 
degree of emissions reductions achievable under section 202(l) for on-
highway heavy-duty vehicle PM emissions. Heavy-duty vehicle emissions 
also cause adverse environmental effects including visibility 
reductions, acid rain, nitrification and eutrophication of water 
bodies.
    Emissions from heavy-duty vehicles, which are predominantly diesel-
powered, account for substantial portions of the country's ambient PM 
and ground-level ozone levels. By 2007, we estimate that heavy-duty 
vehicles will account for 28 percent of mobile source NOX 
emissions (including highway and non-road), and 20 percent of mobile 
source PM emissions. These proportions are even higher in some urban 
areas, such as Atlanta and Los Angeles. Urban areas, which include many 
poorer neighborhoods, can be disproportionately impacted by HDV 
emissions because of heavy traffic in and out of densely populated 
urban areas.
    The Agency developed new emissions inventories and conducted new 
air quality modeling for this rule to determine the risk of exposure to 
unhealthy ambient concentrations of ozone and particulate matter in 
2007, 2020 and 2030. This analysis, supplemented with local air quality 
modeling and other information on emissions and air quality trends, 
indicates that an appreciable number of the 45 areas with a total 
population of 128 million people face a significant risk of violating 
the 1-hour ozone standard between 2007 and 2030. Ten PM10 
nonattainment areas with 28 million people face a significant risk of 
experiencing particulate matter levels that violate the PM10 
standard during the same period.
    Under the mandates and authorities in the Clean Air Act, federal, 
state, and local governments are working to bring ozone and particulate 
levels into compliance with the 1-hour ozone and PM10 NAAQS 
through SIP attainment plans. Areas that reach attainment without 
reductions from this rule are likely to need additional reductions to 
ensure that future air quality continues to achieve ozone and PM 
standards, and areas that seek redesignation to attainment may use the 
reductions from this rule in future maintenance plans.
    The heavy-duty vehicle and engine emission standards, along with 
the diesel fuel sulfur standard finalized today, will have a dramatic 
impact in

[[Page 5012]]

reducing the large contribution of HDVs to air pollution. These 
standards will result in substantial benefits to public health and 
welfare through significant annual reductions in emissions of 
NOX, PM, NMHC, carbon monoxide, sulfur dioxide, and air 
toxics. For example, we project a 1.8 million ton reduction in 
NOX emissions from HD vehicles in 2020, which will increase 
to 2.6 million tons in 2030 when the current HD vehicle fleet is 
completely replaced with newer HD vehicles that comply with these 
emission standards. When coupled with the emission reductions projected 
to result from the Phase 1 (model year 2004) HDV standards, the 
emission reductions from heavy-duty vehicles are projected to be as 
large as the substantial reductions the Agency expects from light-duty 
vehicles as a result of its recently promulgated Tier 2 rulemaking.
    In sum, the Agency's air quality modeling and other evidence 
demonstrates that ambient concentrations of ozone, particulate matter, 
sulfur and nitrogen compounds, VOCs, air toxics, CO and diesel exhaust 
are anticipated to endanger public health, welfare and the environment 
in the time period between 2007 and 2030. Emission reductions expected 
from today's action are predicted to lessen future ambient 
concentrations of ozone and particulate matter and associated adverse 
public health and welfare effects.

B. Public Health and Welfare Concerns

1. Health and Welfare Concerns Raised During Public Hearings
    The Agency received a significant number of comments on this 
section during the public hearings and in written comments from 
interested parties. Comments are addressed in this section as well as 
in the Response to Comment document that accompanies this action.
    Throughout the five public hearings held around the country on the 
proposed heavy-duty engine and diesel fuel rule, the Agency received 
strong public support at each venue for increasing the stringency of 
heavy-duty truck and bus emission standards, and for further controls 
on sulfur in diesel fuel, in order to enable the necessary exhaust 
emission control. In addition to the 55,000 comments received from 
citizens in support of the Agency proposal to clean diesel fuel by mid-
2006 and reduce emissions from diesel engines in 2007, we received 
8,500 comments from citizens urging the Agency to act prior to 2007.
    Public officials and representatives of environmental, public 
health, or community-based organizations testified regularly about the 
link between public health ailments, such as asthma and lung cancer, 
and air pollution caused by diesel exhaust and particulate matter. In 
different ways, many noted that the impact of diesel soot is compounded 
by the fact that it is discharged at street level where people live and 
breathe. A regular complaint was the close proximity of bus depots, 
transfer terminals, and heavily-trafficked roadways to homes and 
apartment buildings, and in particular, to hospitals, playgrounds and 
schools. A common theme revolved around the notion that since asthma is 
an incurable disease, it was of utmost importance to help reduce the 
severity and frequency of attacks by reducing environmental triggers 
such as ozone, particulate matter and diesel exhaust.
    Major industries represented during these public hearings were the 
heavy-duty vehicle engine manufacturers, the oil industry, and the 
commercial truckers. While each had a different perspective, most 
supported the underlying intent of the proposal to improve public 
health and welfare, and some also supported the specific requirements 
as proposed. For those who objected to the proposal, the main thrust of 
their concerns related to the stringency and public health necessity of 
the new standards and the diesel fuel sulfur requirement. Largely in 
their written comments, these industries raised questions about the 
need for additional reductions in order to meet existing ozone and PM 
national ambient air quality standards and took exception with the 
Agency's characterization of diesel exhaust as a human carcinogen at 
environmental levels of exposure. Some industry commenters also 
challenged the Agency's reliance on public welfare and environmental 
effects such as visibility impairment and eutrophication of water 
bodies because the Agency had insufficiently quantified the benefits 
that would result from new standards on heavy-duty vehicles and diesel 
fuel.
    The following subsections present the available information on the 
air pollution situation that is likely to exist without this rule for 
each ambient pollutant. We also present information on the improvement 
that is expected to result from this rule.
2. Ozone and Its Precursors
a. Health and Welfare Effects From Short-Term Exposures to Ozone
    NOX and VOC are precursors in the photochemical reaction 
which forms tropospheric ozone. A large body of evidence shows that 
ozone can cause harmful respiratory effects including chest pain, 
coughing, and shortness of breath, which affect people with compromised 
respiratory systems most severely. When inhaled, ozone can cause acute 
respiratory problems; aggravate asthma; cause significant temporary 
decreases in lung function of 15 to over 20 percent in some healthy 
adults; cause inflammation of lung tissue; produce changes in lung 
tissue and structure; may increase hospital admissions and emergency 
room visits; and impair the body's immune system defenses, making 
people more susceptible to respiratory illnesses. Children and outdoor 
workers are likely to be exposed to elevated ambient levels of ozone 
during exercise and, therefore, are at greater risk of experiencing 
adverse health effects. Beyond its human health effects, ozone has been 
shown to injure plants, which has the effect of reducing crop yields 
and reducing productivity in forest ecosystems.
    There is strong and convincing evidence that exposure to ozone is 
associated with exacerbation of asthma-related symptoms. Increases in 
ozone concentrations in the air have been associated with increases in 
hospitalization for respiratory causes for individuals with asthma, 
worsening of symptoms, decrements in lung function and increased 
medication use. Studies have also indicated that exposure to 
particulate matter can be associated with altered lung function and 
increased respiratory symptoms, and asthmatic children are considered 
to be particularly sensitive to these effects. In addition, exposures 
to particulate matter or ozone have been shown to have a priming effect 
for responsiveness to allergens, with the pollutant exposure leading to 
heightened responses to allergens among allergic asthmatics. It is not 
believed, based on the current evidence, that exposure to outdoor 
pollutants such as ozone or particulate matter is a cause of asthma.
    Asthma is one of the most common and costly diseases in the United 
States. According to the President's Task Force on Environmental Health 
Risks and Safety Risks to Children, America is in the midst of an 
asthma epidemic.11

[[Page 5013]]

Since 1980, the number of asthma sufferers in the United States has 
more than doubled from 6.7 million to 17.3 million in 
1998.12 Today, more than 5 percent of the US population has 
asthma. On average, 15 people died every day from asthma in 1995, and 
the death rate has nearly tripled since 1975. In 1998, the cost of 
asthma to the U.S. economy was estimated to be $11.3 billion, with 
hospitalizations accounting for the single largest portion of the 
cost.13 A recent report by the Pew Environmental Health 
Commission at Johns Hopkins School of Public Health estimates that by 
2010, 22 million Americans will suffer from asthma, or one in 14 
Americans and one in every five families.14 At present, 
asthma cannot be cured, only controlled.
---------------------------------------------------------------------------

    \11\ Asthma and the Environment: A Strategy to Protect Children, 
President's Task Force on Environmental Health Risks and Safety 
Risks to Children, January 28, 1999, Revised May, 2000.
    \12\ Asthma Prevention Program of the National Center for 
Environmental Health, Centers for Disease Control and Prevention, 
``At-A-Glance, 1999; Centers for Disease Control and Prevention, 
CDC, Surveillance for Asthma--United States, 1960-1995,'' MMWR 47 
(No. SS-1) (April 1998).
    \13\ Asthma Statistics, National Institutes of Health, National, 
Heart, Lung, and Blood Institute, January, 1999.
    \14\ Attack Asthma: Why America Needs A Public Health Defense 
System to Battle Environmental Threats, Pew Environmental Health 
Commissions at the Johns Hopkins School of Public Health, June, 
2000.
---------------------------------------------------------------------------

    To address this growing public health problem, the President's Task 
Force on Environmental Health Risks and Safety Risks to Children ranked 
asthma as its highest priority. The President's Task Force created and 
charged the Asthma Priority Area Workgroup, co-chaired by EPA and the 
Department of Health and Human Services, with reviewing current Federal 
efforts to address the issue, and to make recommendations. In May, 
2000, the Task Force issued a strategy that focused on developing a 
greater understanding of the role environmental factors associated with 
the onset of asthma; and triggers of asthma. The report found that 
``children with asthma have long been recognized as particularly 
sensitive to outdoor air pollution,'' The report noted that ``25 
percent of children in America live in areas that regularly exceed EPA 
limits for ozone.'' The first guiding principle was to focus efforts to 
``eliminate the disproportionate impact of asthma in minority 
populations and those living in poverty.'' Testimony received during 
the Agency's five public hearings on this rule contained numerous 
references and detailed personal accounts as to the severe and 
sometimes fatal impact of asthma on the lives of American citizens.
b. Current and Future Nonattainment Status With the 1-Hour Ozone NAAQS
    Today, ground level ozone remains a pervasive pollution problem in 
the United States. As of July, 2000, 102 million people (1999 census) 
lived in 31 metropolitan areas designated nonattainment under the 1-
hour ozone NAAQS.15 This is a sharp decline from the 101 
nonattainment areas originally identified under the Clean Air Act 
Amendments of 1990, but elevated ozone concentrations remain a serious 
public health concern throughout the nation.
---------------------------------------------------------------------------

    \15\ Memorandum to Air Docket, September 18, 2000. Information 
on ozone nonattainment areas and populations as of July 31, 2000 
from US EPA website www.epa.gov/airs/nonattn.html, USA Air Quality 
Nonattainment Areas, Office of Air Quality Planning and Standards.
---------------------------------------------------------------------------

    Over the last decade, declines in ozone levels were found mostly in 
urban areas, where emissions are heavily influenced by controls on 
mobile sources and their fuels.16 Twenty-three metropolitan 
areas have realized a decline in ozone levels since 1989, but at the 
same time, ozone levels in 11 metropolitan areas with 7 million people 
have increased.17 Regionally, California and the Northeast 
have recorded significant reductions in peak ozone levels, while four 
other regions (the Mid-Atlantic, the Southeast, the Central and Pacific 
Northwest) have seen ozone levels increase.
---------------------------------------------------------------------------

    \16\ National Emissions Trends database.
    \17\ National Air Quality and Emissions Trends Report, 1998, 
March, 2000, at 28.
---------------------------------------------------------------------------

    The highest ambient concentrations are currently found in suburban 
areas, consistent with downwind transport of emissions from urban 
centers. Concentrations in rural areas have risen to the levels 
previously found only in cities. Over the last decade, ozone levels at 
17 of our National Parks have increased, and in 1998, ozone levels in 
two parks were 30 to 40 percent higher than the ozone NAAQS.
i. Results of Photochemical Ozone Modeling and Analysis of Emissions 
Inventories
    In conjunction with this rulemaking, the Agency performed ozone air 
quality modeling for nearly the entire Eastern U.S covering 
metropolitan areas from Texas to the Northeast.18 This ozone 
air quality modeling was based upon the same modeling system as was 
used in the Tier 2 air quality analysis, with the addition of updated 
inventory estimates for 2007 and 2030.19 This modeling 
supports the conclusion that there is a broad set of areas with 
predicted ozone concentrations in 2007 and 2030 at or above 0.125 ppm, 
in the baseline scenarios without additional emission reductions. EPA 
established the 1-hour standard at 0.12 parts per million (ppm) daily 
maximum 1-hour average concentration not to be exceeded more than once 
per year on average. Compliance with the 1-hour standard is judged on 
the basis of the most recent three years of ambient air quality 
monitoring data.
---------------------------------------------------------------------------

    \18\ EPA also performed ozone air quality modeling for the 
western United States but, as described further in the air quality 
technical support document, model predictions were well below 
corresponding ambient concentrations. Because of poor model 
performance for this region of the country, the results of western 
ozone modeling were not relied on for this rule.
    \19\ Consistent with a commitment expressed in the proposal, the 
Agency released the emissions inventory inputs for, and a 
description of, ozone modeling into the public record (docket number 
A-99-06), and also onto a website developed expressly for this 
purpose, on a continuous basis as they were developed. Further 
discussion of this modeling, including evaluations of model 
performance relative to predicted future air quality, is provided in 
the air quality modeling Technical Support Document (TSD).
---------------------------------------------------------------------------

    We have compared and supplemented our own ozone modeling with other 
modeling studies, submitted to us as state implementation plan (SIP) 
revisions, or brought to our attention through our consultations with 
states on SIP revisions that are in development. The ozone modeling in 
the SIP revisions has the advantage of using emission inventories that 
are more specific to the area being modeled, and of using 
meteorological conditions selected specifically for each area. Also, 
the SIP revisions included other evidence and analysis, such as 
analysis of air quality and emissions trends, observation-based models 
that make use of data on concentrations of ozone precursors, 
alternative rollback analyses, and information on the responsiveness of 
the air quality model. For some areas, we decided that the predictions 
of 1-hour ozone exceedances from our modeling were less reliable than 
conclusions that could be drawn from this additional evidence and 
analysis. For example, in some areas our episodes did not capture the 
meteorological conditions that have caused high ozone, while local 
modeling did so. Thus, these local analyses are considered to be more 
extensive than our own modeling for estimating whether there would be 
NAAQS nonattainment without further emission reductions, when 
interpreted by a weight of evidence method which meets our guidance for 
such modeling.
    Photochemical ozone modeling conducted for this rulemaking was 
based in part on updated national emissions inventories for all 
sources. National emission trends for NOX

[[Page 5014]]

predict a significant decline from 1996 to 2007, a leveling off of the 
downward trend between 2007 to 2020, and an increase in NOX 
inventories from 2020 to 2030. By 2030, national NOX levels 
are estimated to reach levels that are within ten percent of 2007 
levels. Predictions of national VOC emissions indicate a reduction from 
1996 to 2007, followed by an increase between 2007 and 2030 resulting 
in 2030 levels that are estimated to be 10 percent greater than VOC 
emissions levels in 2007. In metropolitan ozone nonattainment areas, 
such as Charleston, Chicago and Houston, NOX or VOC 
emissions in 2030 are predicted to reach or exceed 2007 levels. These 
estimated national and metropolitan area emissions inventories of ozone 
precursors are consistent with the conclusions reached by analysis of 
ozone modeling conducted for this rule that additional reductions are 
needed in order to enable areas to reach and maintain attainment of the 
ozone standard between 2007 and 2030.
    The Agency conducted ozone modeling based on inventories developed 
with and without reductions from this rulemaking for three future 
years: 2007, 2020 and 2030. The year 2007 was chosen because it is also 
the first year of implementation for the new standards adopted in 
today's action. It is also the year that nine major urban areas with a 
history of persistent and elevated ozone concentrations must 
demonstrate attainment, and is also relevant to the South Coast Air 
Basin of California (South Coast) with an attainment date of 2010. In 
addition, modeling was performed for 2030 when the full benefits of the 
rule are expected to be realized and for 2020 which represents an 
intermediate year between the start of the program and full turnover of 
the affected vehicle fleet. The year 2020 is also representative of the 
period when areas that have come into attainment may need additional 
reductions in order to maintain the standard.
    Today's rule will provide a substantial reduction in emissions of 
ozone precursors, particularly NOX. These emissions 
reductions will greatly lower ozone concentrations which will help 
federal and State efforts to bring about attainment of the current 1-
hour ozone standard. As described in the Air Quality Modeling Technical 
Support Document for this rule, EPA performed regional scale ozone 
modeling for the Eastern U.S. to assess the impacts of the controls in 
this rule on predicted 1-hour ozone exceedances. The results of this 
modeling were examined for those 37 areas in the East for which EPA's 
modeling predicted exceedances in 2007, 2020 and/or 2030 and current 1-
hour design values are above the standard or within 10 percent of the 
standard. The results for these areas combined indicate that there will 
be substantial reductions in the number of exceedances and the 
magnitude of high ozone concentrations in both 2020 and 2030 due to 
this rule. The modeling also indicates that without the rule, 
exceedances would otherwise increase by 37 percent between 2020 and 
2030 as growth in emissions offsets the reductions from Tier 2 and 
other current control programs.
    For all areas combined, the rule is forecast to provide a 33 
percent reduction in exceedances in 2020 and a 38 percent reduction in 
2030. The total amount of ozone above the standard is expected to 
decline by nearly 37 percent in 2020 and 44 percent in 2030. Also, 
daily maximum ozone exceedances are lowered by 5 ppb on average in 2020 
and nearly 7 ppb in 2030. The modeling forecasts an overall net 
reduction of 39 percent in exceedances from 2007, which is close to the 
start of this program, to 2030 when controls will be fully in place. In 
addition, the results for each individual area indicates that all areas 
are expected to have fewer exceedances in 2030 with the HDV controls 
than without this rule.
    During the public comment period on the proposed rule, EPA received 
several comments that expressed concern about potential increases in 
ozone that might result from this rule. As indicated above, the air 
quality modeling results indicate an overall reduction in ozone levels 
in 2007 and 2030 during the various episodes modeled. Examining 
individual areas, nearly the entire country is projected to benefit 
substantially from the reductions in this rule.20 There is a 
metropolitan area that EPA modeled as having exceedances with the one-
hour ozone standard under baseline conditions in 2007 through 2030, 
which the Agency's modeling for the HDV rule estimated could have less 
than a 3 percent increase in its peak ozone levels in 2020 and 2030 and 
small net increase (i.e., less than 1 ppb) in levels above the 1-hour 
standard in 2030. However, EPA's air quality modeling did not predict 
an increase in the number of exceedances in this CMSA/MSA in 2020 and a 
decrease in exceedances occurred in 2030. In another CMSA/MSA in 
another State, in 2030 there was less than a one percent increase in 
the summer peak level. Yet, this area had fewer exceedances and lower 
ozone above the 1-hour standard in both 2020 and 2030 under the rule. 
EPA expects that the States will have State Implementation Plans that 
will consider federal controls and complement them with State actions 
to provide attainment and will work with the States to ensure this 
occurs.
---------------------------------------------------------------------------

    \20\ The air quality modeling was performed for the Eastern 
region of the United States, but EPA also expects the rule to 
benefit nonattainment areas throughout the entire nation, including 
California.
---------------------------------------------------------------------------

    Considering all of EPA's air quality modeling results, it is clear 
that the significant ozone reductions from this rule outweigh the 
limited ozone increases that may occur in the future assuming no 
additional reductions from federal or local controls. Additional 
details on this are provided in the Response to Comments document and 
in EPA's Heavy Duty Rule Air Quality Modeling Technical Support 
Document. Furthermore, EPA's Regulatory Impact Analysis for this rule 
shows significant health and welfare benefits occurring from the ozone 
reductions that the rule provides (see details on the benefits in 
Section V.F.5 of the preamble and Chapter VII of the RIA).
ii. Areas At Risk of Exceeding the 1-Hour Ozone Standard in the Future
    This section presents the Agency's conclusions about the risk of 
future nonattainment for 45 areas listed in Table II.B-1 based on 
photochemical ozone modeling conducted for this rule and other evidence 
such as local air quality modeling.21 The areas listed in 
Table II.B-1 are separated into two broad groups: (1) Those areas with 
attainment dates in 2007 or 2010 that will benefit from reductions from 
this rule to attain and maintain the standard; and (2) those areas with 
attainment dates prior to 2007 that will benefit from reductions from 
this rule to maintain the standard after their attainment dates. 
Because ozone concentrations causing violations of the 1-hour ozone 
standard are well established to endanger public health and welfare, 
this indicates that it is appropriate for the Agency to set new 
standards for heavy-duty vehicles. The following discussion follows 
these groupings from top to bottom. A more detailed discussion is found 
in the Regulatory Impact Analysis (RIA).
---------------------------------------------------------------------------

    \21\ In the proposal, we relied on photochemical ozone modeling 
performed for recently promulgated standards on light duty vehicles, 
or Tier 2. The results presented in this final rulemaking for heavy-
duty vehicles and diesel fuel are largely consistent with the 
findings presented in the proposal, with small differences due to 
updated emissions inventories. As stated in the proposal, the ozone 
modeling methodologies used in the proposal and presented here in 
the final rule are identical.
---------------------------------------------------------------------------

    Ten metropolitan areas contained within designated ozone 
nonattainment areas have statutorily-defined attainment dates of 2007 
or 2010, or

[[Page 5015]]

have requested attainment date extensions to 2007. These 10 areas are 
listed at the top of Table II.B-1, and are New York City, Houston, 
Hartford, New London, Chicago, Milwaukee, Dallas, Beaumont-Port Arthur, 
Los Angeles, and Southeast Desert.
    Each of these areas needs additional emission reductions in order 
to reach attainment by 2007, and to maintain the standards in the 
future. Some of these areas have emission reduction shortfalls that are 
identified in their attainment demonstrations (i.e., South Coast Air 
Basin, New York and Houston), and reductions from this rule will assist 
State efforts to reach attainment.22 Three other areas--
Southeast Desert, Hartford, New London--are subject to ozone transport 
from upwind areas with identified shortfalls (South Coast and New 
York), and depend upon attainment from these upwind areas to reach 
attainment themselves. We have received attainment plans for two areas 
in Texas (Dallas and Beaumont-Port Arthur), and the Agency is likely to 
consider the reductions from this rule in its proposed approval of 
these attainment plans in Federal Register notices. Finally, there are 
two areas in the Midwest--Chicago and Milwaukee--that have incorporated 
reductions from this rule into their regional ozone modeling, and plan 
to rely on reductions from this rule to support their 2007 attainment 
demonstration.23
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    \22\ The South Coast's ``additional measures'' which rely on new 
technologies, are located in its 1994 SIP.
    \23\ Technical Support Document, Midwest Subregional Modeling: 
1-Hour Attainment Demonstration for Lake Michigan Area and Emissions 
Inventory, Illinois Environmental Protection Agency, Indiana 
Department of Environmental Management, Michigan Department of 
Environmental Quality, Wisconsin Department of Natural Resources, 
September 27, 2000, at 14 and at 8.
---------------------------------------------------------------------------

    For all ten areas, even if all shortfalls were filled by the 
States, there is some risk that at least some of the areas will not 
attain the standards by their attainment dates of 2007, or 2010 for Los 
Angeles. In that event, the reductions associated with this program, 
which increase substantially after 2007, will help assure that any 
residual failures to attain are remedied. Finally, there is also some 
risk that the areas will be unable to maintain attainment after 2007. 
Considered collectively, there is a significant risk that some areas 
will not be in attainment throughout the period when the new standards 
will reduce heavy-duty vehicle emissions.
    The rest of the areas have required attainment dates prior to 2007, 
or have no attainment date but are subject to a general obligation to 
have a SIP that provides for attainment and maintenance. These 34 
areas, according to our modeling, are at risk of exceeding the ozone 
NAAQS between 2007 and 2030. These areas will be able to rely on 
reductions from this rule to continue to maintain the standard after 
attainment is reached, and will be able to take credit for this program 
in their maintenance plans when they seek redesignation to attainment 
of the ozone standard. If any of these areas reach attainment, and then 
fall back into nonattainment, or fail to reach attainment by 2007, 
reductions from this rule will assist these areas in achieving the 
ozone standard. If an area does not choose to seek redesignation, the 
continuing reductions from this rulemaking will help ensure maintenance 
(i.e., prevent future exceedances) with the 1-hour standard after 
initial attainment is reached.
    Areas with attainment dates prior to 2007 are presented in two 
groupings in the table at the end of this section: a group of 20 areas 
in the middle of Table II.B-1, and a group of 15 areas at the bottom of 
Table II.B-1. For the middle group of 20 areas, EPA and the States are 
pursuing the established statutory processes for attaining and 
maintaining the ozone standard, or have already redesignated these 
areas to attainment with a maintenance plan (e.g., Cincinnati). EPA has 
re-instated the 1-hour ozone standard to some of these areas, restoring 
the applicability of these processes to them. The Agency believes that 
there is a significant risk that future air quality in a number of 
these areas will exceed the ozone standard at some time in the 2007 and 
later period. This belief is based on three factors: (1) Recent 
exceedances in 1997-1999, (2) predicted exceedances in 2007, 2020 or 
2030 after accounting for existing mobile source requirements and other 
local or regional controls currently in place or required, and (3) our 
assessment of the magnitude of recent violations, the year-to-year 
variability of meteorological conditions conducive to ozone formation, 
transport from areas with later attainment dates, and other variables 
inherent in predicting future attainment such as the potential for some 
areas to experience unexpectedly high economic growth rates, growth in 
vehicle miles traveled, varying population growth from area to area, 
and differences in vehicle choice.
    Only a subset of these 20 areas have yet adopted specific control 
measures that have allowed the Agency to fully approve an attainment 
plan. For some of these areas, we have proposed a finding, based on all 
the available evidence, that the area will attain by its applicable 
attainment date. We have approved a 10-year maintenance plan for 
Cincinnati, OH from 1999 to 2009. However, in many cases, these 
proposals depend on the State adopting additional emission reduction 
measures. The RIA provides more information on our recent proposals on 
attainment demonstrations and maintenance plans.24 Until the 
SIPs for these areas are actually submitted, reviewed and approved by 
EPA, there is some risk that these areas will not adopt fully 
approvable SIPs.
---------------------------------------------------------------------------

    \24\ We have recently proposed favorable action, in some cases 
with a condition that more emission reductions be obtained, on 
attainment demonstrations in these areas with attainment dates prior 
to 2007: Philadelphia, Washington-Baltimore, Atlanta, and St. Louis.
---------------------------------------------------------------------------

    Finally, there are 15 additional metropolitan areas for which the 
available ozone modeling and other evidence is less clear regarding the 
need for additional reductions (see Table II.B-1). Our ozone modeling 
predicted these areas to need further reductions to avoid exceedances 
in 2007, 2020 or 2030. The recent air quality monitoring data for these 
areas shows ozone levels with less than a 10 percent margin below the 
NAAQS. We believe there is a risk that future ozone levels will be 
above the NAAQS because of the year-to-year variability of 
meteorological conditions conducive to ozone formation, or because 
local emissions inventories may increase faster than national 
inventories.
iii. Conclusion
    In sum, without these reductions, there is a significant risk that 
an appreciable number of the 45 areas, with a population of 128 million 
people in 1999, will violate the 1-hour ozone standard during the time 
period when these standards will apply to heavy-duty vehicles. The 
evidence summarized in this section, and presented in more detail in 
the air quality modeling TSD and the RIA, supports the Agency's belief 
that emissions of NOX and VOC from heavy-duty vehicles in 
2007 and later will contribute to a national ozone air pollution 
problem that warrants regulatory action under section 202(a)(3) of the 
Act.

[[Page 5016]]



                             Table II.B-1 a
   [Areas and 1999 Populations at Risk of Exceeding the Ozone Standard
                         between 2007 and 2030]
------------------------------------------------------------------------
                                                                 1999
                                                              Population
                       MSA/CMSA/State                            (in
                                                              millions)
------------------------------------------------------------------------
    Areas with 2007/2010 Attainment Dates (Established or Requested)
------------------------------------------------------------------------
Beaumont-Port Arthur, TX...................................          0.4
Chicago-Gary-Kenosha, IL-IN-WI.............................          8.9
Dallas-Fort Worth, TX......................................          4.9
Hartford, CT...............................................          1.1
Houston-Galveston-Brazoria, TX.............................          4.5
Los Angeles-Riverside-Orange County, CA....................         16.0
Milwaukee-Racine, WI.......................................          1.6
New London-Norwich, CT-RI..................................          0.3
New York-Northern New Jersey-Long Island, NY-NJ-CT-PA......         20.2
Southeast Desert, CA.......................................          0.5
10 areas...................................................         58.4
------------------------------------------------------------------------
  Areas with Pre-2007 Attainment Dates or No Specific Attainment Date,
                 with a Recent History of Nonattainment.
------------------------------------------------------------------------
Atlanta, GA................................................          3.9
Baton Rouge, LA............................................          0.6
Birmingham, AL.............................................          0.9
Boston-Worcester-Lawrence, MA-HN-ME-CT.....................          5.7
Charlotte-Gastonia-Rock Hill, NC-SC........................          1.4
Detroit-Ann Arbor-Flint, MI MSA............................          5.5
Huntington-Ashland, WV-KY-OH...............................          0.3
Louisville, KY-IN..........................................          1.0
Macon, GA MSA..............................................          0.3
Memphis, TN-AR-MS..........................................          1.1
Nashville, TN..............................................          1.2
Philadelphia-Wilmington-Atlantic City, PA-NJ-DE-MD.........            6
Richmond-Petersburg, VA....................................            1
Sacramento-Yolo, CA........................................          1.7
San Diego, CA..............................................          2.8
San Francisco-Oakland-San Jose, CA.........................          6.9
San Joaquin Valley, CA.....................................          3.2
St. Louis, MO-IL...........................................          2.6
Ventura County, CA.........................................          0.7
Washington, DC--Baltimore, DC, MD, VA MSA..................          7.4
20 Areas...................................................         54.2
------------------------------------------------------------------------
Areas with Pre-2007 Attainment Dates and Recent Concentrations within 10
                        percent of an Exceedance.
------------------------------------------------------------------------
Barnstable-Yarmouth, MA....................................          0.2
Benton Harbor, MI..........................................          0.2
Biloxi-Gulfport-Pascagoula, MS MSA.........................          0.4
Charleston, WV MSA.........................................          0.3
Cincinnati-Hamilton, OH-KY-IN..............................          2.0
Cleveland-Akron, OH CMSA...................................          2.9
Grand Rapids-Muskegon-Holland, MI MSA......................          1.1
Houma, LA..................................................          0.2
Lake Charles, LA...........................................          0.2
New Orleans, LA MSA........................................          1.3
Norfolk-Virginia Beach-Newport News, VA-NC MSA.............          1.6
Orlando, FL MSA............................................          1.5
Pensacola, FL MSA..........................................          0.4
Providence-Fall River-Warwick, RI-MA.......................          1.1
Tampa-St. Petersburg-Clearwater, FL MSA....................          2.3
15 areas...................................................         15.7
------------------------------------------------------------------------
    Total Areas: 45........................................  Population:
                                                                    128
------------------------------------------------------------------------
a In order to determine the reliability of model predictions the Agency
  ran the ozone model for current ozone concentrations and compared
  those predictions with actual ozone levels recorded by ozone monitors.
  The results of the model's performance are presented in the RIA for
  this rule.


[[Page 5017]]

c. Public Health and Welfare Concerns from Prolonged and Repeated 
Exposures to Ozone
    A large body of scientific literature regarding health and welfare 
effects of ozone has associated health effects with certain patterns of 
ozone exposures that do not necessarily include any hourly ozone 
concentration above the 0.12 parts per million (ppm) level of the 1-
hour NAAQS. The science indicates that there are health effects 
attributable to prolonged and repeated exposures to lower ozone 
concentrations. Studies of 6 to 8 hour exposures showed health effects 
from prolonged and repeated exposures at moderate levels of exertion to 
ozone concentrations as low as 0.08 ppm. Prolonged and repeated ozone 
concentrations at these levels are common in areas throughout the 
country, and are found in areas that are exceeding, and areas that are 
not exceeding, the 1-hour ozone standard. For example, 153 million 
people, or 87 percent of the total population in counties evaluated 
(176 million), lived in areas with 2 or more days with concentrations 
of 0.09 ppm or higher in 1998, including areas currently violating the 
1-hour NAAQS. In the 2007, before the application of emission 
reductions resulting from this rule, we estimated that 116 million, or 
93 percent of the total population considered in the analysis, are 
predicted to live in areas with at least 2 days with model-adjusted 8-
hour average concentrations of 0.08 ppm or higher. By 2030, the number 
of people (139 million) and the relative percentage (91 percent) of the 
total population considered in the analysis is projected to grow 
significantly without reductions from this rule. Since prolonged 
exposures at moderate levels of ozone are more widespread than 
exceedances of the 1-hour ozone standard, and given the continuing 
nature of the 1-hour ozone problem described above, adverse health 
effects from this type of ozone exposure can reasonably be anticipated 
to occur in the future in the absence of this rule. Adverse welfare 
effects can also be anticipated, primarily from damage to vegetation. 
See the RIA for further details.
    Studies of acute health effects have shown transient pulmonary 
function responses, transient respiratory symptoms, effects on exercise 
performance, increased airway responsiveness, increased susceptibility 
to respiratory infection, increased hospital and emergency room visits, 
and transient pulmonary respiratory inflammation. Such acute health 
effects have been observed following prolonged exposures at moderate 
levels of exertion at concentrations of ozone well below the current 
standard of 0.12 ppm. The effects are more pronounced at concentrations 
above 0.09 ppm, affecting more subjects or having a greater effect on a 
given subject in terms of functional changes or symptoms. A more 
detailed discussion may be found in the RIA.
    With regard to chronic health effects, the collective data have 
many ambiguities, but provide suggestive evidence of chronic effects in 
humans. There is a biologically plausible basis for considering the 
possibility that repeated inflammation associated with exposure to 
ozone over a lifetime, as can occur with prolonged exposure to moderate 
ozone levels below peak levels, may result in sufficient damage to 
respiratory tissue that individuals later in life may experience a 
reduced quality of life, although such relationships remain highly 
uncertain.
    Ozone has many welfare effects, with damage to plants being of most 
concern. Plant damage affects crop yields, forestry production, and 
ornamentals. The adverse effect of ozone on forests and other natural 
vegetation can in turn cause damage to associated ecosystems, with 
additional resulting economic losses, as well as aesthetic impacts 
which may not be fully quantifiable in economic terms. Ozone 
concentrations of 0.10 ppm can be phytotoxic to a large number of plant 
species, and can produce acute injury and reduced crop yield and 
biomass production. Ozone concentrations at or below 0.10 ppm have the 
potential over a longer duration of creating chronic stress on 
vegetation that can result in reduced plant growth and yield, shifts in 
competitive advantages in mixed populations, decreased vigor, and 
injury from other environmental stresses.
    Section 202(a) provides EPA with authority to promulgate standards 
applicable to motor vehicle emissions that ``in the Administrator's 
judgment, cause or contribute to air pollution reasonably anticipated 
to endanger public health and welfare.'' The evidence in the RIA 
regarding the occurrence of adverse health effects due to prolonged and 
repeated exposure to ozone concentrations in the range discussed above, 
and regarding the populations that are expected to receive exposures at 
these levels, along with the welfare effects described above, supports 
a conclusion that emissions of NOX and VOC from heavy-duty 
vehicles in 2007 and later will be contributing to a national air 
pollution problem that warrants regulatory action under section 202(a) 
of the Act.
3. Particulate Matter
a. Health and Welfare Effects
    Particulate matter (PM) represents a broad class of chemically and 
physically diverse substances. It can be principally characterized as 
discrete particles that exist in the condensed (liquid or solid) phase 
spanning several orders of magnitude in size. All particles equal to 
and less than 10 microns are called PM10. Fine particles can 
be generally defined as those particles with an aerodynamic diameter of 
2.5 microns or less (also known as PM2.5), and coarse 
fraction particles are those particles with an aerodynamic diameter 
greater than 2.5 microns, but equal to or less than a nominal 10 
microns. The health and environmental effects of PM are strongly 
related to the size of the particles.
    The emission sources, formation processes, chemical composition, 
atmospheric residence times, transport distances and other parameters 
of fine and coarse particles are distinct. Fine particles are directly 
emitted from combustion sources and are formed secondarily from gaseous 
precursors such as sulfur dioxide, nitrogen oxides, or organic 
compounds. Fine particles are generally composed of sulfate, nitrate, 
chloride and ammonium compounds; organic and elemental carbon; and 
metals. Combustion of coal, oil, diesel, gasoline, and wood, as well as 
high temperature process sources such as smelters and steel mills, 
produce emissions that contribute to fine particle formation. In 
contrast, coarse particles are typically mechanically generated by 
crushing or grinding and are often dominated by resuspended dusts and 
crustal material from paved or unpaved roads or from construction, 
farming, and mining activities. Fine particles can remain in the 
atmosphere for days to weeks and travel through the atmosphere hundreds 
to thousands of kilometers, while coarse particles deposit to the earth 
within minutes to hours and within tens of kilometers from the emission 
source.
    Diesel particles are a component of both coarse and fine PM, but 
fall mostly in the fine and ultrafine size range.25 Diesel 
PM contains small quantities of numerous mutagenic and carcinogenic 
compounds. While representing a very small portion (less than one 
percent) of the national emissions of metals, and a small portion of 
diesel particulate matter (one to five percent), we note that several 
toxic trace metals of potential

[[Page 5018]]

toxicological significance are also emitted by diesel engines including 
chromium, manganese, mercury and nickel. In addition, small amounts of 
dioxins have been measured in diesel exhaust, some of which may 
partition into the particle phase, though the impact of these emissions 
on human health is not clear.
---------------------------------------------------------------------------

    \25\ Fine particulate matter includes particles with a diameter 
less than 2.5 micrometers. Ultrafine particulate matter include 
particles with a diameter less than 100 nanometers.
---------------------------------------------------------------------------

    Particulate matter, like ozone, has been linked to a range of 
serious respiratory health problems. Scientific studies suggest a 
likely causal role of ambient particulate matter (which is attributable 
to a number of sources including diesel) in contributing to a series of 
health effects. The key health effects categories associated with 
ambient particulate matter include premature mortality, aggravation of 
respiratory and cardiovascular disease (as indicated by increased 
hospital admissions and emergency room visits, school absences, work 
loss days, and restricted activity days), aggravated asthma, acute 
respiratory symptoms, including aggravated coughing and difficult or 
painful breathing, chronic bronchitis, and decreased lung function that 
can be experienced as shortness of breath. Observable human noncancer 
health effects associated with exposure to diesel PM include some of 
the same health effects reported for ambient PM such as respiratory 
symptoms (cough, labored breathing, chest tightness, wheezing), and 
chronic respiratory disease (cough, phlegm, chronic bronchitis and 
suggestive evidence for decreases in pulmonary function). Symptoms of 
immunological effects such as wheezing and increased allergenicity are 
also seen. Studies in rodents, especially rats, show the potential for 
human inflammatory effects in the lung and consequential lung tissue 
damage from chronic diesel exhaust inhalation exposure. Both fine and 
coarse particles can accumulate in the respiratory system. Exposure to 
fine particles is most closely associated with such health effects as 
premature mortality or hospital admissions for cardiopulmonary disease. 
For additional information on health effects, see the RIA. PM also 
causes damage to materials and soiling of commonly used building 
materials and culturally important items such as statutes and works of 
art. It is a major cause of substantial visibility impairment in many 
parts of the U.S.
    Heavy-duty vehicles contribute to particle formation through a 
number of pollutants. The contribution to PM fine varies by region of 
the country. Sulfate plays a major role in the composition of fine 
particulate across the country, but typically makes up over half the 
fine particles found in the Eastern United States. Organic carbon 
accounts for a large portion of fine particle mass, with a slightly 
higher fraction in the west. Diesel engines are the principal source of 
elemental carbon, which makes up about 5-6 percent of particle mass. 
Nationally, nitrate plays a relatively small role in the make up of 
fine particles, but ammonium nitrate plays a far larger role in 
southern California. Ammonium nitrate-formed secondarily from 
NOX and ammonia emissions--is one of the most significant 
components of particulate matter pollution in California. During some 
of the worst episodes of elevated particle levels in the South Coast, 
ammonium nitrate can account for about 65-75 percent of the 
PM2.5 mass. Reducing ammonium nitrate through controls on 
NOX sources is a critical part of California's particulate 
matter strategy. Nationally, the standards finalized in this rule will 
significantly reduce HDV emissions of SOX, NOX, 
VOCs and elemental carbon, and thus contribute to reductions in ambient 
concentrations of PM10 and PM2.5.
b. Attainment and Maintenance of the PM10 NAAQS
    Under the CAA, we are to regulate HDV emissions if they contribute 
to air pollution that can reasonably be anticipated to endanger public 
health and welfare. We have already addressed the question of what 
concentration patterns of PM endanger public health, in setting the 
NAAQS for PM10 in 1987. The PM NAAQS were revised in 1997, 
largely by adding new standards for fine particles (PM2.5) 
and modifying the form of the daily PM10 standard. On 
judicial review, the revised standards were remanded for further 
proceedings, and the revised PM10 standards were vacated. 
The Supreme Court is currently reviewing that decision. Oral arguments 
were held on November 7, 2000 and a decision by the Court is expected 
in 2001. Pending final resolution of the litigation, the 1987 
PM10 standard is the applicable NAAQS for PM10.
    Commenters questioned the need for additional PM10 
reductions in order to achieve attainment with the PM10 
NAAQS, and questioned the Agency's statement that, unlike ozone, 
PM10 emissions are projected to increase in the future. 
Commenters are correct that significant progress has occurred over the 
last decade,26 but the Agency's statement was based on 
projected PM10 inventory increases in the future between 
1996 and 2030. During this period, inventory trends for current 
PM10 nonattainment areas, or those with concentrations 
within 10 percent of the standard, are predicted to increase 
significantly. For example, from 1996 to 2030, increases are predicted 
in Clark County (Las Vegas) of 41 percent, Harris County (Houston) of 
37 percent, and Phoenix of 24 percent. A more detailed discussion is 
provided in the RIA.
---------------------------------------------------------------------------

    \26\ Ambient concentrations of PM10 and 
PM10 emissions have declined over the last ten years by 
25 percent and 19 percent, respectively. National Air Quality and 
Emissions Trends Report, 1998, US EPA, March, 2000.
---------------------------------------------------------------------------

i. Current PM10 Nonattainment
    The most recent PM10 monitoring data indicates that 14 
designated PM10 nonattainment areas with a projected 
population of 23 million violated the PM10 NAAQS in the 
period 1997-1999. Table II.B-3 lists the 14 areas, and also indicates 
the PM10 nonattainment classification and 1999 projected 
population for each PM10 nonattainment area. The projected 
population in 1999 was based on 1990 population figures which were then 
increased by the amount of population growth in the relevant county 
from 1990 to 1999.

Table II.B-3.--PM10 Nonattainment Areas Violating the PM10 NAAQS in 1997-
                                   99
------------------------------------------------------------------------
                                                               1999
                                                            Population
               Area                    Classification     (projected, in
                                                             millions)
------------------------------------------------------------------------
Hayden/Miami, AZ..................  Moderate............           0.004
Phoenix, AZ.......................  Serious.............           2.977
Nogales, AZ.......................  Moderate............           0.025
San Joaquin Valley, CA............  Serious.............           3.214
Imperial Valley, CA...............  Moderate............           0.122

[[Page 5019]]

 
Owens Valley, CA..................  Serious.............           0.018
Searles Valley, CA................  Moderate............           0.029
Coachella Valley, CA..............  Serious.............           0.239
South Coast Air Basin.............  Serious.............          14.352
Las Vegas, NV.....................  Serious.............           1.200
Reno, NV..........................  Moderate............           0.320
Anthony, NM b.....................  Moderate............           0.003
El Paso, TX a.....................  Moderate............           0.611
Wallula, WA b.....................  Moderate............           0.052
      Total Areas: 14.............  ....................         23.167
------------------------------------------------------------------------
a EPA has determined that continuing PM10 nonattainment in El Paso, TX
  is attributable to international transport under section 179(B).
b The violation in this area has been determined to be attributable to
  natural events under section 188(f) of the Act.

    In addition to the 14 PM10 nonattainment areas that are 
currently violating the PM10 NAAQS, there are 25 
unclassifiable areas that have recently recorded ambient concentrations 
of PM10 above the PM10 NAAQS. EPA adopted a 
policy in 1996 that allows areas with PM10 exceedances that 
are attributable to natural events to retain their designation as 
unclassifiable if the State is taking all reasonable measures to 
safeguard public health regardless of the sources of PM10 
emissions. Areas that remain unclassifiable areas are not required 
under the Clean Air Act to submit attainment plans, but we work with 
each of these areas to understand the nature of the PM10 
problem and to determine what best can be done to reduce it. With 
respect to the monitored violations reported in 1997-99 in the 25 areas 
designated as unclassifiable, we have not yet excluded the possibility 
that factors such as a one-time monitoring upset or natural events, 
which ordinarily would not result in an area being designated as 
nonattainment for PM10, may be responsible for the problem. 
Emission reductions from today's action will assist these currently 
unclassifiable areas to achieve ambient PM10 concentrations 
below the current PM10 NAAQS.
ii. Risk of Future Exceedances of the PM10 Standard
    The new standards for heavy-duty vehicles will benefit public 
health and welfare through reductions in direct diesel particles and 
NOX, VOCs, and SOX which contribute to secondary 
formation of particulate matter. Because ambient particle 
concentrations causing violations of the PM10 standard are 
well established to endanger public health and welfare, this 
information supports the new standards for heavy-duty vehicles. The 
reductions from today's rule will assist States as they work with the 
Agency through implementation of local controls including development 
and adoption of additional controls as needed to move their areas into 
attainment by the applicable deadline, and maintain the standards 
thereafter.
    The Agency's PM inventory analysis performed for this rulemaking 
predicts that without additional reductions 10 areas face a significant 
risk of failing to meet or to maintain the PM10 NAAQS even 
with federal, State and local controls currently in place.27 
Table II.B-4 presents information about these 10 areas and subdivides 
them into two groups. The first group of 6 areas are designated 
PM10 nonattainment areas which had recent monitored 
violations of the PM10 NAAQS in 1997-1999 and increasing 
inventories of PM10 from 2007 to 2030 (see Table II.B-3 for 
predicted increases in emissions). These areas have a population of 19 
million. Included in the group are the nonattainment areas that are 
part of the Los Angeles, Phoenix and Las Vegas (Clark County) 
metropolitan areas, where traffic from heavy-duty vehicles is 
substantial. These six areas will benefit from the reductions in 
emissions that will occur from the new standards for heavy-duty 
vehicles, as will other areas impacted by heavy-duty vehicle emissions.
---------------------------------------------------------------------------

    \27\ EPA has evaluated projected emissions for this analysis 
rather than future air quality because REMSAD, the model EPA has 
used for analyses related to this rule, was designed principally to 
estimate long-term average concentrations of fine particulate matter 
and its ability to predict short-term PM10 concentrations 
has not been satisfactorily demonstrated. In contrast with ozone, 
which is the product of complex photochemical reactions and 
therefore difficult to directly relate to precursor emissions, 
ambient PM10 concentrations are more heavily influenced 
by direct emissions of particulate matter and can therefore be 
correlated more meaningfully with emissions inventories.
---------------------------------------------------------------------------

    The second group of four counties listed in Table II.B-4 with a 
total of nine million people in 1999 also had predicted exceedances of 
the PM10 standard. While these four areas registered, in 
either 1997 or 1998, single-year annual average monitored 
PM10 levels of at least 90 percent of the PM10 
NAAQS, these areas did not exceed the formal definition of the 
PM10 NAAQS over the three-year period ending in 1999. For 
each of these four areas (i.e., Cuyahoga, Harris, New York, and San 
Diego), inventories of total PM10 are predicted to increase 
between 1996, when these areas recorded values within 10 percent of the 
PM10 standard, and 2030 when this rule will take full 
effect. Additionally, EPA is in the process of taking final action on a 
request by the State of Ohio to redesignate Cuyahoga County as 
attainment. This action is based on locally developed information and 
is consistent with the requirements of the CAA which include, among 
other requirements a 10-year plan for maintenance of the 
PM10 standard.
    For some of these areas, total PM10 inventories are 
predicted to decline or stay relatively constant from 1996 to 2007, and 
then increase after 2007. Based on inventory projections, the small 
margin of attainment which the four areas currently enjoy will likely 
erode between 1996 and 2030, and for some areas before 2007, if 
additional actions to reduce the growth of future emissions are not 
taken. We therefore consider these four areas to each individually have 
a significant risk of exceeding the PM10 standard between 
2007 and 2030 without further emission reductions. The emission 
reductions from the new standards for heavy-duty vehicles will help 
these areas attain and maintain the PM10 NAAQS in 
conjunction with other processes that

[[Page 5020]]

are currently moving these areas towards attainment.

  Table II.B-4--Areas With Significant Risk of Exceeding the PM10 NAAQS
        Without Further Emission Reductions Between 2007 and 2030
------------------------------------------------------------------------
                                              Percent          1999
                                           increases in     Population
                  Area                    PM10 emissions    (projected)
                                            (1996-2030)     (millions)
------------------------------------------------------------------------
Areas currently exceeding the PM10
 standard:
    Clark Co., NV (Las Vegas)...........              41           1.217
    El Paso, TX a.......................              14           0.611
    Hayden/Miami, AZ....................               4           0.004
    Los Angeles South Coast Air Basin,                14          14.352
     CA.................................
    Nogales, AZ.........................               3           0.025
    Phoenix, AZ.........................              24           3.012
                                         -------------------------------
        Subtotal for 6 Areas............  ..............          19.22
                                         ===============================
Areas within 10% of exceeding the PM10
 standard:
    Cuyahoga Co., OH (Cleveland)........              28           1.37
    Harris, Co., TX (Houston)...........              37           3.26
    New York Co., NY....................              14           1.55
    San Diego Co., CA...................              13           2.83
                                         -------------------------------
        Subtotal for 4 Areas............  ..............           9.01
                                         ===============================
        10 Areas........................  ..............          28.23
------------------------------------------------------------------------
a EPA has determined that PM10 nonattainment in this area is
  attributable to international transport. While reductions in heavy-
  duty vehicle emissions cannot be expected to result in attainment,
  they will help reduce the degree of PM10 nonattainment.

    EPA recognizes that the SIP process is ongoing and that 
nonattainment areas are in the process of implementing, or will be 
adopting and implementing, additional control measures to achieve the 
PM10 NAAQS in accordance with their attainment dates under 
the Clean Air Act. EPA believes, however, that as in the case of ozone, 
there are uncertainties inherent in any demonstration of attainment 
that is premised on forecasts of emission levels in future years. Even 
if these areas adopt and submit SIPs that EPA is able to approve as 
demonstrating attainment of the PM10 standard, and attain 
the standard by the appropriate attainment dates, the inventory 
analysis conducted for this rule and the history of PM10 
levels in these areas indicates that there is still a significant risk 
that these areas will need the reductions from the heavy-duty vehicle 
standards adopted today to maintain the PM10 standards in 
the long term (ie, between 2007 and 2030). In addition, this list does 
not fully consider the possibility that there are other areas which are 
now meeting the PM10 NAAQS that have at least a significant 
probability of requiring further reductions to continue to maintain it.
c. Public Health and Welfare Concerns From Exposure to Fine PM
    Many epidemiologic studies have shown statistically significant 
associations of ambient PM levels with a variety of human health 
endpoints in sensitive populations, including mortality, hospital 
admissions and emergency room visits, respiratory illness and symptoms 
measured in community surveys, and physiologic changes in mechanical 
pulmonary function. These effects have been observed in many areas with 
ambient PM levels at or below the current PM10 NAAQS. The 
epidemiologic science points to fine PM as being more strongly 
associated with some health effects, such as premature mortality, than 
coarse PM.
    Associations of both short-term and long-term PM exposure with most 
of the above health endpoints have been consistently observed. The 
general internal consistency of the epidemiologic data base and 
available findings have led to increasing public health concern, due to 
the severity of several studied endpoints and the frequent 
demonstration of associations of health and physiologic effects with 
ambient PM levels at or below the current PM10 NAAQS. The 
weight of epidemiologic evidence suggests that ambient PM exposure has 
affected the public health of U.S. populations. Specifically, increased 
mortality associated with fine PM was observed in cities with longer-
term average fine PM concentrations in the range of 16 to 21 
g/m 3.
    Current 1999 PM2.5 monitored values, which cover about a 
third of the nation's counties, indicate that at least 40 million 
people live in areas where long term ambient fine particulate matter 
levels are at or above 16 g/m 3 (37 percent of the 
population in the areas with monitors), which is the low end of the 
range of long term average PM2.5 concentrations in cities 
where statistically significant associations were found with serious 
health effects, including premature mortality (EPA, 1996).28
---------------------------------------------------------------------------

    \28\ EPA (1996) Review of the National Ambient Air Quality 
Standards for Particulate Matter: Policy Assessment of Scientific 
and Technical Information OAQPS Staff Paper. EPA-452/R-96-013.
---------------------------------------------------------------------------

    The Agency used the Regulatory Model System for Aerosols and 
Desposition (REMSAD) to model baseline and post-control ambient PM 
concentrations. For a description of the REMSAD model, the reader is 
referred to Chapter VII of the RIA.
    Our REMSAD modeled predictions allow us to also estimate the 
affected population for the counties which do not currently have 
PM2.5 monitors. According to our national modeled 
predictions, there were a total of 76

[[Page 5021]]

million people (1996 populations) living in areas with modeled annual 
average PM2.5 concentrations at or above 16 g/m 
3 (29 percent of the population).29
---------------------------------------------------------------------------

    \29\ REMSAD modeling for PM2.5 annual average 
concentrations. Total 1996 population in all REMSAD grid cells is 
263 million.
---------------------------------------------------------------------------

    The REMSAD model also allows us to estimate future PM2.5 
levels. However, the most appropriate method of making these 
projections relies on the model to predict changes between current and 
future states. Thus, we have estimated future conditions only for the 
areas with current PM2.5 monitored data (which, as just 
noted, covers about a third of the nation's counties). For these 
counties, REMSAD predicts the current level of 37 percent of the 
population living in areas where fine PM levels are at or above 16 
g/m 3 to increase to 59 percent in 2030.
    It is reasonable to anticipate that sensitive populations exposed 
to similar or higher levels, now and in the 2007 and later time frame, 
will also be at increased risk relative to the general population of 
premature mortality associated with exposures to fine PM. In addition, 
statistically significant relationships have also been observed in U.S. 
cities between PM levels and increased respiratory symptoms and 
decreased lung functions in children.
    Since EPA's examination in the mid-1990s of the epidemiological and 
toxicological evidence of the health effects of PM, many new studies 
have been published that reevaluate or extend the initial research. The 
Agency is currently reviewing these new studies to stay abreast of the 
literature and adjust as necessary its assessment of PM's health 
effects. It is worth noting that within this new body of scientific 
literature, there are two new studies funded by the Health Effects 
Institute, a EPA-industry jointly funded group, that have generally 
confirmed the mid-1990s findings of the Agency about the association of 
fine particles and premature mortality and various other respiratory 
and cardiovascular effects. HEI's National Morbidity, Mortality and Air 
Pollution Study (NMMAPS), evaluated associations between air pollutants 
and mortality in 90 U.S. cities, and also evaluated associations 
between air pollutants and hospital admissions among the elderly in 14 
U.S. cities.30 In HEI's Reanalysis of the Harvard Six Cities 
Study and the American Cancer Society Study of Particulate Air 
Pollution and Mortality, data were obtained from the original 
investigators for two previous studies.31 32, The extensive 
analyses included replication and validation of the previous findings, 
as well as sensitivity analyses using alternative analytic techniques, 
including different methods of covariate adjustment, exposure 
characterization, and exposure-response modeling.33
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    \30\ Samet JM, Zeger SL, Dominici F, Curriero F, Coursac I, 
Dockery DW, Schwartz J, Zanobetti A. 2000. The National Morbidity, 
Mortality and Air Pollution Study: Part II: Morbidity, Mortality and 
Air Pollution in the United States. Research Report No. 94, Part II. 
Health Effects Institute, Cambridge MA, June 2000.
    \31\ Dockery, D.W., Pope, C.A., III, Xu, X., Spengler, J.D., 
Ware, J.H., Fay, M.E., Ferris, B.G., Speizer, F.E. (1993) An 
association between air pollution and mortality in six U.S. cities. 
N. Engl. J. Med. 329:1753-1759.
    32 Pope, C. A., III, Thun, M. J., Namboodiri, M. M., 
Dockery, D. W., Evans, J. S., Speizer, F. E., Heath, C. W., Jr. 
(1995) Particulate air pollution as a predictor of mortality in a 
prospective study of U.S. adults. Am. J. Respir. Crit. Care Med. 
151: 669-674.
    \33\ Krewski D, Burnett RT, Goldbert MS, Hoover K, Siemiatycki 
J, Jarrett M, Abrahamowicz M, White WH. (2000) Reanalysis of the 
Harvard Six Cities Study and the American Cancer Society Study of 
Particulate Air Pollution and Mortality. Special Report to the 
Health Effects Institute, Cambridge MA, July 2000.
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    Section 202(a) provides EPA with independent authority to 
promulgate standards applicable to motor vehicle emissions that ``in 
the Administrator's judgment, cause or contribute to air pollution 
reasonably anticipated to endanger public health and welfare.'' The 
body of health evidence is supportive of our view that PM exposures are 
a serious public health concern. This concern exists for current 
exposures as well as exposures that can reasonably be anticipated to 
occur in the future. The risk is significant from an overall public 
health perspective because of the large number of individuals in 
sensitive populations that we expect to be exposed to ambient fine PM 
in the 2007 and later time frame, as well as the importance of the 
negative health effects. This information warrants a requirement to 
reduce emissions from heavy-duty vehicles, to address elevated levels 
of fine PM. This evidence supports EPA's conclusion that emissions from 
heavy-duty vehicles that lead to the formation of fine PM in 2007 and 
later will be contributing to a national air pollution problem that 
warrants action under section 202(a)(3).
d. Other Welfare Effects Associated with PM
    The deposition of airborne particles reduces the aesthetic appeal 
of buildings, and promotes and accelerates the corrosion of metals, 
degrades paints, and deteriorates building materials such as concrete 
and limestone. This materials damage and soiling are related to the 
ambient levels of airborne particulates, which are emitted by heavy-
duty vehicles. Although there was insufficient data to relate materials 
damage and soiling to specific concentrations, and thereby to allow the 
Agency to establish a secondary PM standard for these impacts, we 
believe that the welfare effects are real and that heavy-duty vehicle 
PM, NOX, SOX, and VOC contribute to materials 
damage and soiling.
e. Conclusions Regarding PM
    There is a significant risk that, despite statutory requirements 
and EPA and State efforts towards attainment and maintenance, some 
areas of the U.S. will violate the PM10 NAAQS in 2007 and 
thereafter. Heavy-duty vehicles contribute substantially to 
PM10 levels, as shown in Section II.C below.
    It is also reasonable to anticipate that concentrations of fine PM, 
as represented for example by PM2.5 concentrations, will 
also endanger public health and welfare even if all areas attain and 
maintain the PM10 NAAQS. Heavy-duty vehicles contribute to 
this air pollution problem.
    There are also important environmental impacts of PM10, 
such as regional haze which impairs visibility. Furthermore, while the 
evidence on soiling and materials damage is limited and the magnitude 
of the impact of heavy-duty vehicles on these welfare effects is 
difficult to quantify, these welfare effects support our belief that 
this action is necessary and appropriate.
    Finally, in addition to its contribution to PM inventories, diesel 
exhaust PM is of special concern because it has been implicated in an 
increased risk of lung cancer and respiratory disease in human studies, 
and an increased risk of noncancer health effects as well. The 
information provided in this section shows that there will be air 
pollution that warrants regulatory action under section 202(a)(3) of 
the Act.
4. Diesel Exhaust
    Diesel emissions are of concern to the agency beyond their 
contribution to ambient PM. As discussed in detail in the draft RIA, 
there have been health studies specific to diesel exhaust emissions 
which indicate potential hazards to human health that appear to be 
specific to this emissions source. For chronic exposure, these hazards 
included respiratory system toxicity and carcinogenicity. Acute 
exposure also causes transient effects (a wide range of physiological 
symptoms stemming from irritation and inflammation mostly in the 
respiratory system) in humans though they are highly variable depending 
on individual human susceptibility. The chemical

[[Page 5022]]

composition of diesel exhaust includes several hazardous air 
pollutants, or air toxics. In our Mobile Source Air Toxic Rulemaking 
under section 202(l) of the Act discussed above, EPA determined that 
diesel particulate matter and diesel exhaust organic gases be 
identified as a Mobile Source Air Toxic (MSAT). The purpose of the MSAT 
list is to provide a screening tool that identifies compounds emitted 
from motor vehicles or their fuels for which further evaluation of 
emissions controls is appropriate. As discussed in chapter 3 on engine 
technology, the particulate matter standard finalized today reflects 
the greatest degree of emissions reductions achievable under section 
202(l) for on-highway heavy-duty vehicle PM emissions.
a. Potential Cancer Effects of Diesel Exhaust
    The EPA has concluded that diesel exhaust is likely to be 
carcinogenic to humans by inhalation at occupational and environmental 
levels of exposure.34 The draft Health Assessment Document 
for Diesel Exhaust (draft Assessment), was reviewed in public session 
by the Clean Air Scientific Advisory Committee (CASAC) on October 12-
13, 2000.35 The CASAC found that the Agency's conclusion 
that diesel exhaust is likely to be carcinogenic to humans is 
scientifically sound. CASAC concurred with the draft Assessment's 
findings with the proviso that EPA provide modifications and 
clarifications on certain topics. The Agency expects to produce the 
finalized Assessment in early 2001. Information presented here is 
consistent with that to be provided in the final Assessment.
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    \34\ U.S. EPA (2000) Health Assessment Document for Diesel 
Exhaust: SAB Review Draft. EPA/600/8-90/057E Office of Research and 
Development, Washington, D.C. The document is available 
electronically at www.epa.gov/ncea/dieslexh.htm.
    \35\ EPA (2000) Review of EPA's Health Assessment Document for 
Diesel Exhaust (EPA 600/8-90/057E). Review by the Clean Air 
Scientific Advisory Committee (CASAC) December 2000. EPA-SAB-CASAC-
01-003.
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    In its review of the published literature, EPA found that about 30 
individual epidemiologic studies show increased lung cancer risk 
associated with diesel emissions. In the draft Assessment EPA evaluated 
22 studies that were most relevant for risk assessment, 16 of which 
reported significant increased lung cancer risks, ranging from 20 to 
167 percent, associated with diesel exhaust exposure. Published 
analytical results of pooling many of the 30 studies showed that on 
average, the risks were increased by 33 to 47 percent. Questions remain 
about the influence of other factors (e.g., effect of smoking, other 
particulate sources), the quality of the individual epidemiologic 
studies, exposure levels, and consequently the precise magnitude of the 
increased risk of lung cancer. From a weight of evidence perspective, 
EPA concludes that the epidemiologic evidence, as well as supporting 
data from certain animal and mode of action studies, support the 
Agency's conclusion that exposure to diesel exhaust is likely to pose a 
human lung cancer hazard to occupationally exposed individuals as well 
as to the general public exposed to typically lower environmental 
levels of diesel exhaust.
    Risk assessments in the peer-reviewed literature have attempted to 
assess the lifetime risk of lung cancer in workers occupationally 
exposed to diesel exhaust. These estimates suggest that lung cancer 
risk may range from 10-4 to 10-2. 36 
37 38 The Agency recognizes the significant 
uncertainties in these studies, and has not used these estimates to 
assess the possible cancer unit risk associated with ambient exposure 
to diesel exhaust.
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    \36\ California Environmental Protection Agency, Office of 
Health Hazard Assessment (CAL-EPA, OEHHA) (1998) Proposed 
Identification of Diesel Exhaust as a Toxic Air Contaminant. 
Appendix III Part B Health Risk Assessment for Diesel Exhaust. April 
22, 1998.
    \37\ Harris, J.E. (1983) Diesel emissions and Lung Cancer. Risk 
Anal. 3:83-100.
    \38\ Stayner, L.S., Dankovic, D., Smith, R., Steenland, K. 
(1998) Predicted Lung Cancer Risk Among Miners Exposed to Diesel 
Exhaust Particles. Am. J. of Indus. Medicine 34:207-219.
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    While available evidence supports EPA's conclusion that diesel 
exhaust is likely to be a human lung carcinogen, and thus is likely to 
pose a cancer hazard to humans, EPA has concluded that the available 
data are not sufficient to develop a confident estimate of cancer unit 
risk. The absence of a cancer unit risk for diesel exhaust limits our 
ability to quantify, with confidence, the potential impact of the 
hazard (magnitude of risk) on exposed populations. In the draft 
Assessment, EPA acknowledged this limitation and provided a discussion 
of the possible environmental cancer risk consistent with the majority 
of the occupational epidemiological findings of increased lung cancer 
risk and the exposure differences between the occupational and 
environmental settings.39 The Agency concluded in developing 
its perspective on risk that there is a reasonable potential that 
environmental lifetime cancer risks (``environmental risk range'') from 
diesel exhaust may exceed 10-5 and could be as high as 
10-3.40
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    \39\ See Chapter 8.4 and 9.5.2 of the U.S. EPA (2000) Health 
Assessment Document for Diesel Emissions: SAB Review Draft. EPA/600/
8-90/057E Office of Research and Development, Washington, D.C. The 
document is available electronically at www.epa.gov/ncea/dieselexh.htm.
    \40\ As used in this rule, environmental risk is defined as the 
risk (i.e. a mathematical probability) that lung cancer would be 
observed in the population after a lifetime exposure to diesel 
exhaust. Exposure levels may be occupational lifetime or 
environmental lifetime exposures. An environmental risk in the 
magnitude of 10-5 translates as the probability of lung 
cancer being evidenced in one person in a population of one hundred 
thousand having a lifetime exposure.
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    The environmental risk estimates included in the Agency's risk 
perspective are meant only to gauge the possible magnitude of risk to 
provide a means to understand the potential significance of the lung 
cancer hazard. The estimates are not to be construed as cancer unit 
risk estimates and are not suitable for use in analyses which would 
estimate possible lung cancer cases in exposed populations.
    EPA recognizes that, as in all such risk assessments, there are 
uncertainties in this assessment of the environmental risk range 
including limitations in exposure data, uncertainty with respect to the 
most accurate characterization of the risk increases observed in the 
epidemiological studies, chemical changes in diesel exhaust over time, 
and extrapolation of the risk from occupational to ambient 
environmental exposures. As with any such risk assessment for a 
carcinogen, despite EPA's thorough examination of the available 
epidemiologic evidence and exposure information, at this time EPA can 
not rule out the possibility that the lower end of the risk range 
includes zero.41 However, it is the Agency's best scientific 
judgement that the assumptions and other elements of this analysis are 
reasonable and appropriate for identifying the risk potential based on 
the scientific information currently available.
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    \41\ EPA's scientific judgment (which CASAC has supported) is 
that diesel exhaust is likely to be carcinogenic to humans. Notably, 
similar scientific judgements about the carcinogenicity of diesel 
exhaust have been recently made by the National Toxicology Program 
of the Department of Health and Human Services, NIOSH, WHO, and OEHA 
of the State of California. In the risk perspective discussed above, 
EPA recognizes the possibility that the lower end of the 
environmental risk range includes zero. The risks could be zero 
because (1) some individuals within the population may have a high 
tolerance level to exposure from diesel exhaust and therefore are 
not susceptible to the cancer risks from environmental exposure and 
(2) although EPA has not seen evidence of this, there could be a 
threshold of exposure below which there is no cancer risk.
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    The Agency believes that the risk estimation techniques that were 
used in the draft Assessment to gauge the potential for and possible 
magnitude of risk are reasonable and the CASAC

[[Page 5023]]

panel has concurred with the Assessment's discussion of the possible 
environmental risk range with an understanding that some clarifications 
and caveats would be added to the final version of the Assessment. 
Details of the technical approach used in estimating the possible range 
of environmental risks and uncertainties are provided in the RIA.
    In the draft Assessment, the Agency also provided a discussion of 
the potential overlap and/or relatively small difference between some 
occupational settings where increased lung cancer risk is reported and 
ambient environmental exposures. The potential for small exposure 
differences underscores the concern that some degree of occupational 
risk may also be present in the environmental setting and that 
extrapolation of occupational risk to ambient environmental exposure 
levels should be more confidently judged to be appropriate. The 
relevant exposure information is presented in the RIA.
    In the absence of having a unit cancer risk to assess environmental 
risk, EPA has considered the relevant epidemiological studies and 
principles for their assessment, the relative risk from occupational 
exposure as assessed by others, and relative exposure differences 
between occupational and ambient environmental levels of diesel exhaust 
exposure.
    While uncertainty exists in estimating the possible magnitude of 
the environmental risk range, the likely hazard to humans together with 
the potential for significant environmental risks leads the Agency to 
believe that diesel exhaust emissions should be reduced in order to 
protect the public's health. We believe that this is a prudent measure 
in light of:
     The designation that diesel exhaust is likely to be 
carcinogenic to humans,
     The exposure of the entire population to various levels of 
diesel exhaust,
     The consistent observation of significantly increased lung 
cancer risk in workers exposed to diesel exhaust, and
     The potential overlap and/or relatively small difference 
between some occupational settings where increased lung cancer risk is 
reported and ambient exposures.
    In the late 1980s, the International Agency for Research on Cancer 
(IARC) determined that diesel exhaust is ``probably carcinogenic to 
humans'' and the National Institute for Occupational Safety and Health 
classified diesel exhaust a ``potential occupational 
carcinogen.''42 43 Based on IARC findings, the 
State of California identified diesel exhaust in 1990 as a chemical 
known to the State to cause cancer. In 1996, the International 
Programme on Chemical Safety of the World Health Organization listed 
diesel exhaust as a ``probable'' human carcinogen.44 In 
1998, the California Office of Environmental Health Hazard Assessment 
(OEHHA, California EPA) identified diesel PM as a toxic air contaminant 
due to the noncancer and cancer hazard and because of the potential 
magnitude of the cancer risk.45 Most recently, the U.S. 
Department of Health and Human Services National Toxicology Program 
designated diesel exhaust particles as ``reasonably anticipated to be a 
human carcinogen'' in its Ninth Report on Carcinogens.46 The 
concern for a carcinogenicity hazard resulting from diesel exhaust 
exposures is longstanding and widespread.
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    \42\ National Institute for Occupational Safety and Health 
(NIOSH) (1988) Carcinogenic effects of exposure to diesel exhaust. 
NIOSH Current Intelligence Bulletin 50. DHHS, Publication No. 88-
116. Centers for Disease Control, Atlanta, GA.
    43 International Agency for Research on Cancer (1989) 
Diesel and gasoline engine exhausts and some nitroarenes, Vol. 46. 
Monographs on the evaluation of carcinogenic risks to humans. World 
Heath Organization, International Agency for Research on Cancer, 
Lyon, France.
    \44\ World Health Organization (1996) Diesel fuel and exhaust 
emissions: International program on chemical safety. World Health 
Organization, Geneva, Switzerland.
    \45\ Office of Environmental Health Hazard Assessment (1998) 
Health risk assessment for diesel exhaust, April 1998. California 
Environmental Protection Agency, Sacramento, CA.
    \46\ U.S. Department of Health and Human Services (2000) Ninth 
report on carcinogens. National Toxicology Program, Research 
Triangle Park, NC. ehis.niehs.nih.gov/roc/toc9.html.
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b. Noncancer Effects of Diesel Exhaust
    The acute and chronic exposure-related noncancer effects of diesel 
exhaust emissions are also of concern to the Agency. Acute exposure to 
diesel exhaust can result in physiologic symptoms consistent with 
irritation and inflammation, and evidence of immunological effects 
including increased reaction to allergens and some symptoms associated 
with asthma. The acute effects data, however, lack sufficient detail to 
permit the calculation of protective levels for human exposure.
    For chronic diesel exhaust exposure, EPA is completing the 
development of an inhalation reference concentration (RfC). The RfC is 
an estimate of the continuous human inhalation exposure (including 
sensitive subgroups) that is likely to be without an appreciable risk 
of deleterious noncancer effects during a lifetime. While the limited 
amount of human data are suggestive of respiratory distress, animal 
test data are quite definitive in providing a basis to anticipate a 
hazard to the human lung based on the irritant and inflammatory 
reactions in test animals. Thus, EPA believes that chronic diesel 
exhaust exposure, at sufficient exposure levels, increases the hazard 
and risk of an adverse health effect. Based on CASAC advice regarding 
the use of the animal data to derive the RfC, the Agency will provide 
in the final Assessment in 2001 an RfC based on diesel exhaust effects 
in test animals of approximately 5 g/m 3.
    In addition, it is also instructive to recognize that diesel 
exhaust particulate matter is part of ambient fine PM. A qualitative 
comparison of adverse effects of exposure to ambient fine PM and diesel 
exhaust particulate matter shows that the respiratory system is 
adversely affected in both cases, though a wider spectrum of adverse 
effects has been identified for ambient fine PM. Relative to the diesel 
PM database, there is a wealth of human data for fine PM noncancer 
effects. Since diesel exhaust PM is a component of ambient fine PM, the 
fine PM health effects data base can be informative. The final 
Assessment will discuss the fine PM health effects data and its 
relation to evaluating health effects associated with diesel exhaust.
5. Other Criteria Pollutants
    The standards being finalized today will help reduce levels of 
three other pollutants for which NAAQS have been established: carbon 
monoxide (CO), nitrogen dioxide (NO2), and sulfur dioxide 
(SO2). As of July, 2000, every area in the United States has 
been designated to be in attainment with the NO2 NAAQS. 
There were 28 areas designated as nonattainment with the SO2 
standard, and 17 areas designated CO nonattainment areas.
    A health threat of carbon monoxide at outdoor levels occurs for 
those who suffer from cardiovascular disease, such as angina petoris, 
where it can exacerbate the effects. Studies also show that outdoor 
levels can lower peak performance from individuals that are exercising 
and lower exercise tolerance of sensitive individuals. EPA believes 
that epidemiological evidence suggests that there is a risk of 
premature mortality and lowered birth weight from CO 
exposure.47 The Carbon Monoxide Criteria Document was 
finalized in

[[Page 5024]]

August 2000 and made available to the public at that time.
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    \47\ U.S. Environmental Protection Agency, Air Quality Criteria 
for Carbon Monoxide, June 2000.
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6. Other Air Toxics
    In addition to NOX and particulates, heavy-duty vehicle 
emissions contain several other substances that are known or suspected 
human or animal carcinogens, or have serious noncancer health effects. 
These include benzene,1,3-butadiene, formaldehyde, acetaldehyde, 
acrolein, and dioxin. For some of these pollutants, heavy-duty engine 
emissions are believed to account for a significant proportion of total 
nation-wide emissions. Although these emissions will decrease in the 
short term, they are expected to increase between 2010 and 2020 without 
the emission limits, as the number of miles traveled by heavy-duty 
trucks increases. In the RIA, we present current and projected 
exposures to benzene, 1,3-butadiene, formaldehyde, and acetaldehyde 
from all on-highway motor vehicles.
    By reducing hydrocarbon and other organic emissions, both in gas 
phase and bound to particles, the emission control program in today's 
action will also reduce the direct emissions of air toxics from HDVs. 
Today's action will reduce exposure to hydrocarbon and other organic 
emissions and therefore help reduce the impact of HDV emissions on 
cancer and noncancer health effects.
a. Benzene
    Highway mobile sources account for 42 percent of nationwide 
emissions of benzene and HDVs account for 7 percent of all highway 
vehicle benzene emissions.48 The EPA has recently 
reconfirmed that benzene is a known human carcinogen by all routes of 
exposure (including leukemia at high, prolonged air exposures), and is 
associated with additional health effects including genetic changes in 
humans and animals and increased proliferation of bone marrow cells in 
mice.49 50 51 EPA believes that the 
data indicate a causal relationship between benzene exposure and acute 
lymphocytic leukemia and suggest a relationship between benzene 
exposure and chronic non-lymphocytic leukemia and chronic lymphocytic 
leukemia. Respiration is the major source of human exposure and at 
least half of this exposure is attributable to gasoline vapors and 
automotive emissions. A number of adverse noncancer health effects 
including blood, disorders, such as preleukemia and aplastic anemia, 
have also been associated with low-dose, long-term exposure to benzene.
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    \48\ U.S. EPA (2000) 1996 National Toxics Inventory. http://www.epa.gov/ttn/uatw/nata. Inventory values for 1,3 butadiene, 
formaldehyde, acetaldehyde, and acrolein discussed below also come 
from this source.
    \49\ International Agency for Research on Cancer, IARC 
monographs on the evaluation of carcinogenic risk of chemicals to 
humans, Volume 29, Some industrial chemicals and dyestuffs, 
International Agency for Research on Cancer, World Health 
Organization, Lyon, France, p. 345-389, 1982.
    50 Irons, R.D., W.S. Stillman, D.B. Colagiovanni, and 
V.A. Henry, Synergistic action of the benzene metabolite 
hydroquinone on myelopoietic stimulating activity of granulocyte/
macrophage colony-stimulating factor in vitro, Proc. Natl. Acad. 
Sci. 89:3691-3695, 1992.
    51 Environmental Protection Agency, Carcinogenic 
Effects of Benzene: An Update, National Center for Environmental 
Assessment, Washington, DC. 1998.
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b. 1,3-Butadiene
    Highway mobile sources account for 42 percent of the annual 
emissions of 1,3-butadiene and HDVs account for 15 percent of the 
highway vehicle portion. Today's program will play an important role in 
reducing in the mobile contribution of 1,3-butadiene. Reproductive and/
or developmental effects have been observed in mice and rats following 
inhalation exposure to 1,3-butadiene.52 No information is 
available on developmental/reproductive effects in humans following 
exposure to 1,3-butadiene. In the EPA1998 draft Health Risk Assessment 
of 1,3-Butadiene, that was reviewed by the SAB, EPA proposed that 1,3-
butadiene is a known human carcinogen based on human epidemiologic, 
laboratory animal data, and supporting data such as the genotoxicity of 
1,3-butadiene metabolites.53 The Environmental Health 
Committee of EPA's Scientific Advisory Board (SAB), reviewed the draft 
document in August 1998 and recommended that 1,3-butadiene be 
classified as a probable human carcinogen, stating that designation of 
1,3-butadiene as a known human carcinogen should be based on 
observational studies in humans, without regard to mechanistic or other 
information.54 In applying the 1996 proposed Guidelines for 
Carcinogen Risk Assessment, the Agency relies on both observational 
studies in humans as well as experimental evidence demonstrating 
causality and therefore the designation of 1,3-butadiene as a known 
human carcinogen remains applicable.55 The Agency has 
revised the draft Health Risk Assessment of 1,3-Butadiene based on the 
SAB and public comments. The draft Health Risk Assessment of 1,3-
Butadiene will undergo the Agency consensus review, during which time 
additional changes may be made prior to its public release and 
placement on the Integrated Risk Information System (IRIS).
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    \52\ Environmental Protection Agency. Draft Health Risk 
Assessment of 1,3-Butadiene, National Center for Environmental 
Assessment, Office of Research and Development, U.S. EPA, EPA/600/P-
98/001A, February 1998.
    \53\ An SAB Report: Review of the Health Risk Assessment of 1,3-
Butadiene. EPA-SAB-EHC-98, August, 1998.
    \54\ Scientific Advisory Board. 1998. An SAB Report: Review of 
the Health Risk Assessment of 1,3-Butadiene. EPA-SAB-EHC-98, August, 
1998.
    \55\ [55]: EPA 1996. Proposed guidelines for carcinogen risk 
assessment. Federal Register 61(79):17960-18011.
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c. Formaldehyde
    Highway mobile sources contribute 24 percent of the national 
emissions of formaldehyde, and HDVs account for 36 percent of the 
highway portion. EPA has classified formaldehyde as a probable human 
carcinogen based on evidence in humans and in rats, mice, hamsters, and 
monkeys.56 Epidemiological studies in occupationally exposed 
workers suggest that long-term inhalation of formaldehyde may be 
associated with tumors of the nasopharyngeal cavity (generally the area 
at the back of the mouth near the nose), nasal cavity, and sinus. 
Formaldehyde exposure also causes a range of noncancer health effects, 
including irritation of the eyes (tearing of the eyes and increased 
blinking) and mucous membranes. Sensitive individuals may experience 
these adverse effects at lower concentrations than the general 
population and in persons with bronchial asthma, the upper respiratory 
irritation caused by formaldehyde can precipitate an acute asthmatic 
attack. The agency is currently conducting a reassessment of risk from 
inhalation exposure to formaldehyde.
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    \56\ Environmental Protection Agency, Assessment of Health Risks 
to Garment Workers and Certain Home Residents from Exposure to 
Formaldehyde, Office of Pesticides and Toxic Substances, April 1987.
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d. Acetaldehyde
    Highway mobile sources contribute 29 percent of the national 
acetaldehyde emissions and HDVs are responsible for approximately 33 
percent of these highway mobile source emissions. Acetaldehyde is 
classified as a probable human carcinogen and is considered moderately 
toxic by the inhalation, oral, and intravenous routes. The primary 
acute effect of exposure to acetaldehyde vapors is irritation of the 
eyes, skin, and respiratory tract. At high concentrations, irritation 
and pulmonary effects can occur, which could facilitate the uptake of 
other contaminants. The agency is currently conducting a reassessment 
of

[[Page 5025]]

risk from inhalation exposure to acetaldehyde.
e. Acrolein
    Highway mobile sources contribute 16 percent of the national 
acrolein emissions and HDVs are responsible for approximately 39 
percent of these highway mobile source emissions. Acrolein is extremely 
toxic to humans when inhaled, with acute exposure resulting in upper 
respiratory tract irritation and congestion. The Agency has developed a 
reference concentration for inhalation (RfC) of acrolein of 0.02 
micrograms/m3.57 Although no information is 
available on its carcinogenic effects in humans, based on laboratory 
animal data, EPA considers acrolein a possible human carcinogen.
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    \57\ U.S. EPA (1993) Environmental Protection Agency, Integrated 
Risk Information System (IRIS), National Center for Environmental 
Assessment, Cincinnati, OH.
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f. Dioxins
    Recent studies have confirmed that dioxins are formed by and 
emitted from heavy-duty diesel trucks and are estimated to account for 
1.2 percent of total dioxin emissions in 1995. In the environment, the 
pathway of immediate concern is the food pathway (e.g., human ingestion 
of certain foods, e.g. meat and dairy products contaminated by dioxin) 
which may be affected by deposition of dioxin from the atmosphere. EPA 
classified dioxins as probable human carcinogens in 1985. Recently EPA 
has proposed, and the Scientific Advisory Board has concurred, to 
classify one dioxin compound, 2,3,7,8-tetrachlorodibenzo-p-dioxin as a 
human carcinogen and the complex mixtures of dioxin-like compounds as 
likely to be carcinogenic to humans using the draft 1996 carcinogen 
risk assessment guidelines.58 Using the 1986 cancer risk 
assessment guidelines, the hazard characterization for 2,3,7,8-
tetrachlorodibenzo-p-dioxin is ``known'' human carcinogen and the 
hazard characterization for complex mixtures of dioxin-like compounds 
is ``probable'' human carcinogens. Acute and chronic noncancer effects 
have also been reported for dioxin.
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    \58\ U.S. EPA (2000) Exposure and Human Health Reassessment of 
2,3,7,8-Tetrachlorodibenzo-p-Dioxin (TCDD) and Related Compounds. 
Part III: Integrated Summary and Risk Characterization for 2,3,7,8-
Tetrachlorodibenzo-p-Dioxin (TCDD) and Related Compounds. External 
Review Draft. EPA/600/P-00/001Ag.
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7. Other Welfare and Environmental Effects
    Some commenters challenged the Agency's use of adverse welfare and 
environmental effects associated with emissions from heavy-duty 
vehicles as a partial basis for this rulemaking. Other commenters went 
to great lengths to support the Agency's inclusion of these welfare and 
environmental effects. Additional information has been added since the 
proposal in order to update and clarify the available information on 
welfare and environmental impacts of heavy-duty vehicle emissions. The 
following section presents information on four categories of public 
welfare and environmental impacts related to heavy-duty vehicle 
emissions: acid deposition, eutrophication of water bodies, POM 
deposition, and impairment of visibility.
a. Acid Deposition
    Acid deposition, or acid rain as it is commonly known, occurs when 
SO2 and NOX react in the atmosphere with water, 
oxygen, and oxidants to form various acidic compounds that later fall 
to earth in the form of precipitation or dry deposition of acidic 
particles.59 It contributes to damage of trees at high 
elevations and in extreme cases may cause lakes and streams to become 
so acidic that they cannot support aquatic life. In addition, acid 
deposition accelerates the decay of building materials and paints, 
including irreplaceable buildings, statues, and sculptures that are 
part of our nation's cultural heritage. To reduce damage to automotive 
paint caused by acid rain and acidic dry deposition, some manufacturers 
use acid-resistant paints, at an average cost of $5 per vehicle--a 
total of $61 million per year if applied to all new cars and trucks 
sold in the U.S.
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    \59\ Much of the information in this subsection was excerpted 
from the EPA document, Human Health Benefits from Sulfate Reduction, 
written under Title IV of the 1990 Clean Air Act Amendments, U.S. 
EPA, Office of Air and Radiation, Acid Rain Division, Washington, DC 
20460, November 1995.
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    Acid deposition primarily affects bodies of water that rest atop 
soil with a limited ability to neutralize acidic compounds. The 
National Surface Water Survey (NSWS) investigated the effects of acidic 
deposition in over 1,000 lakes larger than 10 acres and in thousands of 
miles of streams. It found that acid deposition was the primary cause 
of acidity in 75 percent of the acidic lakes and about 50 percent of 
the acidic streams, and that the areas most sensitive to acid rain were 
the Adirondacks, the mid-Appalachian highlands, the upper Midwest and 
the high elevation West. The NSWS found that approximately 580 streams 
in the Mid-Atlantic Coastal Plain are acidic primarily due to acidic 
deposition. Hundreds of the lakes in the Adirondacks surveyed in the 
NSWS have acidity levels incompatible with the survival of sensitive 
fish species. Many of the over 1,350 acidic streams in the Mid-Atlantic 
Highlands (mid-Appalachia) region have already experienced trout losses 
due to increased stream acidity. Emissions from U.S. sources contribute 
to acidic deposition in eastern Canada, where the Canadian government 
has estimated that 14,000 lakes are acidic. Acid deposition also has 
been implicated in contributing to degradation of high-elevation spruce 
forests that populate the ridges of the Appalachian Mountains from 
Maine to Georgia. This area includes national parks such as the 
Shenandoah and Great Smoky Mountain National Parks.
    A recent study of emissions trends and acidity of waterbodies in 
the Eastern United States by the General Accounting Office (GAO) found 
that sulfates declined in 92 percent of a representative sample of 
lakes from 1992 to 1999, and nitrate levels increased in 48 percent of 
the lakes sampled.60 The decrease in sulfates is consistent 
with emissions trends, but the increase in nitrates is inconsistent 
with the stable levels of nitrogen emissions and deposition. The study 
suggests that the vegetation and land surrounding these lakes have lost 
some of their previous capacity to use nitrogen, thus allowing more of 
the nitrogen to flow into the lakes and increase their acidity. 
Recovery of acidified lakes is expected to take a number of years, even 
where soil and vegetation have not been ``nitrogen saturated,'' as EPA 
called the phenomenon in a 1995 study.61 This situation 
places a premium on reductions of SOX and especially 
NOX from all sources, including HDVs, in order to reduce the 
extent and severity of nitrogen saturation and acidification of lakes 
in the Adirondacks and throughout the United States.
---------------------------------------------------------------------------

    \60\ Acid Rain: Emissions Trends and Effects in the Eastern 
United States, US General Accounting Office, March, 2000 (GOA/RCED-
00-47).
    \61\ Acid Deposition Standard Feasibility Study: Report to 
Congress, EPA 430R-95-001a, October, 1995.
---------------------------------------------------------------------------

    The SOX and NOX reductions from today's 
action will help reduce acid rain and acid deposition, thereby helping 
to reduce acidity levels in lakes and streams throughout the country 
and help accelerate the recovery of acidified lakes and streams and the 
revival of ecosystems adversely affected by acid deposition. Reduced 
acid deposition levels will also help reduce stress on forests, thereby 
accelerating reforestation efforts and improving timber production. 
Deterioration of our

[[Page 5026]]

historic buildings and monuments, and of buildings, vehicles, and other 
structures exposed to acid rain and dry acid deposition also will be 
reduced, and the costs borne to prevent acid-related damage may also 
decline. While the reduction in sulfur and nitrogen acid deposition 
will be roughly proportional to the reduction in SOX and 
NOX emissions, respectively, the precise impact of today's 
action will differ across different areas.
b. Eutrophication and Nitrification
    Eutrophication is the accelerated production of organic matter, 
particularly algae, in a water body. This increased growth can cause 
numerous adverse ecological effects and economic impacts, including 
nuisance algal blooms, dieback of underwater plants due to reduced 
light penetration, and toxic plankton blooms. Algal and plankton blooms 
can also reduce the level of dissolved oxygen, which can also adversely 
affect fish and shellfish populations.
    In 1999, NOAA published the results of a five year national 
assessment of the severity and extent of estuarine eutrophication. An 
estuary is defined as the inland arm of the sea that meets the mouth of 
a river. The 138 estuaries characterized in the study represent more 
than 90 percent of total estuarine water surface area and the total 
number of US estuaries. The study found that estuaries with moderate to 
high eutrophication conditions represented 65 percent of the estuarine 
surface area. Eutrophication is of particular concern in coastal areas 
with poor or stratified circulation patterns, such as the Chesapeake 
Bay, Long Island Sound, or the Gulf of Mexico. In such areas, the 
``overproduced'' algae tends to sink to the bottom and decay, using all 
or most of the available oxygen and thereby reducing or eliminating 
populations of bottom-feeder fish and shellfish, distorting the normal 
population balance between different aquatic organisms, and in extreme 
cases causing dramatic fish kills.
    Severe and persistent eutrophication often directly impacts human 
activities. For example, losses in the nation's fishery resources may 
be directly caused by fish kills associated with low dissolved oxygen 
and toxic blooms. Declines in tourism occur when low dissolved oxygen 
causes noxious smalls and floating mats of algal blooms create 
unfavorable aesthetic conditions. Risks to human health increase when 
the toxins from algal blooms accumulate in edible fish and shellfish, 
and when toxins become airborne, causing respiratory problems due to 
inhalation. According to the NOAA report, more than half of the 
nation's estuaries have moderate to high expressions of at least one of 
these symptoms--an indication that eutrophication is well developed in 
more than half of U.S. estuaries.
    In recent decades, human activities have greatly accelerated 
nutrient inputs, such as nitrogen and phosphorous, causing excessive 
growth of algae and leading to degraded water quality and associated 
impairments of freshwater and estuarine resources for human 
uses.62 Since 1970, eutrophic conditions worsened in 48 
estuaries and improved in 14. In 26 systems, there was no trend in 
overall eutrophication conditions since 1970.63 On the New 
England coast, for example, the number of red and brown tides and 
shellfish problems from nuisance and toxic plankton blooms have 
increased over the past two decades, a development thought to be linked 
to increased nitrogen loadings in coastal waters. Long-term monitoring 
in the United States, Europe, and other developed regions of the world 
shows a substantial rise of nitrogen levels in surface waters, which 
are highly correlated with human-generated inputs of nitrogen to their 
watersheds.
---------------------------------------------------------------------------

    \62\ Deposition of Air Pollutants to the Great Waters, Third 
Report to Congress, June, 2000.
    \63\ Deposition of Air Pollutants to the Great Waters, Third 
Report to Congress, June, 2000. Great Waters are defined as the 
Great Lakes, the Chesapeake Bay, Lake Champlain, and coastal waters. 
The first report to Congress was delivered in May, 1994; the second 
report to Congress in June, 1997.
---------------------------------------------------------------------------

    On a national basis, the most frequently recommended control 
strategies by experts surveyed by National Oceanic and Atmospheric 
Administration (NOAA) between 1992-1997 were agriculture, wastewater 
treatment, urban runoff, and atmospheric deposition.64 In 
its Third Report to Congress on the Great Waters, EPA reported that 
atmospheric deposition contributes from 2 to 38 percent of the nitrogen 
load to certain coastal waters.65 A review of peer reviewed 
literature in 1995 on the subject of air deposition suggests a typical 
contribution of 20 percent or higher.66 Human-caused 
nitrogen loading to the Long Island Sound from the atmosphere was 
estimated at 14 percent by a collaboration of federal and state air and 
water agencies in 1997.67 The National Exposure Research 
Laboratory, US EPA, estimated based on prior studies that 20 to 35 
percent of the nitrogen loading to the Chesapeake Bay is attributable 
to atmospheric deposition.68 The mobile source portion of 
atmospheric NOX contribution to the Chesapeake Bay was 
modeled at about 30 percent of total air deposition.69
---------------------------------------------------------------------------

    \64\ Bricker, Suzanne B., et al., National Estuarine 
Eutrophication Assessment, Effects of Nutrient Enrichment in the 
Nation's Estuaries, National Ocean Service, National Oceanic and 
Atmospheric Administration, September, 1999.
    \65\ Deposition of Air Pollutants to the Great Waters, Third 
Report to Congress, June, 2000.
    \66\ Valigura, Richard, et al., Airsheds and Watersheds II: A 
Shared Resources Workshop, Air Subcommittee of the Chesapeake Bay 
Program, March, 1997.
    \67\ The Impact of Atmospheric Nitrogen Deposition on Long 
Island Sound, The Long Island Sound Study, September, 1997.
    \68\ Dennis, Robin L., Using the Regional Acid Deposition Model 
to Determine the Nitrogen Deposition Airshed of the Chesapeake Bay 
Watershed, SETAC Technical Publications Series, 1997.
    \69\ Dennis, Robin L., Using the Regional Acid Deposition Model 
to Determine the Nitrogen Deposition Airshed of the Chesapeake Bay 
Watershed, SETAC Technical Publications Series, 1997.
---------------------------------------------------------------------------

    Deposition of nitrogen from heavy-duty vehicles contributes to 
elevated nitrogen levels in waterbodies. In the Chesapeake Bay region, 
modeling shows that mobile source deposition occurs in relatively close 
proximity to highways, such as the 1-95 corridor which covers part of 
the Bay surface. The new standards for heavy-duty vehicles will reduce 
total NOX emissions by 2.6 million tons in 2030. The 
NOX reductions will reduce the airborne nitrogen deposition 
that contributes to eutrophication of watersheds, particularly in 
aquatic systems where atmospheric deposition of nitrogen represents a 
significant portion of total nitrogen loadings.
c. Polycyclic Organic Matter Deposition
    EPA's Great Waters Program has identified 15 pollutants whose 
deposition to water bodies has contributed to the overall contamination 
loadings to the these Great Waters.70 One of these 15 
pollutants, a group known as polycyclic organic matter (POM), are 
compounds that are mainly adhered to the particles emitted by mobile 
sources and later fall to earth in the form of precipitation or dry 
deposition of particles. The mobile source contribution of the 7 most 
toxic POM is at least 62 tons/year and represents only those POM that 
adhere to mobile source particulate emissions.71 The 
majority of these emissions are produced by diesel engines.
---------------------------------------------------------------------------

    \70\ Deposition of Air Pollutants to the Great Waters--Third 
Report to Congress, June, 2000, Office of Air Quality Planning and 
Standards Deposition of Air Pollutants to the Great Waters--Second 
Report to Congress, Office of Air Quality Planning and Standards, 
June 1997, EPA-453/R-97-011.
    \71\ The 1996 National Toxics Inventory, Office of Air Quality 
Planning and Standards, October 1999.

---------------------------------------------------------------------------

[[Page 5027]]

    POM is generally defined as a large class of chemicals consisting 
of organic compounds having multiple benzene rings and a boiling point 
greater than 100 degrees C. Polycyclic aromatic hydrocarbons are a 
chemical class that is a subset of POM. POM are naturally occurring 
substances that are byproducts of the incomplete combustion of fossil 
fuels and plant and animal biomass (e.g., forest fires). Also, they 
occur as byproducts from steel and coke productions and waste 
incineration. Evidence for potential human health effects associated 
with POM comes from studies in animals (fish, amphibians, rats) and in 
human cells culture assays. Reproductive, developmental, immunological, 
and endocrine (hormone) effects have been documented in these systems. 
Many of the compounds included in the class of compounds known as POM 
are classified by EPA as probable human carcinogens based on animal 
data.
    Evidence for potential human health effects associated with POM 
comes from studies in animals (fish, amphibians, rats) and in human 
cells culture assays. Reproductive, developmental, immunological, and 
endocrine (hormone) effects have been documented in these systems. Many 
of the compounds included in the class of compounds known as POM are 
classified by EPA as probable human carcinogens based on animal data.
    The particulate reductions from today's action will help reduce not 
only the particulate emissions from highway diesel engines but also the 
deposition of the POM adhering to the particles, thereby helping to 
reduce health effects of POM in lakes and streams, accelerate the 
recovery of affected lakes and streams, and revive the ecosystems 
adversely affected.
d. Visibility and Regional Haze
    Visibility impairment, also called regional haze, is a complex 
problem caused by a variety of sources, both natural and anthropogenic 
(e.g., motor vehicles). Regional haze masks objects on the horizon and 
reduces the contrast of nearby objects. The formation, extent, and 
intensity of regional haze are functions of meteorological and chemical 
processes, which sometimes cause fine particle loadings to remain 
suspended in the atmosphere for several days and to be transported 
hundreds of kilometers from their sources (NRC, 1993).
    Visibility has been defined as the degree to which the atmosphere 
is transparent to visible light (NRC, 1993). Visibility impairment is 
caused by the scattering and absorption of light by particles and gases 
in the atmosphere. Fine particles (0.1 to 2.5 microns in diameter) are 
more effective per unit mass concentration at impairing visibility than 
either larger or smaller particles (NAPAP, 1991). Most of the diesel 
particle mass emitted by diesel engines falls within this fine particle 
size range. Light absorption is often caused by elemental carbon, a 
product of incomplete combustion from activities such as burning diesel 
fuel or wood. These particles cause light to be scattered or absorbed, 
thereby reducing visibility.
    Heavy-duty vehicles contribute a significant portion of the 
emissions of direct PM, NOX, and SOX that result 
in ambient PM that contributes to regional haze and impaired 
visibility. The Grand Canyon Visibility Transport Commission's report 
found that heavy-duty diesel vehicles contribute 41 percent of fine 
elemental carbon or soot, 20 percent of NOX, 7 percent of 
fine organic carbon, and 6 percent of SOX. The report also 
found that reducing total mobile source emissions is an essential part 
of any program to protect visibility in the Western U.S. The Commission 
identified mobile source pollutants of concern as VOC, NOX, 
and elemental and organic carbon. The Western Governors Association, in 
later commenting on the Regional Haze Rule and on protecting the 16 
Class I areas on the Colorado Plateau, stated that the federal 
government, and particularly EPA, must do its part in regulating 
emissions from mobile sources that contribute to regional haze in these 
areas. As described more fully later in this section, today's action 
will result in large reductions in these pollutants. These reductions 
are expected to provide an important step towards improving visibility 
across the nation. Emissions reductions being achieved to attain the 1-
hour ozone and PM10 NAAQS will assist in visibility 
improvements. Moreover, the timing of the reductions from the standards 
fits very well with the goals of the regional haze program. We will 
work with the regional planning bodies to make sure they have the 
information to take account of the reductions from this final rule in 
their planning efforts.
    The Clean Air Act contains provisions designed to protect national 
parks and wilderness areas from visibility impairment. In 1999, EPA 
promulgated a rule that will require States to develop plans to 
dramatically improve visibility in national parks. Although it is 
difficult to determine natural visibility levels, we believe that 
average visual range in many Class I areas in the United States is 
significantly less (about 50-66 percent of natural visual range in the 
West, about 20 percent of natural visual range in the East) than the 
visual range that will exist without anthropogenic air pollution. The 
final Regional Haze Rule establishes a 60-year time period for planning 
purposes, with several near term regulatory requirements, and is 
applicable to all 50 states. One of the obligations is for States to 
representative conduct visibility monitoring in mandatory Class I 
Federal areas and determine baseline conditions using data for year 
2000 to 2004. Reductions of particles, NOX, sulfur, and VOCs 
from this rulemaking will have a significant impact on moving all 
states towards achieving long-term visibility goals, as outlined in the 
1999 Regional Haze Rule.

C. Contribution from Heavy-Duty Vehicles

    Nationwide, heavy-duty vehicles are projected to contribute about 
15 percent of the total NOX inventory, and 28 percent of the 
mobile source inventory in 2007. Heavy-duty NOX emissions 
also contribute to fine particulate concentrations in ambient air due 
to the transformation in the atmosphere to nitrates. The NOX 
reductions resulting from today's standards will therefore have a 
considerable impact on the national NOX inventory. All 
highway vehicles account for 34 percent and heavy-duty highway vehicles 
account for 20 percent of the mobile source portion of national 
PM10 emissions in 2007. The heavy-duty portion of the 
inventory is often greater in the cities, and the reductions in this 
rulemaking will have a relatively greater benefit in those areas.
1. NOX Emissions
    Heavy-duty vehicles are important contributors to the national 
inventories of NOX emissions. Without NOX 
reductions from this rule, HDVs are expected to contribute 
approximately 18 percent of annual NOX emissions in 1996. 
The HDV contribution is predicted to fall to 15 percent in 2007 and 14 
percent in 2020 due to reductions from the 2004 heavy-duty rulemaking, 
and then rise again to 16 percent of total NOX inventory by 
2030 (Table II.C-1). Annual NOX reductions from this rule 
are expected to total 2.6 million tons in 2030.

[[Page 5028]]



                Table II.C-1--NOX Emissions From HDVs With and Without Reductions From This Rule
----------------------------------------------------------------------------------------------------------------
                                                             Without this rule (base case)       With this rule
----------------------------------------------------------------------------------------------   (control case)
                                                                                              ------------------
                                                           HDV annual NOX     HDV annual NOX     Reductions in
                          Year                                  tons        tons as a percent    annual HDV NOX
                                                                               of total NOX           tons
----------------------------------------------------------------------------------------------------------------
1996...................................................         4,810,000                 18                n/a
2007...................................................         3,040,000                 15             58,000
2020...................................................         2,560,000                 14          1,820,000
2030...................................................         2,960,000                 16          2,570,000
----------------------------------------------------------------------------------------------------------------

    The contribution of heavy-duty vehicles to NOX 
inventories in many MSAs is significantly greater than that reflected 
in the national average. For example, HDV contributions to total annual 
NOX is greater than the national average in the eight 
metropolitan statistical areas listed in Table II.C-2. Examples of 
major cities with a history of persistent ozone violations that are 
heavily impacted by NOX emissions from HDVs include: Los 
Angeles, Washington, DC, San Diego, Hartford, Atlanta, Sacramento. As 
presented in the table below, HDV's contribute from 22 percent to 33 
percent of the total NOX inventories in these selected 
cities. NOX emissions also contribute to the formation of 
fine particulate matter, especially in the West. In all areas, 
NOX also contributes to environmental and welfare effects 
such as regional haze, and eutrophication and nitrification of water 
bodies.

Table II.C-2--Heavy-Duty Vehicle Percent Contribution to NOX Inventories
                     in Selected Urban Areas in 2007
------------------------------------------------------------------------
                                                             HDV NOX as
                                               HDV NOX as    portion of
              MSA, CMSA / State                portion of      mobile
                                                total NOX    source NOX
                                                   (%)           (%)
------------------------------------------------------------------------
National....................................           15            28
Sacramento, CA..............................           33            37
Hartford, CT................................           28            38
San Diego, CA...............................           25            28
San Francisco, CA...........................           24            29
Atlanta, GA.................................           22            34
Los Angeles.................................           22            26
Dallas......................................           22            28
Washington-Baltimore, MSA...................           22            36
------------------------------------------------------------------------

2. PM Emissions
    Nationally, we estimate that primary emissions of PM10 
to be about 33 million tons/year in 2007. Fugitive dust, other 
miscellaneous sources and crustal material (wind erosion) constitute 
approximately 90 percent of the 2007 PM10 inventory. 
However, there is evidence from ambient studies that emissions of these 
materials may be overestimated and/or that once emitted they have less 
of an influence on monitored PM concentration than this inventory share 
would suggest. Mobile sources account for 22 percent of the 
PM10 inventory (excluding the contribution of miscellaneous 
and natural sources) and highway heavy-duty engines, the subject of 
today's action, account for 20 percent of the mobile source portion of 
national PM10 emissions in 2007.
    The contribution of heavy-duty vehicle emissions to total PM 
emissions in some metropolitan areas is substantially higher than the 
national average. This is not surprising, given the high density of 
these engines operating in these areas. For example, in Los Angeles, 
Atlanta, Hartford, San Diego, Santa Fe, Cincinnati, and Detroit, the 
estimated 2007 highway heavy-duty vehicle contribution to mobile source 
PM10 ranges from 25 to 38 percent, while the national 
percent contribution to mobile sources for 2007 is projected to be 
about 20 percent. As illustrated in Table II.C-3, heavy-duty vehicles 
operated in El Paso, Indianapolis, San Francisco, and Minneapolis also 
account for a higher portion of the mobile source PM inventory than the 
national average. These data are based on updated inventories developed 
for this rulemaking. Importantly, these estimates do not include the 
contribution from secondary PM, which is an important component of 
diesel PM.

   Table II.C-3--2007 Heavy-Duty Vehicle Contribution to Urban Mobile
                          Source PM Inventories
------------------------------------------------------------------------
                                                               HDV PM
                                                            Contribution
                        MSA, State                            to mobile
                                                             source PMGa
------------------------------------------------------------------------
National (48 State).......................................           20
Atlanta, GA MSA...........................................           25
Cincinnati-Hamilton, OH-KY-IN CMSA........................           26
Detroit-Ann Arbor-Flint, MI CMSA..........................           25
El Paso, TX MSA...........................................           23
Hartford, CT MSA..........................................           30
Indianapolis, IN MSA......................................           23
Los Angeles-Riverside-Orange County, CA CMSA..............           25
Minneapolis-St. Paul, MN-WI MSA...........................           23
San Diego, CA MSA.........................................           27
San Francisco-Oakland-San Jose, CA CMSA...................           24
Santa Fe, NM MSA..........................................          38
------------------------------------------------------------------------
a Direct exhaust emissions only; excludes secondary PM.

    The city-specific emission inventory analysis and investigations of 
ambient PM2.5 summarized in the RIA indicate that the 
contribution of diesel engines to PM inventories in several urban areas 
around the U.S. is much higher than indicated by the national PM 
emission inventories only. One possible explanation for this is the 
concentrated use of diesel engines in certain local or regional areas 
which is not well represented by the national, yearly average presented 
in national PM emission inventories. Another reason may be 
underestimation of the in-use diesel PM emission rates. Our current 
modeling incorporates deterioration only as would be experienced in 
properly maintained, untampered vehicles. We are currently in the 
process of reassessing the rate of in-use deterioration of diesel 
engines and vehicles which could significantly increase the 
contribution of HDVs to diesel PM.

[[Page 5029]]

3. Environmental Justice
    Environmental justice is a priority for EPA. The Federal government 
stated its concern, in part, over this issue through issuing Executive 
Order 12898, Federal Actions To Address Environmental Justice in 
Minority Populations and Low-Income Populations (February 11, 1994). 
This Order requires that federal agencies make achieving environmental 
justice part of their mission. Similarly, the EPA created an Office of 
Environmental Justice (originally the Office of Environmental Equity) 
in 1992, commissioned a task force to address environmental justice 
issues, oversees a Federal Advisory Committee addressing environmental 
justice issues (the National Environmental Justice Advisory Council), 
and has developed an implementation strategy as required under 
Executive Order 12898.
    Application of environmental justice principles as outlined in the 
Executive Order advances the fair treatment of people of all races, 
income, and culture with respect to the development, implementation, 
and enforcement of environmental laws, regulations, and policies. Fair 
treatment implies that no person or group of people should shoulder a 
disproportionate share of any negative environmental impacts resulting 
from the execution of this country's domestic and foreign policy 
programs.
    For the last several years, environmental organizations and 
community-based citizens groups have been working together to phase out 
diesel buses in urban areas. For example, the Natural Resources Defense 
Council initiated a ``Dump Dirty Diesel'' campaign in the 1990s to 
press for the phase out of diesel buses in New York City. Other 
environmental organizations operating in major cities such as Boston, 
Newark, and Los Angeles have joined this campaign. The Coalition for 
Clean Air worked with NRDC and other experts to perform exposure 
monitoring in communities located near distribution centers where 
diesel truck traffic is heavy. These two organizations concluded that 
facilities with heavy truck traffic are exposing local communities to 
diesel exhaust concentrations far above the average levels in outdoor 
air. The report states: ``These affected communities, and the workers 
at these distribution facilities with heavy diesel truck traffic, are 
bearing a disproportionate burden of the health risks.'' 72 
Other diesel ``hot spots'' identified by the groups are bus terminals, 
truck and bus maintenance facilities, retail distribution centers, and 
busy streets and highways.
---------------------------------------------------------------------------

    \72\ Exhausted by Diesel: How America's Dependence on Diesel 
Engines Threatens Our Health, Natural Resources Defense Council, 
Coalition for Clean Air, May 1998.
---------------------------------------------------------------------------

    While there is currently a limited understanding of the 
relationship of environmental exposures to the onset of asthma, the 
environmental triggers of asthma attacks for children with asthma have 
become increasingly well characterized.73 Asthma's burden 
falls hardest on the poor, inner city residents, and children. Among 
children up to 4 years of age, asthma prevalence increased 160 percent 
since 1980.74 African-American children have an annual rate 
of hospitalization three times that for white children, and are four 
times as likely to seek care at an emergency room.75 In 
1995, the death rate from asthma in African-American children, 11.5 per 
million, was over four times the rate in white American children, 2.6 
per million.76
---------------------------------------------------------------------------

    \73\ Asthma and the Environment: A Strategy to Protect Children, 
President's Task Force on Environmental Health Risks and Safety 
Risks to Children, January 28, 1999, Revised May, 2000.
    \74\ Asthma Statistics, National Institutes of Health, National 
Heart, Lung and Blood Institute, January, 1999.
    \75\ Asthma and the Environment: A Strategy to Protect Children, 
President's Task Force on Environmental Health Risks and Safety 
Risks to Children, January 28, 1999, Revised May, 2000. The Task 
Force was formed in conjunction with Executive Order 13045 (April 
21, 1997), is co-chaired by Department of Health and Human Services 
and EPA, and is charged with recommending strategies for protecting 
children's environmental health and safety. In April, 1998, the Task 
Force identified childhood asthma as one of its top four priorities 
for immediate attention.
    \76\ Id.
---------------------------------------------------------------------------

    Local community groups and private citizens testified at public 
hearings held for this rule that the residents of their communities 
suffer greatly, and disproportionally, from air pollution in general, 
and emissions from heavy-duty vehicles in particular. For example, a 
testifier in New York pointed out that ``since Northern Manhattan and 
the South Bronx experience asthma mortality and morbidity rates at 
three to five times greater than the citywide average, New York City's 
problem is Northern Manhattan's crisis.'' 77
---------------------------------------------------------------------------

    \77\ Testimony by Peggy Shepard, Executive Director, West Harlem 
Environmental Action, June 19th, 2000.
---------------------------------------------------------------------------

    The new standards established in this rulemaking are expected to 
improve air quality across the country and will provide increased 
protection to the public against a wide range of health effects, 
including chronic bronchitis, respiratory illnesses, and aggravation of 
asthma symptoms. These air quality and public health benefits could be 
expected to mitigate some of the environmental justice concerns related 
to heavy-duty vehicles since the rule will provide relatively larger 
benefits to heavily impacted urban areas.

D. Anticipated Emissions Benefits

    This subsection presents the emission benefits we anticipate from 
heavy-duty vehicles as a result of our new NOX, PM, and NMHC 
emission standards for heavy-duty engines. The graphs and tables that 
follow illustrate the Agency's projection of future emissions from 
heavy-duty vehicles for each pollutant. The baseline case represents 
future emissions from heavy-duty vehicles at present standards 
(including the MY2004 standards). The controlled case quantifies the 
future emissions of heavy-duty vehicles once the new standards in this 
FRM are implemented.
    We use the same baseline inventory as is used in the county-by-
county, hour-by-hour air quality analyses associated with this rule. 
However, we made a slight modification to the controlled inventory to 
incorporate the changes between the proposed and final standards. 
Because the detailed air quality analyses took several months to 
perform, we had to use the proposed standards for the air quality 
analysis. Since beginning this analysis, we updated the control case 
emission inventories to reflect the final phase-in of the 
NOX standard, slight changes to the timing of the HDGV 
standards, a temporary compliance option for introducing the low sulfur 
fuel requirements, and various hardship provisions for refiners in our 
emission inventory projections. The emission inventory calculations are 
presented in detail in the Regulatory Impact Analysis.
1. NOX Reductions
    The Agency expects substantial NOX reductions on both a 
percentage and a tonnage basis from the new standards. The RIA provides 
additional projections between 2007 and 2030. As stated previously, 
HDVs contribute about 15 percent to the national NOX 
inventory for all sources in 2007. Figure II.D-1 shows our national 
projections of total NOX emissions with and without the 
engine controls finalized today. Table II.D-1 presents the total 
reductions.78 This includes both exhaust and crankcase 
emissions.79 The standards

[[Page 5030]]

should result in close to a 90 percent reduction in NOX from 
new engines.
---------------------------------------------------------------------------

    \78\ The baseline used for this calculation is the 2004 HDV 
standards (64 FR 58472). These reductions are in addition to the 
NOX emissions reductions projected to result from the 
2004 HDV standards.
    79 We include in the NOX projections 
excess emissions, developed by the EPA's Office of Enforcement and 
Compliance, that were emitted by many model year 1998-98 diesel 
engines. This is described in more detail in Chapter 2 of the RIA.

BILLING CODE 6560-50-P
[GRAPHIC] [TIFF OMITTED] TR18JA01.000

BILLING CODE 6560-50-C

[[Page 5031]]



               Table II.D-1.--Estimated Reductions in NOX
------------------------------------------------------------------------
                                                                 NOX
                                                              reduction
                       Calendar year                          [thousand
                                                             short tons]
------------------------------------------------------------------------
2007.......................................................           58
2010.......................................................          419
2015.......................................................        1,260
2020.......................................................        1,820
2030.......................................................        2,570
------------------------------------------------------------------------

2. PM Reductions
    As stated previously, HDVs will contribute about 20 percent to the 
2007 national PM10 inventory for mobile sources. The 
majority of the projected PM reductions are directly a result of the 
exhaust PM standard. However, a modest amount of PM reductions will 
come from reducing sulfur in the fuel. For the existing fleet of heavy-
duty vehicles, a small fraction of the sulfur in diesel fuel is emitted 
directly into the atmosphere as direct sulfate, and a portion of the 
remaining fuel sulfur is transformed in the atmosphere into sulfate 
particles, referred to as indirect sulfate. Reducing sulfur in the fuel 
decreases the amount of direct sulfate PM emitted from heavy-duty 
diesel engines and the amount of heavy-duty diesel engine SOx emissions 
that are transformed into indirect sulfate PM in the 
atmosphere.80 For engines meeting the new standards, we 
consider low sulfur fuel to be necessary to enable the PM control 
technology. In other words, we do not claim an additional benefit 
beyond the new exhaust standard for reductions in direct sulfate PM for 
new engines. However, once the low sulfur fuel requirements go into 
effect, many pre-2007 model year engines would also be using low sulfur 
fuel. Because these pre-2007 model year engines are certified with 
higher sulfur fuel, they will achieve reductions in PM beyond their 
certification levels.
---------------------------------------------------------------------------

    \80\ Sulfate forms a significant portion of total fine 
particulate matter in the Northeast Chemical speciation data in the 
Northeast collected in 1995 shows that the sulfate fraction of fine 
particulate matter ranges from 20 and 27 percent of the total fine 
particle mass. Determination of Fine Particle and Concentrations and 
Chemical Composition in the Northeastern United States. 1995. 
NESCAUM, prepared by Cass, et al., September 1999.
---------------------------------------------------------------------------

    Figure II.D-2 shows our national projections of total HDV PM (TPM) 
emissions with and without the new engine controls. This figure 
includes brake and tire wear, crankcase emissions and the direct 
sulfate PM (DSPM) benefits due to the use of low sulfur fuel by the 
existing fleet. These direct sulfate PM benefits from the existing 
fleet are also graphed separately. The new standards will result in 
about a 90 percent reduction in exhaust PM from new heavy-duty diesel 
engines. The low sulfur fuel should result in more than a 95 percent 
reduction in direct sulfate PM from pre-2007 heavy-duty diesel engines. 
Due to complexities of the conversion and removal processes of sulfur 
dioxide, we do not attempt to quantify the indirect sulfate reductions 
that would be derived from this rulemaking in the inventory analysis. 
Nevertheless, we recognize that these indirect sulfate PM reductions 
contribute significant additional benefits to public health and 
welfare, and we include this effect in our more detailed air quality 
analysis.
[GRAPHIC] [TIFF OMITTED] TR18JA01.001



[[Page 5032]]



                Table II.D-2.--Estimated Reductions in PM
------------------------------------------------------------------------
                                                                  PM
                                                              reduction
                       Calendar year                          [thousand
                                                             short tons]
------------------------------------------------------------------------
2007.......................................................           11
2010.......................................................           36
2015.......................................................           61
2020.......................................................           82
2030.......................................................          109
------------------------------------------------------------------------

3. NMHC Reductions
    The standards described in Section III are designed to be feasible 
for both gasoline and diesel heavy-duty vehicles. Although the 
standards give manufacturers the same phase-in for NMHC as for 
NOX, we model the NMHC reductions for diesel vehicles to be 
fully in place in 2007 due to the application of particulate control 
technology. We believe the use of aftertreatment for PM control will 
cause the NMHC levels to be below the standards as soon as the PM 
standard goes into effect in 2007.
    HDVs account for about 3 percent of national VOC and 8 percent from 
mobile sources in 2007. Figure II.D-3 shows our national projections of 
total NMHC emissions with and without the new engine controls. This 
includes both exhaust emissions and evaporative emissions. Table II.D-3 
presents the projected reductions of NMHC due to the new standards.

BILLING CODE 6560-50-P

[[Page 5033]]

[GRAPHIC] [TIFF OMITTED] TR18JA01.002

BILLING CODE 6560-50-C

[[Page 5034]]



               Table II.D-3.--Estimated Reductions in NMHC
------------------------------------------------------------------------
                                                                 NMHC
                                                              reduction
                       Calendar year                          [thousand
                                                             short tons]
------------------------------------------------------------------------
2007.......................................................            2
2010.......................................................           21
2015.......................................................           54
2020.......................................................           83
2030.......................................................          115
------------------------------------------------------------------------

4. Additional Emissions Benefits
    This subsection looks at tons/year emission inventories of CO, 
SOX, and air toxics from HDEs. Although we are not including 
stringent standards for these pollutants in this action, we believe the 
standards will result in reductions in CO, SOX, and air 
toxics. Here, we present our anticipated benefits.
a. CO Reductions
    In 2007, HDVs are projected to contribute to approximately 5 
percent of national CO and 9 percent of CO from mobile sources. 
Although it does not include new CO emission standards, today's action 
would nevertheless be expected to result in a considerable reduction in 
CO emissions from heavy-duty vehicles. CO emissions from heavy-duty 
diesel vehicles, although already very low, would likely be reduced by 
an additional 90 percent due to the operation of emissions control 
systems that will be necessary to achieve today's new standards for 
hydrocarbons and particulate matter. CO emissions from heavy-duty 
gasoline vehicles would also likely decline as the NMHC emissions are 
decreased. Table II.D-4 presents the projected reductions in CO 
emissions from HDVs.

                Table II.D-4.--Estimated Reductions in CO
------------------------------------------------------------------------
                                                                  CO
                                                              reduction
                       Calendar year                          [thousand
                                                             short tons]
------------------------------------------------------------------------
2007.......................................................           56
2010.......................................................          317
2015.......................................................          691
2020.......................................................          982
2030.......................................................        1,290
------------------------------------------------------------------------

b. SOX Reductions
    HDVs are projected to emit approximately 0.5 percent of national 
SOX and 8 percent of mobile source SOX in 2007. 
We are requiring significant reductions in diesel fuel sulfur to enable 
certain emission control devices to function properly. We expect 
SOX emissions to decline as a direct benefit of low sulfur 
diesel fuel. The majority of these benefits will be from heavy-duty 
highway diesel vehicles; however, some benefits will also come from 
highway fuel burned in other applications such as light-duty diesel 
vehicles and nonroad engines. As discussed in greater detail in the 
section on PM reductions, the amount of sulfate particles (direct and 
indirect) formed as a result of diesel exhaust emissions will decline 
for all HD diesel engines operated on low sulfur diesel fuel, including 
the current on-highway HD diesel fleet, and those non-road HD diesel 
engines that may operate on low sulfur diesel fuel in the future. Table 
II.D-5 presents our estimates of SOX reductions resulting 
from the low sulfur fuel.

    Table II.D-5.--Estimated Reductions In SOX Due To Low Sulfur Fuel
------------------------------------------------------------------------
                                                                 SOX
                                                              reduction
                       Calendar year                          [thousand
                                                             short tons]
------------------------------------------------------------------------
2007.......................................................           79
2010.......................................................          107
2015.......................................................          117
2020.......................................................          126
2030.......................................................          142
------------------------------------------------------------------------

c. Air Toxics Reductions
    This FRM establishes new non-methane hydrocarbon standards for all 
heavy-duty vehicles and a formaldehyde standard for complete heavy-duty 
vehicles. Hydrocarbons are a broad class of chemical compounds 
containing carbon and hydrogen. Many forms of hydrocarbons, such as 
formaldehyde, are directly hazardous and contribute to what are 
collectively called ``air toxics.'' Air toxics are pollutants known to 
cause or suspected of causing cancer or other serious human health 
effects or ecosystem damage. The Agency has identified at least 20 
compounds emitted from on-road gasoline vehicles that have 
toxicological potential, 19 of which are emitted by diesel vehicles, as 
well as an additional 20 compounds which have been listed as toxic air 
contaminants by California ARB.81 82 This action 
also will reduce emissions of diesel exhaust and diesel particulate 
matter (see Section II.B for a discussion of health effects).
---------------------------------------------------------------------------

    \81\ National Air Quality and Emissions Trends Report, 1997, 
(EPA 1998), p. 74.
    \82\ California Environmental Protection Agency (1998) Report to 
the Air Resources Board on the Proposed Identification of Diesel 
Exhaust as a Toxic Air Contaminant. Appendix III, Part A: Exposure 
Assessment. April 1998.
---------------------------------------------------------------------------

    Our assessment of heavy-duty vehicle (gasoline and diesel) air 
toxics focuses on the following compounds with cancer potency estimates 
that have significant emissions from heavy-duty vehicles: benzene, 
formaldehyde, acetaldehyde, and 1,3-butadiene. These compounds are an 
important, but limited, subset of the total number of air toxics that 
exist in exhaust and evaporative emissions from heavy-duty vehicles. 
The reductions in air toxics quantified in this section represent only 
a fraction of the total number and amount of air toxics reductions 
expected from the new hydrocarbon standards.
    For this analysis, we estimate that air toxic emissions are a 
constant fraction of hydrocarbon exhaust emissions from future engines. 
Because air toxics are a

[[Page 5035]]

subset of hydrocarbons, and new emission controls are not expected to 
preferentially control one type of air toxic over another, the selected 
air toxics chosen for this analysis are expected to decline by the same 
percentage amount as hydrocarbon exhaust emissions. We have not 
performed a separate analysis for the new formaldehyde standard since 
compliance with the hydrocarbon standard should result in compliance 
with the formaldehyde standard for all petroleum-fueled engines. The 
RIA provides more detail on this analysis. Table II.D-6 shows the 
estimated air toxics reductions associated with the reductions in 
hydrocarbons.

                         Table II.D-6.--Estimated Reductions In Air Toxics (short tons)
----------------------------------------------------------------------------------------------------------------
                  Calendar year                       Benzene      Formaldehyde    Acetaldehyde    1,3-Butadiene
----------------------------------------------------------------------------------------------------------------
2007............................................              24             181              67              14
2010............................................             356           1,670             608             135
2015............................................             965           4,720           1,720             384
2020............................................           1,340           7,080           2,600             567
2030............................................           1,960          10,200           3,730             823
----------------------------------------------------------------------------------------------------------------

E. Clean Heavy-Duty Vehicles and Low-Sulfur Diesel Fuel are Critically 
Important for Improving Human Health and Welfare

    Despite continuing progress in reducing emissions from heavy-duty 
engines, emissions from these engines continue to be a concern for 
human health and welfare. Ozone continues to be a significant public 
health problem, and affects not only people with impaired respiratory 
systems, such as asthmatics, but healthy children and adults as well. 
Ozone also causes damage to plants and has an adverse impact on 
agricultural yields. Particulate matter, like ozone, has been linked to 
a range of serious respiratory health problems, including premature 
mortality, aggravation of respiratory and cardiovascular disease, 
aggravated asthma, acute respiratory symptoms, and chronic bronchitis. 
Importantly, EPA has concluded that diesel exhaust is likely to be 
carcinogenic to humans by inhalation at occupational and environmental 
levels of exposure.
    Today's action will reduce NOX, VOC, CO, PM, and 
SOX emissions from these heavy-duty vehicles substantially. 
These reductions will help reduce ozone levels nationwide and reduce 
the frequency and magnitude of predicted exceedances of the ozone 
standard. These reductions will also help reduce PM levels, both by 
reducing direct PM emissions and by reducing emissions that give rise 
to secondary PM. The NOX and SOX reductions will 
help reduce acidification problems, and the NOX reductions 
will help reduce eutrophication problems. The PM and NOX 
standard enacted today will help improve visibility. All of these 
reductions are expected to have a beneficial impact on human health and 
welfare by reducing exposure to ozone, PM, diesel exhaust and other air 
toxics and thus reducing the cancer and noncancer effects associated 
with exposure to these substances.

III. Heavy-Duty Engine and Vehicle Standards

    In this section, we describe the vehicle and engine standards we 
are finalizing today to respond to the serious air quality needs 
discussed in Section II. Specifically, we discuss:
     The CAA and why we are finalizing new heavy-duty 
standards.
     The technology opportunity for heavy-duty vehicles and 
engines.
     Our new HDV and HDE standards, and our phase-in of those 
standards.
     Why we believe the stringent standards being finalized 
today are feasible in conjunction with the low sulfur gasoline required 
under the recent Tier 2 rule and the low sulfur diesel fuel being 
finalized today.
     The effects of diesel fuel sulfur on the ability to meet 
the new standards, and what happens if high sulfur diesel fuel is used.
     Plans for future review of the status of heavy-duty diesel 
NOX emission control technology.

A. Why Are We Setting New Heavy-Duty Standards?

    We are finalizing new heavy-duty vehicle and engine standards and 
related provisions under section 202(a)(3) of the CAA, which authorizes 
EPA to establish emission standards for new heavy-duty motor vehicles. 
(See 42 U.S.C. 7521(a)(3).) Section 202(a)(3)(A) requires that such 
standards ``reflect the greatest degree of emission reduction 
achievable through the application of technology which the 
Administrator determines will be available for the model year to which 
such standards apply, giving appropriate consideration to cost, energy, 
and safety factors associated with the application of such 
technology.'' Section 202(a)(3)(B) allows EPA to take into account air 
quality information in revising such standards. Because heavy-duty 
engines contribute greatly to a number of serious air pollution 
problems, especially the health and welfare effects of ozone, PM, and 
air toxics, and because millions of Americans live in areas that exceed 
the national air quality standards for ozone or PM, we believe the air 
quality need for tighter heavy-duty standards is well founded. This, 
and our belief that a significant degree of emission reduction from 
heavy-duty vehicles and engines is achievable, giving appropriate 
consideration to cost, energy, and safety factors, through the 
application of new diesel emission control technology, further 
refinement of well established gasoline emission controls, and 
reductions of diesel fuel sulfur levels, leads us to believe that new 
emission standards are warranted.

B. Emission Control Technologies for Heavy-Duty Vehicles and Engines

    For the past 30 or more years, emission control development for 
gasoline vehicles and engines has concentrated most aggressively on 
exhaust emission control devices. These devices currently provide as 
much as or more than 95 percent of the emission control on a gasoline 
vehicle. In contrast, the emission control development work for diesels 
has concentrated on improvements to the engine itself to limit the 
emissions leaving the combustion chamber.
    However, during the past 15 years, more development effort has been 
put into diesel exhaust emission control devices, particularly in the 
area of PM control. Those developments, and recent developments in 
diesel NOX control devices, make the widespread commercial 
use of diesel exhaust emission controls feasible. Through use of these 
devices, we believe emissions control similar to that attained by 
gasoline applications will be possible with diesel applications. 
However, without low sulfur diesel fuel, these technologies cannot be 
implemented on heavy-duty diesel applications. Low sulfur diesel fuel 
will at the same time

[[Page 5036]]

also allow these technologies to be implemented on light-duty diesel 
applications.
    As discussed at length in the preamble to our proposal, several 
exhaust emission control devices have been or are being developed to 
control harmful diesel exhaust pollutants. Of these, we believe that 
the catalyzed diesel particulate trap and the NOX adsorber 
are the most likely candidates to be used to meet the very low diesel 
exhaust emission standards adopted today on the variety of applications 
in the heavy-duty diesel market. While other technologies exist that 
have the potential to provide significant emission reductions, such as 
selective catalytic reduction systems for NOX control, and 
development of these technologies is being pursued to varying degrees, 
we believe that the catalyzed diesel particulate trap and the 
NOX adsorber will be the only likely broadly applicable 
technology choice by the makers of engines and vehicles for the 
national fleet in this timeframe. However, as discussed in detail in 
the Final RIA, we strongly believe that none of these technologies can 
be brought to market on diesel engines and vehicles unless the kind of 
low sulfur diesel fuel adopted in this rule is available.
    As for gasoline engines and vehicles, improvement continues to be 
made to gasoline emissions control technology. This includes 
improvement to catalyst designs in the form of improved washcoats and 
improved precious metal dispersion. Much effort has also been put into 
improved cold start strategies that allow for more rapid catalyst 
light-off. This can be done by retarding the spark timing to increase 
the temperature of the exhaust gases, and by using air-gap manifolds, 
exhaust pipes, and catalytic converter shells to decrease heat loss 
from the system.
    These improvements to gasoline emission controls will be made in 
response to the California LEV-II standards and the federal Tier 2 
standards.83 These improvements should transfer well to the 
heavy-duty gasoline segment of the fleet. With such migration of light-
duty technology to heavy-duty vehicles and engines, we believe that 
considerable improvements to heavy-duty gasoline emissions can be 
realized, thus allowing vehicles to meet the much more stringent 
standards adopted today.
---------------------------------------------------------------------------

    \83\ See Chapter IV.A of the final Tier 2 Regulatory Impact 
Analysis, contained in Air Docket A-97-10, and McDonald, Joseph, and 
Jones, Lee, ``Demonstration of Tier 2 Emission Levels for Heavy 
Light-Duty Trucks,'' SAE 2001-01-1957.
---------------------------------------------------------------------------

    The following discussion provides more detail on the technologies 
we believe are most capable of meeting very stringent heavy-duty 
emission standards. The goal of this discussion is to describe the 
emission reduction capability of these emission control technologies 
and their critical need for diesel fuel sulfur levels as low as those 
being finalized today. But first, we present the details of the new 
emission standards being finalized today.

C. What Engine and Vehicle Standards Are We Finalizing?

1. Heavy-Duty Engine Exhaust Emissions Standards
a. FTP Standards 84
---------------------------------------------------------------------------

    \84\ The Phase 1 heavy-duty rule recently promulgated by EPA 
specified two supplemental sets of standards for heavy-duty diesel 
engines. (See 65 FR 59896, October 6, 2000.) Manufacturers of heavy-
duty diesel engines must meet these supplemental standards, the 
Supplemental Emission Test (SET, formerly referred to as the 
Supplemental Steady-State (SSS) test) and the Not-to-Exceed (NTE) 
standards, beginning in model year 2007, in addition to meeting the 
preexisting standards, which must be met using the preexisting 
federal test procedure (FTP). For the purposes of this preamble, we 
refer to the standards met using the preexisting FTP as the FTP 
standards, though the SET and NTE test procedures have now been 
added to the regulations establishing the various federal test 
procedures for heavy-duty diesel engines.
---------------------------------------------------------------------------

    The emission standards finalized today for heavy-duty engines are 
summarized in Table III.C-1. For reasons explained below, the phase-in 
schedule for these standards differs from the proposed schedule. We are 
also finalizing an incentive provision to encourage the early 
introduction of engines meeting these new standards. This incentive 
provision is explained in section III.D. In addition, we have altered 
our Averaging, Banking, and Trading (ABT) provisions from what was 
proposed. The final ABT provisions are discussed in detail in section 
VI.

   Table III.C-1.--Full Useful Life Heavy-Duty Engine Exhaust Emissions Standards and Phase-Ins for Incomplete
                                                    Vehicles
----------------------------------------------------------------------------------------------------------------
                                                                           Phase-In by Model Year a
                                                   Standard  ---------------------------------------------------
                                                  (g/bhp-hr)      2007         2008         2009         2010
----------------------------------------------------------------------------------------------------------------
Diesel............................          NOX         0.20          50%          50%          50%         100%
                                           NMHC         0.14          50%          50%          50%         100%
                                             PM         0.01         100%         100%         100%         100%
Gasoline..........................          NOX         0.20           0%          50%         100%         100%
                                           NMHC         0.14           0%          50%         100%         100%
                                             PM         0.01           0%          50%         100%        100%
----------------------------------------------------------------------------------------------------------------
a Percentages represent percent of sales.

    With respect to PM, this new standard represents a 90 percent 
reduction for most heavy-duty diesel engines from the current PM 
standard. The current PM standard for most heavy-duty engines, 0.10 g/
bhp-hr, was implemented in the 1994 model year; the PM standard for 
urban buses implemented in that same year was 0.05 g/bhp-hr; these 
standards are not changing when other standards change in the 2004 
model year timeframe. The new PM standard of 0.01 g/bhp-hr being 
finalized today is projected to require the addition of highly 
efficient PM traps to diesel engines, including those diesel engines 
used in urban buses; it is not expected to require the addition of any 
new hardware for gasoline engines.
    With respect to NMHC and NOX, these new standards 
represent significant reductions from the 2004 diesel engine standard 
which is either 2.4 g/bhp-hr NOX+NMHC, or 2.5 g/bhp-hr 
NOX+NMHC with a cap on NMHC of 0.5 g/bhp-hr. We generally 
expect that 2004 diesel engines will meet those standards with emission 
levels around 2.2 g/bhp-hr NOX and 0.2 g/bhp-hr NMHC. Like 
the PM standard, the new NOX standard is projected to 
require the addition of a highly efficient NOX emission 
control system to diesel engines which, with help from the PM trap, 
will need to be optimized to control NMHC emissions. For gasoline

[[Page 5037]]

engines, the 2005 model year standard recently finalized in the Phase 1 
heavy-duty rule is 1.0 g/bhp-hr NOX+NMHC. (See 65 FR 59896, 
October 6, 2000.) There is a direct trade off between NOX 
and NMHC emissions with a gasoline engine, but we would generally 
expect NOX levels over 0.5 g/bhp-hr and NMHC levels below 
that. Regardless of the NOX and NMHC split, today's 
standards represent significant reductions for 2008 and later engines 
that will require substantial improvement in the effectiveness of 
heavy-duty gasoline emission control technology.
    We proposed a new formaldehyde standard of 0.016 g/bhp-hr for both 
heavy-duty diesel and gasoline engines. However, we have decided not to 
finalize those standards. We proposed the formaldehyde (HCHO) standard 
because it is a hazardous air pollutant that is emitted by heavy-duty 
engines and other mobile sources. In the proposal, we stated our belief 
that formaldehyde emissions from gasoline and diesel engines are and 
will remain inherently low, but having the standard would ensure that 
excess emissions would not occur. Several commenters took issue with 
our proposed standard claiming that the benefits were nonexistent, that 
we should address toxic emissions in our toxics rulemaking, and that we 
had shown neither its technological feasibility nor its measurability. 
After further consideration we do believe that the proposed 
formaldehyde standard is not necessary because the NMHC standard we are 
promulgating today will almost certainly result in formaldehyde 
emissions well below our proposed formaldehyde standard. As a result, 
other comments on this issue such as those concerning technological 
feasibility and measurability are no longer relevant to this rule. We 
will continue to evaluate this issue to ensure that formaldehyde 
emissions do not become a problem in the future and may take action to 
consider standards if warranted.
    We believe a phase-in of the diesel NOX standard is 
appropriate. With a phase-in, manufacturers are able to introduce the 
new technology on a portion of their engines, thereby gaining valuable 
experience with the technology prior to implementing it on their entire 
fleet. Also, we are requiring that the NOX, and NMHC 
standards be phased-in together for diesel engines. That is, engines 
will be expected to meet both of these new standards, not just one or 
the other. We are requiring this because the standard finalized in the 
Phase 1 heavy-duty rule is a combined NMHC+NOX standard. 
With separate NOX and NMHC phase-ins, say 50/50/50/100 for 
NOX and 100 percent in 2007 for NMHC, the 2.5 gram engines 
being phased-out would have a 2.5 gram NOX+NMHC standard and 
a new 0.14 gram NMHC standard with which to comply. While this could be 
done, we believe that it introduces unnecessary compliance complexity 
to the program.
    In our NPRM, we requested comment on a range of possible phase-in 
schedules for NOX including anything from our primary 
proposal of 25/50/75/100 percent phase-in to a possible requirement for 
100 percent compliance in the 2007 model year. We have determined that 
a 50/50/50/100 percent phase-in schedule is the most appropriate 
schedule for several reasons.
    Some commenters argued that we should require 100 percent 
compliance in the 2007 model year because of the 0.20 gram standard was 
both technologically feasible and critical given the nation's air 
quality needs. Other commenters were concerned that 100 percent 
compliance to the 0.20 gram NOX standard in the first year 
of the program was ill advised as it would provide little opportunity 
for industry to ``field test'' new NOX control technologies. 
These commenters also expressed concern over workload burdens on 
industry members needing to redesign all of their new engines and 
vehicles in one year. Some commenters were concerned that a 25/50/75/
100 percent phase-in schedule would introduce competitiveness issues 
whereby those vehicles equipped with new NOX control 
technology may be less attractive to some buyers than vehicles without 
the technology, making them difficult for manufacturers to sell.
    We set standards and implementation schedules based on many factors 
including technological feasibility, cost, energy, and safety. 
Considering these factors, we believe that industry should be provided 
the flexibility of having a phase-in of the new NOX 
standard. As discussed in section III.E below, we believe the 0.20 gram 
NOX standard is feasible in the 2007 time frame. However, we 
believe a phase-in is appropriate for a couple of reasons. First, the 
phase-in will provide industry with the flexibility to roll out the 
NOX control technology on only a portion of their fleet. 
This will allow them to focus their resources on that half of their 
fleet being brought into compliance in 2007. This ability to focus 
their efforts will increase both the efficiency and the effectiveness 
of those efforts. Second, a phase-in allows industry the ability to 
introduce the new technology on those engines it believes are best 
suited for a successful implementation which, in turn, provides a 
valuable opportunity to refine that technology on only a portion of 
their product line prior to the next push toward full implementation.
    Another concern with respect to our proposed phase-in schedule was 
raised by several commenters and pertains to its interaction with the 
final implementation schedule for the new supplemental requirements 
(the Supplemental Emission Test, SET, and the Not-to-Exceed, NTE). 
These requirements, finalized in the Phase 1 heavy-duty final rule, 
will be implemented in the 2007 model year on all heavy-duty diesel 
engines. (See 65 FR 59896, October 6, 2000.) Under a 25/50/75/100 
percent phase-in schedule of new diesel engine emission requirements, 
25 percent of engines in the 2007 model year would meet 0.20 and 0.01 
g/bhp-hr NOX and PM, while 75 percent would meet 2.5 and 
0.01 g/bhp-hr NOX and PM. Further, all of those engines 
would be required, beginning in the 2007 model year, to meet the 
supplemental requirements based on the FTP emission standards to which 
they were certified. A 25/50/75/100 percent phase-in schedule would 
change the supplemental requirements for those 25 percent of engines in 
the 2008 model year that would have to change to meet the new 50 
percent compliance requirement. This change would be required even 
though the supplemental requirements on those 25 percent of engines 
were first implemented only one model year earlier, in model year 2007. 
Commenters have questioned whether this is consistent with section 
202(a)(3)(c) of the Clean Air Act, which requires that standards for 
heavy-duty vehicles and engines apply for no less than three model 
years without revision. Under this argument, the supplemental 
requirements implemented in the 2007 model year must be allowed three 
model years of stability, meaning that no changes can be required to 
those standards until the 2010 model year.
    The final phase-in schedule, 50/50/50/100 percent, addresses any 
concerns about violating the stability requirement of the Act and 
addresses the technology and lead time benefits of a phase-in as 
discussed above.85 While this phase-in does not provide 
certain commenters with their goal of 100 percent implementation of 
very low NOX engines in 2007, we believe it is

[[Page 5038]]

appropriate for the technology, cost, and other reasons described 
above. This 50/50/50/100 percent phase-in schedule does provide a more 
rapid implementation of low NOX engines and, more 
importantly, provides more air quality benefits in 2007 than would our 
proposed phase-in schedule. We are also finalizing provisions that 
would encourage manufacturers to introduce clean technology, both 
diesel and gasoline, earlier than required in return for greater 
flexibility during the later years of our phase-in. These optional 
early incentive provisions are analogous to those included in our 
light-duty Tier 2 rule and are discussed in more detail in section 
III.D. We have also revised our Averaging, Banking, and Trading program 
to increase flexibility as discussed further in section VI.
---------------------------------------------------------------------------

    \85\ EPA need not determine, at this time, whether the 25/50/75/
100 percent phase-in schedule violates section 202(a)(3)(c), as the 
50/50/50/100 percent phase-in schedule clearly does not and is 
available to all manufacturers.
---------------------------------------------------------------------------

    For gasoline engines, we proposed 100 percent compliance in the 
2007 model year. However, since the proposal was published, we have set 
new standards for heavy-duty gasoline engines that take effect in the 
2005 model year. Therefore, the three year stability requirement of the 
CAA requires that today's new standards not apply until the 2008 model 
year at the earliest. Further, while we had not proposed a phase-in for 
gasoline standards, based on comments received we believe that a phase-
in should be provided. The phase-in will allow manufacturers to 
implement improved gasoline control technologies on their heavy-duty 
gasoline engines in the same timeframe as they implement those 
technologies on their Tier 2 medium-duty passenger vehicles (MDPV). 
This consistency with Tier 2 is discussed in more detail below in 
section III.C.2 on vehicle standards. Note that the gasoline engine 
phase-in schedule is the same as but separate from the gasoline vehicle 
phase-in schedule discussed below. As we have done for diesel engines, 
we have also revised our Averaging, Banking, and Trading program for 
gasoline engines to increase flexibility as discussed further in 
section VI.
    For a discussion of why we believe these standards are 
technologically feasible in the time frame required, refer to section 
III.E below and for a more detailed discussion refer to the RIA 
contained in the docket. The averaging, banking, and trading (ABT) 
provisions associated with today's standards are discussed in Section 
VI of this preamble. The reader should refer to that section for more 
details.
b. Supplemental Provisions for HD Diesel Engines (SET & NTE)
    In addition to the new FTP standards for HD diesel engines 
contained in today's final action, we are also finalizing the 
supplemental emission standards we proposed to apply to the new HDDEs, 
with a number of changes as discussed in this section. The supplemental 
provisions will help ensure that HD diesel engines achieve the expected 
in-use emission reductions over a wide range of vehicle operation and a 
wide range of ambient conditions, not only the test cycle and 
conditions represented by the traditional FTP. The Agency has 
historically relied upon the FTP and the prohibition of defeat devices 
to ensure that HDDE emission control technologies which operate during 
the laboratory test cycle continue to operate in-use. The supplemental 
provisions are a valuable addition to the FTP and the defeat device 
prohibition to ensure effective in-use emission control. The 
supplemental provisions for HD diesel engines consist of two principal 
requirements, the supplemental emission test and associated standards 
(SET),86 and the not-to-exceed test and associated standards 
(NTE). The supplemental emission standards finalized today for heavy-
duty diesel engines are summarized in Table III.C-2.
---------------------------------------------------------------------------

    \86\ In the Phase 1 rulemaking, the Supplemental Emission Test 
was referred to as the supplemental steady state test. As discussed 
in the Phase 1 rule, the supplemental steady state test is based on 
and is consistent with the European Commissions ``EURO III ESC'' 
test. (See 65 FR 59915.) In this final rule we have renamed the 
supplemental steady state test the Supplemental Emission Test (SET).

 Table III.C-2.--Full Useful Life Heavy-Duty Diesel Engine Supplemental
                       Exhaust Emissions Standards
------------------------------------------------------------------------
                                             Requirements for NOX, NMHC,
             Supplemental test                           PM
------------------------------------------------------------------------
Supplemental emission test................  1.0  x  FTP standard (or
                                             FEL).
Not-to-exceed test........................  1.5  x  FTP standard (or
                                             FEL).
------------------------------------------------------------------------

    The SET and NTE test procedures were recently adopted for 2007 on-
highway HD diesel engines. (See 65 FR 59896, October 6, 2000.) In the 
recent HD Phase 1 rulemaking which promulgated the SET and NTE, the 
supplemental provisions were finalized in the context of the emission 
control technology expected to be used to meet the 2004 FTP standards, 
i.e., injection timing strategies and cooled EGR. In this final action, 
we are finalizing a number of changes to the supplemental provisions to 
address specific technical issues raised by commenters and which result 
from the expected application of high efficiency exhaust emission 
control devices on HD diesel engines and vehicles to meet today's new 
standards. These changes are minor in nature and will not impact the 
emission reductions we expect from the Phase 2 standards. These changes 
are discussed in the following sections. Additional discussion 
regarding the supplemental provisions for HDDEs is contained in the RIA 
and the Response to Comments (RTC) for this final rule, as well as in 
Section III.E of this preamble (``Feasibility of the New Engine and 
Vehicle Standards'').
i. Supplemental Emission Test
    We are finalizing supplemental emission test provisions for HD 
diesel engines and vehicles certified to the new FTP standards 
contained in this final rule. The SET emission standard is equal to 1.0 
times the FTP standard or FEL for HD diesel engines. Emission results 
from this test must meet the numerical standards for the FTP. The SET 
requirements are phased-in beginning with the 2007 model year, 
consistent with the phase-in of the new FTP standards. The supplemental 
emission test duty cycle consists of 13 modes of speed and torque, 
primarily covering the typical highway cruise operating range of heavy-
duty diesel engines. The emission results from each of the modes are 
weighted by defined factors in the regulations, and the final weighted 
emission value for each pollutant must meet the SET standard. In 
addition, several of the 13 individual modes are in the NTE control 
zone, and must meet the applicable NTE requirements. The SET test is a 
laboratory test performed using an engine dynamometer under the same 
conditions which apply to the FTP, as specified in the regulations. 
(See 40 CFR 86.1360.)
    The regulations for the SET in model year 2007 as they apply to the 
2004 FTP emission standards contain additional steady-state test point 
emission limits. The Phase 1 supplemental requirements define a 
``Maximum Allowable Emission Limit'' (MAEL) which the engines must 
comply with. The Phase 1 regulations allowed EPA to randomly select up 
to three steady-state test points prior to certification which the 
manufacturer would test to show compliance with the MAEL. These test 
points are referred to as ``mystery points''. In this final rule we 
have eliminated the MAEL for engines certified to the Phase 2 
standards. The MAEL assures that an engine is calibrated to maintain 
emission control similar to the SET test under steady state conditions 
across the engine map, not just at the pre-defined 13 test points

[[Page 5039]]

which comprise the SET test. For Phase 1 engines the MAEL was necessary 
to ensure this potential for gaming did not occur because the 
difference between the FTP standard and the NTE standard could be 
large, for example, 0.625 g/bhp-hr for NMHC + NOX. However, 
for Phase 2 engines the NTE requirements are a mere 0.10 g/bhp-hr 
NOX greater than the FTP standard. Considering this small 
increment, we have eliminated the MAEL for Phase 2 engines because it 
is redundant with the NTE. For the same reasons, we have eliminated the 
certification ``mystery points'' for engines complying with today's 
diesel engine standards.
ii. Not-to-Exceed
    We are also finalizing revisions to the not-to-exceed emission 
standards for HD diesel engines certified to the Phase 2 FTP standards 
contained in this final rule. These NTE procedures apply under engine 
operating conditions within the range specified in the NTE test 
procedure that could reasonably be expected to be seen in normal 
vehicle operation and use. (See 40 CFR 86.1370.) The NTE procedure 
defines limited and specific engine operating regions (i.e., speed and 
torque conditions) and ambient operating conditions (i.e., altitude, 
temperature, and humidity conditions) which are subject to the NTE 
emission standards. Emission results from this test procedure must be 
less than or equal to 1.5 times the FTP standards (or FEL) for 
NOX, NMHC, and PM. The new NTE requirements are phased-in 
starting with the 2007 model year, consistent with the new FTP 
standards.
    The Not-To-Exceed (NTE) provisions were recently finalized for 
HDDEs certified to the 2004 FTP emission standards with implementation 
beginning in model year 2007. (See 65 FR 59896, October 6, 2000.) The 
NTE approach establishes an area (the ``NTE control area'') under the 
torque curve of an engine where emissions must not exceed a specified 
value for any of the regulated pollutants.87 The NTE 
requirements would apply under engine operating conditions that could 
reasonably be expected to be seen in normal vehicle operation and use 
which occur during the conditions specified in the NTE test procedure. 
(See 40 CFR 86.1370.) This test procedure covers a specific range of 
engine operation and ambient operating conditions (i.e., temperature, 
altitude, and humidity). The NTE control area, emissions standards, 
ambient conditions and test procedures for HDDEs are described in the 
regulations.
---------------------------------------------------------------------------

    \87\ Torque is a measure of rotational force. The torque curve 
for an engine is determined by an engine ``mapping'' procedure 
specified in the Code of Federal Regulations. The intent of the 
mapping procedure is to determine the maximum available torque at 
all engine speeds. The torque curve is merely a graphical 
representation of the maximum torque across all engine speeds.
---------------------------------------------------------------------------

    The NTE multiplier promulgated in the previous final rulemaking for 
HD diesel engines certified to the 2004 FTP standards is 1.25  x  FTP 
standard (e.g., 1.25  x  2.5g/bhp-hr NMHC+NOX and 1.25  x  
0.1 g/bhp-hr PM). We believe the NTE cap finalized today (1.5  x  the 
Phase 2 FTP standards or FEL) allows sufficient headroom above the FTP 
standard to accommodate the technical challenges necessary to meet the 
NTE standard which must be met over a broader range of ambient 
conditions, a shorter time period, and a wider variety of operating 
conditions, than the FTP or the SET. While the 1.5 NTE multiplier we 
are finalizing is greater than what we proposed, in absolute terms the 
NTE requirement for Phase 2 engines is much smaller than for Phase 1 
engines (i.e., the magnitude of the cap in g/bhp-hr emissions), and the 
Phase 2 NTE cap will help ensure the emission reductions we expect from 
the Phase 2 standards will occur in-use. The NTE requirements have been 
modified from what we proposed based on our assessment of the emission 
performance of the exhaust emission control devices that will be used 
to meet the new FTP standards (e.g., catalyzed particulate traps and 
NOX adsorbers). Under the program finalized today, an NTE 
limit of 1.5  x  the NOX FEL would apply to 2007 and later 
model year engines certified with FELs less than 1.5 g/bhp-hr 
NOX. As discussed throughout this notice, the stringent 2007 
PM standard, 0.01 g/bhp-hr, can be met with the use of catalyzed 
particulate traps. Because of the very low particulate matter emissions 
which will be emitted by engines meeting the PM standard, this final 
rule also establishes a minimum PM NTE requirement for engines 
certified with FELs below 0.01 g/bhp-hr at 1.5  x  the FTP standard, 
not the FEL. Based on our assessment of the expected exhaust emission 
control devices and their performance, the NTE standard of 1.5  x  FTP 
standard is both technologically feasible and appropriate. A detailed 
discussion of the feasibility of the NTE requirements is contained in 
the RIA for this final rule.
    Today's action allows the NTE deficiency provisions we recently 
finalized for 2007 HDDEs meeting the 2004 FTP standards to be used by 
HDDEs meeting the standards contained in today's final rule (See 40 CFR 
86.007-11(a)(4)(iv) in the regulations, and 65 FR 59914 of the Phase 1 
rule for a detailed discussion of the NTE deficiencies.). These 
deficiency provisions are similar to the deficiency provisions which 
currently apply to LD and HD on-board diagnostic systems. This will 
allow the Administrator to accept a HDDE as compliant with the NTE even 
though some specific requirements are not fully met. This provision 
will be available for manufacturers through 2013, though it will be 
more limited after 2009 as described below. In the Phase 1 rule, the 
Agency finalized deficiency provisions which were allowed through model 
year 2009. In this rule, it is appropriate to extend the availability 
of the NTE deficiency provisions beyond 2009. Given the nature of the 
phase-in requirements in this rule, manufacturers may be introducing 
new engine families certified to the Phase 2 NOX and NMHC 
standards as late as model year 2010, and these families may need 
limited access to a NTE deficiency for a few years after their 
introduction. Therefore, we have extended the availability of 
deficiencies through model year 2013, but with one constraint. Given 
the considerable lead time available, we have limited the number of 
deficiencies to three per engine family for 2010 through 2013.
    In addition, we have made a number of changes to the NTE 
requirements to address specific technical issues which arise from the 
application of high efficiency exhaust emission control devices to 
HDDEs. These provisions will only be summarized here. A detailed 
discussion is contained in the RIA and the RTC for this final rule. 
These changes include: engine start-up provisions; exhaust emission 
control device warm-up provisions; modifications of the NTE control 
zone; and adjustments to the NTE minimum emissions sample time.
    Under this final rule, the NTE requirements will not apply during 
engine start-up conditions. EPA intended to include the provision 
excluding start-up provisions from the NTE requirements under the Phase 
1 rulemaking, and it was discussed in the preamble for both the Phase 1 
proposal and final rule. However, this provision was inadvertently left 
out of the regulations. We have corrected this in today's rule for both 
Phase 1 and Phase 2 engines. In addition, with the application of 
advanced exhaust emission control devices, an exhaust emission control 
device warm-up provision is a necessary criterion for the NTE. 
Specifically, until the exhaust gas temperature on the outlet side of 
the exhaust emission control device(s)

[[Page 5040]]

achieves 250 degrees Celsius, the engine is not subject to the NTE. 
Additional discussion of this provision is contained in the RIA.
    We have made three changes to the NTE engine control zone. First, 
we have expanded the NTE engine control zone for engines certified to 
the new 0.01 g/bhp-hr PM standard. The NTE requirements as specified in 
the regulations for engines certified to the 2004 FTP standards provide 
specific ``PM carve-outs'' to the NTE control zone. These carve-outs 
define an area of the engine operating regime (speed and torque area) 
to which the NTE does not apply for PM emissions. (See 65 FR 59961.) 
The PM only carve-outs were specified because, under certain engine 
operating regions, the NTE requirements for PM could not be met with 
the technology projected to be used to meet the 2004 FTP standards. 
However, as discussed in the RIA, the advanced PM trap technology that 
will be used to meet the PM standard contained in today's final rule is 
very efficient at controlling PM emissions across the entire NTE 
control zone. Due to the high PM reduction capabilities of catalyzed PM 
traps, there is no need for the PM specific carve-outs. Therefore, we 
have eliminated the NTE PM carve-outs for Phase 2 engines. Second, we 
have added a provision which would allow a manufacturer to exclude 
defined regions of the NTE engine control zone from NTE compliance if 
the manufacturer could demonstrate that the engine, when installed in a 
specified vehicle(s), is not capable of operating in such regions. 
Finally, we have added a provision which would allow a manufacturer to 
petition the Agency to limit testing in a defined region of the NTE 
engine control zone during NTE testing. This optional provision would 
require the manufacturer to provide the Agency with in-use operation 
data which the manufacturer could use to define a single, continuous 
region of the NTE control zone. This single area of the control zone 
must be specified such that operation within the defined region 
accounts for 5 percent or less of the total in-use operation of the 
engine, based on the supplied data. Further, to protect against gaming 
by manufacturers, the defined region must generally be elliptical or 
rectangular in shape, and share a boundary with the NTE control zone. 
If approved by EPA, the regulations then disallow testing with sampling 
periods in which operation within the defined region constitutes more 
than 5.0 percent of the time-weighted operation within the sampling 
period.
    We have also changed the minimum emissions sample time approach for 
NTE testing to address technical issues specific to the advanced 
exhaust emission control devices anticipated to be used to meet the NTE 
requirements. We proposed that the minimum emission sample time for the 
NTE was 30 seconds, which is what we recently finalized for engines 
certified to the Phase 1 standards. This short sample time was 
sufficient to ensure that momentary spikes in emissions (e.g., such as 
could occur in a two or three second time frame) could not be isolated 
for determining compliance with the NTE (e.g., an NTE test must be no 
shorter than a 30 second average). However, the use of highly efficient 
exhaust emission control devices complicates the minimum sample time 
requirements because of the potential for short-duration emission 
increases during regeneration events. We have adjusted the minimum 
sample time requirements to address this issue as follows (a detailed 
discussion of the need for this change is contained in the RIA). The 
regulations specify that the NTE sample time can be as short as 30 
seconds provided no regeneration events occur within the sample period. 
However, if a regeneration event is included in the sample time, the 
sample time must include the period of time from the start of one 
regeneration event to the start of the next regeneration event, for 
each regeneration included in the sample. A regeneration event is 
determined by the engine manufacturer. This second provision regarding 
the minimum NTE sample time also cannot be shorter than 30 seconds. 
This sample time provision applies to any HDDE engine equipped with an 
exhaust emission control device which requires discreet regeneration 
events, regardless of the nature of the regeneration (e.g., 
NOX regeneration, desulfation).
c. Crankcase Emissions Control
    Crankcase emissions are the pollutants that are emitted in the 
gases that are vented from an engine's crankcase. These gases are also 
referred to as ``blowby gases'' because they result from engine exhaust 
from the combustion chamber ``blowing by'' the piston rings into the 
crankcase. These gases are vented to prevent high pressures from 
occurring in the crankcase. Our emission standards have historically 
prohibited crankcase emissions from all highway engines except 
turbocharged heavy-duty diesel engines. The most common way to 
eliminate crankcase emissions has been to vent the blowby gases into 
the engine air intake system, so that the gases can be recombusted. We 
made the exception for turbocharged heavy-duty diesel engines in the 
past because of concerns about fouling that could occur by routing the 
diesel particulates (including engine oil) into the turbocharger and 
aftercooler. Our concerns are now alleviated by newly developed closed 
crankcase filtration systems, specifically designed for turbocharged 
heavy-duty diesel engines. These new systems (discussed more fully in 
Section III.E below and in Chapter III of the Final RIA) are already 
required for new on-highway diesel engines under the EURO III emission 
standards.
    In today's action, we are eliminating the exception for 
turbocharged heavy-duty diesel engines starting in the 2007 model year. 
Manufacturers will be required to control crankcase emissions from 
these engines, preferably by routing them back to the engine intake or 
to the exhaust stream upstream of the exhaust emission control devices. 
However, in response to the manufacturers' comments, we are finalizing 
the crankcase control requirement to allow manufacturers to treat 
crankcase emissions from these engines the same as other exhaust 
emissions (i.e., we provide a performance requirement and leave the 
design to the manufacturer). Under this allowance, manufacturers could 
potentially discharge some or all of the crankcase emissions to the 
atmosphere, but only if they were able to keep the combined total of 
the crankcase emissions and the other exhaust emissions below the 
applicable exhaust emission standards. They could do this by routing 
the crankcase gases into the exhaust stream downstream of the exhaust 
emission control devices, or by continuing the current practice of 
venting the gases to the engine compartment. But, they could take 
either of these approaches only if they make sure that the combined 
total of the crankcase emissions and the other exhaust emissions are 
below the applicable exhaust emission standards. Also, the manufacturer 
would have to ensure that the crankcase emissions were readily 
measurable during laboratory and in-use field testing.88 
Despite this allowance made at the request of commenters, given the low 
levels of today's final standards we believe that manufacturers will 
have to close the crankcases of all of their

[[Page 5041]]

engines by either routing the crankcase emissions into the engine 
intake or by routing them into the exhaust upstream of the exhaust 
emission control devices.
---------------------------------------------------------------------------

    \88\ During laboratory testing, the crankcase emissions would 
need to be vented in a controlled manner so that they could be 
routed into the dilution tunnel to ensure their proper measurement 
and inclusion in the tested emission level.
---------------------------------------------------------------------------

d. On-Board Diagnostics (OBD)
    The Phase 1 heavy-duty final rule put into place OBD requirements 
for heavy-duty diesel and gasoline engines weighing 14,000 pounds or 
less. (See 65 FR 59896, October 6, 2000.) In that rule, the OBD 
thresholds for malfunction identification are based on multiples of the 
applicable FTP emission standards to which the engine is certified. 
Given the structure of the 2004 FTP emission standards (2005 FTP 
emission standards for gasoline engines), which are combined 
NMHC+NOX standards, the OBD thresholds are based on a 
multiple of the combined FTP standards. However, the structure of the 
2007 FTP standards (2008 for gasoline engines) finalized today is not a 
combined NMHC+NOX standard, but is instead a separate 
NOX and a separate NMHC standard.
    Therefore, today's final rule is revising the existing section of 
the regulations to link OBD thresholds to whatever the appropriate 
standards are whether they are the combined FTP standards or the new 
separate FTP standards finalized today. This is consistent with the 
intent of our OBD requirements since inception--that the OBD thresholds 
be based on the FTP standards to which the vehicle or engine has been 
certified.
    We are also revising the phase-in for the OBD requirements 
finalized in the Phase 1 rule. (See 65 FR 59896.) In that rule, OBD 
systems were required to phase-in on a schedule of 60/80/100 percent 
beginning in the 2005 model year. At least one commenter claimed that 
the OBD phase-in may require multiple changes to OBD systems in 
consecutive years, because OBD systems are tied to the FTP standards to 
which they are certified.89 We have decided, for diesel 
engine OBD systems, to revise the 60/80/100 percent phase-in to 50/50/
100 percent beginning in the 2005 model year. This revised phase-in not 
only alleviates the commenter's concerns, but also makes the OBD phase-
in consistent with the implementation of new emission standards.
---------------------------------------------------------------------------

    \89\ EPA does not believe there would be any legal stability 
concern even if we had kept the OBD phase-in as finalized in the 
Phase 1 rule. However, EPA agrees with the commenter that the phase-
in as finalized in the Phase 1 rule would have complicated 
compliance unnecessarily.
---------------------------------------------------------------------------

    In addition, we have decided, for gasoline engine OBD systems, to 
revise the 60/80/100 percent phase-in to 60/80/80/100 percent beginning 
in the 2005 model year.90 As with the new diesel OBD phase-
in, this gasoline engine OBD phase-in alleviates the commenter's 
concerns, and it also makes the gasoline OBD phase-in more consistent 
with the implementation of new emission standards while maximizing the 
percentage of gasoline engines designed to meet the OBD requirements.
---------------------------------------------------------------------------

    \90\ For those manufacturers choosing compliance Options 1 or 2 
as part of the Phase 1 program, the gasoline engine OBD phase-in 
will become 40/60/80/80/100 percent beginning in model year 2004. 
(See 65 FR 59896, October 6, 2000.)
---------------------------------------------------------------------------

    We also received comments suggesting that we commit to making any 
necessary changes to the OBD requirements based on the outcome of 
future rulemaking efforts by the California Air Resources Board (ARB). 
While we cannot make any such commitment, nor do we believe the 
commenter truly would want us to commit to making changes solely 
because ARB made changes, we do intend to continue our normal practice 
of working closely with ARB and harmonizing our OBD requirements where 
appropriate. Of course, any changes to our OBD requirements could only 
be done via rulemaking.91
---------------------------------------------------------------------------

    \91\ This comment also pertained to gasoline vehicle-based OBD 
systems. Our statements made here pertain to those requirements as 
well but are not repeated below in section III.2.c.
---------------------------------------------------------------------------

2. Heavy-Duty Vehicle Exhaust Emissions Standards 92
---------------------------------------------------------------------------

    \92\ As noted above, vehicle and engine standards apply to all 
vehicles and engines, even if they are alternative fueled vehicles 
and engines.
---------------------------------------------------------------------------

a. FTP Standards
    The emission standards being finalized today for heavy-duty 
gasoline vehicles are summarized in Table III.C-3. We have already 
required that all complete heavy-duty gasoline vehicles, whether for 
transporting passengers or for work, be chassis certified. (See 65 FR 
59896, October 6, 2000.) Current federal regulations do not require 
that complete diesel vehicles over 8,500 pounds be chassis certified; 
instead, our regulations have traditionally required certification of 
their engines. Today's final rule allows, as an option, chassis 
certification of complete heavy-duty diesel vehicles under 14,000 
pounds. This option is discussed in more detail later in this section.
    The Tier 2 final rule created a new vehicle category called 
``medium-duty passenger vehicles.'' 93 These vehicles, both 
gasoline and diesel, are required to meet requirements of the Tier 2 
program, which carries with it a chassis certification requirement. As 
a result, diesel medium-duty passenger vehicles must certify using the 
chassis certification test procedure.94 Today's heavy-duty 
vehicle based standards, or chassis standards, for 2008 and later model 
year heavy-duty gasoline vehicles would apply to the remaining complete 
gasoline vehicles under 14,000 pounds and those complete diesel 
vehicles under 14,000 pounds choosing the chassis certification option; 
these complete vehicles are typically used for commercial, non-
passenger applications. The standards shown in Table III.C-3 are, we 
believe, comparable in stringency to the diesel and gasoline engine 
standards shown in Table III.C-1.
---------------------------------------------------------------------------

    \93\ Medium-duty passenger vehicles are defined as any complete 
vehicle between 8,500 and 10,000 pounds GVWR designed primarily for 
the transportation of persons. The definition specifically excludes 
any vehicle that (1) has a capacity of more than 12 persons total 
or, (2) is designed to accommodate more than 9 persons in seating 
rearward of the driver's seat or, (3) has a cargo box (e.g., pick-up 
box or bed) of six feet or more in interior length. (See the Tier 2 
final rulemaking, 65 FR 6698, February 10, 2000.)
    \94\ The Tier 2 final rule did make a limited allowance for 
engine certification of diesel MDPVS through the 2007 model year. 
The reader should refer to the Tier 2 final rule for details on that 
allowance. (See 65 FR 6750, February 10, 2000.)

[[Page 5042]]



   Table III.C-3.--Full Useful Life Heavy-Duty Vehicle Exhaust Emissions Standards and Phase-Ins for Complete
                                                   Vehicles a
                                                  [Grams/mile]
----------------------------------------------------------------------------------------------------------------
                                                                                  Phase-in by model year b
       Weight range (GVWR)                               Standard (g/mi)  --------------------------------------
                                                                                  2008                2009
----------------------------------------------------------------------------------------------------------------
8,500 to 10,000 lbs                NOX                 0.2                 ..................  .................
                                   NMHC                0.195               ..................  .................
                                   HCHO                0.032               ..................  .................
                                   PM                  0.02                ..................  .................
10,001 to 14,000 lbs               NOX                 0.4                 50%                 100%
                                   NMHC                0.230               ..................  .................
                                   HCHO                0.040               ..................  .................
                                   PM                  0.02                ..................  .................
----------------------------------------------------------------------------------------------------------------
a Does not include medium-duty passenger vehicles.
b Percentages represent percent of sales.

    These NOX standards represent a 78 percent reduction and 
a 60 percent reduction from the standards for 8,500-10,000 pound and 
10,000-14,000 pound vehicles, respectively, finalized for the 2005 
model year. The 2005 model year standards are equivalent to the 
California LEV-I NOX standards of 0.9 g/mi and 1.0 g/mi, 
respectively. The NOX standards shown in Table III.C-3 are 
consistent with the CARB LEV-II NOX standards for low 
emission vehicles (LEVs) in each respective weight range. The 
NOX standard is slightly higher for the 10,000 to 14,000 
pound vehicles for several reasons: these vehicles are tested at a 
heavier payload; they generally have a larger frontal area which 
creates more drag on the engine and requires it to work harder; and 
their in-use duty cycle tends to be more severe. The increased weight 
results in using more fuel per mile than vehicles tested at lighter 
payloads; therefore, they tend to emit slightly more grams of pollutant 
per mile than lighter vehicles.95
---------------------------------------------------------------------------

    \95\ Engine standards, in contrast, are stated in terms of grams 
per unit of work rather than grams per mile. Therefore, engine 
emission standards need not increase with weight because heavier 
engines do not necessarily emit more per unit of work produced. In 
contrast, heavier vehicles, due to their greater mass, tend to emit 
more per mile due to the increased load placed on the engine which 
requires the engine to do more work to travel each mile.
---------------------------------------------------------------------------

    The NMHC standards finalized today represent a 30 percent reduction 
from the 2005 standards for 8500-10,000 and 10,000-14,000 pound 
vehicles. The 2005 model year standards require such vehicles to meet 
NMHC standard levels of 0.28 g/mi and 0.33 g/mi, respectively (equal to 
the California LEV-I nonmethane organic gases (NMOG) standard levels). 
These new NMHC standards are consistent with the CARB LEV-II NMOG 
standards for LEVs in each respective weight class. The NMHC standard 
for 10,000-14,000 pound vehicles is higher than for 8,500-10,000 pound 
vehicles for the same reason as stated above for the higher 
NOX standard for such vehicles.
    The formaldehyde (HCHO) standards shown in Table III.C-3 are not 
the standards we proposed. The standards we are finalizing are 
equivalent to the California LEV-II LEV category standards. This 
approach is being taken to maintain consistency with the approach taken 
on NOX and NMHC standards. Although we are not finalizing 
formaldehyde standards for engine certified systems, because all the 
exhaust emission standards for complete vehicles are consistent with 
the CARB LEV II standards, we believe it is appropriate to maintain the 
formaldehyde standard for gasoline vehicles. Formaldehyde is a 
hazardous air pollutant that is emitted by heavy-duty vehicles and 
other mobile sources, and we are finalizing these formaldehyde 
standards to prevent excessive formaldehyde emissions. These standards 
are especially important for any methanol-fueled vehicles because 
formaldehyde is chemically similar to methanol and is one of the 
primary byproducts of incomplete combustion of methanol. Formaldehyde 
is also emitted by vehicles using petroleum fuels (i.e., gasoline or 
diesel fuel), but to a lesser degree than is typically emitted by 
methanol-fueled vehicles. We expect that petroleum-fueled vehicles able 
to meet the NMHC standards should comply with the formaldehyde 
standards with large compliance margins. Based upon our analysis of the 
similar Tier 2 standards for passenger vehicles, we believe that 
formaldehyde emissions from petroleum-fueled vehicles when complying 
with the new PM, NMHC and NOX standards should be as much as 
90 percent below the standards.96 Thus, to reduce testing 
costs, we are finalizing a provision that permits manufacturers of 
petroleum-fueled vehicles to demonstrate compliance with the 
formaldehyde standards based on engineering analysis. This provision 
requires manufacturers to make a demonstration in their certification 
application that vehicles having similar size and emission control 
technology have been shown to exhibit compliance with the applicable 
formaldehyde standard for their full useful life. This demonstration is 
expected to be similar to that required to demonstrate compliance with 
the Tier 2 formaldehyde standards.
---------------------------------------------------------------------------

    \96\ See the Tier 2 Response to Comments document contained in 
Air Docket A-97-10.
---------------------------------------------------------------------------

    The PM standard is 80 percent lower than the CARB LEV-II LEV 
category PM standard of 0.12 g/mi, which actually applies only to 
diesel vehicles. Note that the PM standard shown in Table III.C-3 
represents not only a stringent PM level, but a new standard for 
federal HDVs where none existed before. Both the California LEV II 
program for heavy-duty diesel vehicles and the federal Tier 2 standards 
for over 8,500 pound gasoline and diesel vehicles designed for 
transporting passengers contain PM standards. The PM standard finalized 
today is consistent with the light-duty Tier 2 bins 7 and 8 level of 
0.02 g/mi.
    The timing for our final gasoline vehicle standards differs from 
what we had proposed. Our proposal had no phase-in, requiring 100 
percent compliance in the 2007 model year. However, since the proposal 
was published, we have set new standards for heavy-duty gasoline 
complete vehicles that take effect in the 2005 model year. Therefore, 
the three year stability requirement of the CAA requires that today's 
new standards not apply until the 2008 model year at the earliest. 
Further, based on comments

[[Page 5043]]

received, we believe that a phase-in should be provided. The phase-in 
will allow manufacturers to implement improved gasoline control 
technologies on their heavy-duty gasoline vehicles in the same 
timeframe as they implement those technologies on their Tier 2 medium-
duty passenger vehicles (MDPV). The MDPVs generally use the same 
engines and emission control systems as do the heavy-duty versions of 
those vehicles. MDPVs must comply with our light-duty Tier 2 program at 
50 percent beginning in the 2008 model year and then 100 percent in the 
2009 model year. As a result of this MDPV phase-in, and the stability 
requirements of the CAA, and because we believe it provides the 
greatest emission control considering costs, we are finalizing a 
gasoline phase-in of 50/100 percent beginning in the 2008 model year. 
Commenters suggested a 40/80/100 percent phase-in beginning in the 2008 
model year, but we believe that a 50/100 percent phase-in allows 
appropriate leadtime and synergy with the MDPV requirements of our Tier 
2 program. It is worth clarifying that this phase-in excludes 
California complete heavy-duty vehicles, which are already required to 
be certified to the California emission standards. It also excludes 
vehicles sold in any state that has adopted California emission 
standards for complete heavy-duty vehicles. It would be inappropriate 
to allow manufacturers to ``double-count'' the vehicles by allowing 
them to count those vehicles both as part of their compliance with this 
phase-in and for compliance with California requirements. We would 
handle heavy-duty engines similarly if California were to adopt 
different emission standards than those being established by this rule.
    We are also finalizing provisions that would encourage 
manufacturers to introduce clean technology earlier than required in 
return for greater flexibility during the later years of our phase-in. 
These optional early incentive provisions are analogous to those 
included in our light-duty Tier 2 rule and are discussed in more detail 
in section III.D.
    As we have done for diesel and gasoline engines, we have revised 
our Averaging, Banking, and Trading program for gasoline vehicles and 
engines to increase flexibility as discussed further in section VI. The 
reader should refer to that section for more details. Note that the 
gasoline vehicle phase-in schedule is the same as but separate from the 
gasoline engine phase-in schedule discussed above. For a discussion of 
why we believe these standards are technologically feasible in the time 
frame required, refer to section III.E below, and for a more detailed 
discussion refer to the RIA contained in the docket.
    We are also allowing complete heavy-duty diesel vehicles under 
14,000 pounds to certify to the heavy-duty vehicle standards. The issue 
of chassis certification of diesels was raised as part of the Phase 1 
rule. At that time, manufacturers expressed little interest in such a 
provision. Because the heavy-duty diesel industry is largely not a 
vertically-integrated industry, in that one company makes the engine 
and another makes the vehicle, chassis certification is not an 
immediately attractive or practical option for diesel engine 
manufacturers. Nonetheless, some manufacturers have begun to express 
interest in diesel chassis certification.97 Also, the 
California Air Resources Board allows complete diesel vehicles to 
chassis certify. We like the idea of diesel chassis certification 
because it allows us to more easily evaluate such vehicles in-use. A 
chassis certified diesel could be acquired easily by EPA and tested in 
its vehicle configuration without the need to remove the engine for an 
engine test.
---------------------------------------------------------------------------

    \97\ See memorandum from Todd Sherwood to Air Docket A-99-06, 
dated December 6, 2000, Item #IV-E-47.
---------------------------------------------------------------------------

    Therefore, while we fully expect that manufacturers will continue 
to certify the engines intended for complete diesel vehicles to the 
engine standards, we will allow the option to chassis certify such 
vehicles. Any chassis-certified complete diesel vehicles must meet the 
applicable Phase 2 emission standards for complete vehicles (i.e., this 
option is not available to diesels certified to the Phase 1 standards). 
In addition, while complete diesel vehicles would count against the 
phase-in requirements for diesel engines, they would not be allowed in 
the Averaging, Banking, and Trading program. Therefore, a chassis-
certified diesel vehicle can neither use nor earn ABT credits, but 
counts as part of the 50 percent phase-in. Further, complete diesels 
choosing the chassis certification option would be required to comply 
with our federal OBD vehicle-based requirements for monitoring of 
exhaust emission control devices, even if choosing the option to 
demonstrate OBD compliance using the California OBD II requirements. 
Lastly, diesel vehicles choosing this option would be certified under 
subpart S which applies to chassis certified complete vehicles, but the 
evaporative emissions provisions of that subpart would not apply for 
diesel vehicles.
b. Supplemental Federal Test Procedure
    We did not propose new supplemental FTP (SFTP) standards for heavy-
duty vehicles. The SFTP standards control off-cycle emissions in a 
manner somewhat analogous to the NTE requirements for engines. We 
believe that the SFTP standards are an important part of our light-duty 
program just as we believe the NTE requirements will be an important 
part of our heavy-duty diesel engine program. Although we did not 
propose SFTP standards for heavy-duty vehicles, we stated an intention 
to do so via a separate rulemaking. We requested comment on such an 
approach, and on appropriate SFTP levels for heavy-duty vehicles along 
with supporting data.
    We received unanimous support from industry commenters to address 
SFTP standards for heavy-duty vehicles in a separate rulemaking. In our 
Tier 2 final rule, we stated that we are currently contemplating a new 
SFTP rulemaking that would consider ``Tier 2'' SFTP standards for all 
Tier 2 vehicles, including MDPVs. California is also interested in 
developing more stringent SFTP standards within the context of their 
LEV II program and we are coordinating with California on these new 
SFTP standards. Given our concern over ``off cycle'' emissions, we 
believe it is appropriate that SFTP standards apply to all chassis 
certified vehicles, heavy-duty and light-duty. As part of the SFTP rule 
being contemplated, we expect to examine not only those issues stated 
in the Tier 2 rule (e.g., the SFTP test cycles and different SFTP 
standards for different vehicles sizes) but also the issue of heavy-
duty SFTP standards.
c. On-Board Diagnostics (OBD)
    The Phase 1 heavy-duty rule finalized OBD requirements for heavy-
duty diesel engines, heavy-duty gasoline engines, and heavy-duty 
complete vehicles weighing 14,000 pounds or less. (See 65 FR 59896, 
October 6, 2000.) In that rulemaking, the final regulatory language 
stated the OBD catalyst thresholds for complete vehicles as multiples 
of a combined NMHC+NOX emission standard. However, the 
emission standards for complete vehicles are not combined, as are the 
engine standards in that final rule. Therefore, the OBD catalyst 
thresholds for complete vehicles were not stated properly in the 
applicable sections of the regulations.
    Today's final rule corrects that regulatory error by revising the 
appropriate regulatory language to link the OBD thresholds to a 
separate, rather than combined, set of FTP exhaust

[[Page 5044]]

emission standards. This is consistent with the Phase 1 heavy-duty 
proposal which correctly linked the proposed OBD thresholds to the 
separate FTP exhaust emission standards. (See 64 FR 58472, October 29, 
1999.) It is also consistent with the preamble to the Phase 1 final 
rule, which stated the catalyst monitor threshold correctly. This 
change makes the OBD thresholds for complete vehicle certifications 
consistent with the structure used since implementation of the federal 
OBD requirements. (See 58 FR 9468, February 19, 1993.)
    Consistent with the changes already discussed in section III.C.1, 
we are also revising the phase-in for complete vehicle OBD requirements 
finalized in the Phase 1 rule. (See 65 FR 59896.) In that rule, OBD 
systems were required to phase-in on a schedule of 60/80/100 percent 
beginning in the 2005 model year. At least one commenter pointed out 
that the OBD phase-in may require multiple changes to OBD systems in 
consecutive years because OBD systems are tied to the FTP standards to 
which they are certified. We have decided, for gasoline vehicle OBD 
systems, to revise the 60/80/100 percent phase-in to 60/80/80/100 
percent beginning in the 2005 model year.98 This revised OBD 
phase-in alleviates the commenter's concerns, and it makes the gasoline 
OBD phase-in more consistent with the implementation of new emission 
standards while maximizing the percentage of gasoline vehicles designed 
to meet the OBD requirements.
---------------------------------------------------------------------------

    \98\ For those manufacturers choosing compliance Options 1 or 2 
as part of the Phase 1 program, the gasoline vehicle OBD phase-in 
will become 40/60/80/80/100 percent beginning in model year 2004. 
(See 65 FR 59896.)
---------------------------------------------------------------------------

3. Heavy-Duty Evaporative Emissions Standards
    We are finalizing new evaporative emission standards for heavy-duty 
vehicles and engines. The new standards are shown in Table III.C-4. 
These standards will apply to heavy-duty gasoline-fueled vehicles and 
engines, and methanol-fueled heavy-duty vehicles and engines. 
Consistent with existing standards, the standard for the two day 
diurnal plus hot soak test sequence would not apply to liquid petroleum 
gas (LPG) fueled and natural gas fueled HDVs.

    Table III.C-4.--New Heavy-Duty Evaporative Emissions Standards a
                            [Grams per test]
------------------------------------------------------------------------
                                                            Supplemental
                                                  3 day         2 day
                   Category                     diurnal +     diurnal +
                                                 hot soak    hot soak b
------------------------------------------------------------------------
8,500-14,000 lbs.............................          1.4          1.75
>14,000 lbs..................................          1.9          2.3
------------------------------------------------------------------------
a To be implemented on the same schedule as the gasoline engine and
  vehicle exhaust emission standards shown in Tables III.C-1 and III.C-
  3. These new standards do not apply to medium-duty passenger vehicles,
  and do not apply to diesel fueled vehicles and engines.
b Does not apply to LPG or natural gas fueled HDVs.

    These new standards represent more than a 50 percent reduction in 
the numerical standards as they exist today. The Phase 1 heavy-duty 
rule made no changes to the numerical value of the standard, but it did 
put into place new evaporative emission test procedures for heavy-duty 
complete gasoline vehicles.99 (See 65 FR 59896, October 6, 
2000.) For establishing evaporative emission levels from complete 
heavy-duty vehicles, the standards shown in Table III.C-4 presume the 
test procedures required in the Phase 1 heavy-duty rule.
---------------------------------------------------------------------------

    \99\ The test procedure changes codify a commonly approved 
waiver allowing heavy-duty gasoline vehicles to use the light-duty 
driving cycle for demonstrating evaporative emission compliance. The 
urban dynamometer driving schedule (UDDS) used for heavy-duty 
vehicles is somewhat shorter than that used for light-duty vehicles, 
both in terms of mileage covered and minutes driven. This results in 
considerably less time for canister purge under the heavy-duty 
procedure than under the light-duty procedure. We recognize this 
discrepancy and have routinely provided waivers under the enhanced 
evaporative program that allow the use of the light-duty procedures 
for heavy-duty certification testing. This is consistent with CARB's 
treatment of equivalent vehicles.
---------------------------------------------------------------------------

    The new standards for 8,500 to 14,000 pound vehicles are consistent 
with the Tier 2 standards for medium-duty passenger vehicles (MDPV). 
MDPVs are of consistent size and have essentially identical evaporative 
emission control systems as the remaining work-oriented HDVs in the 
8,500 to 10,000 pound weight range. Therefore, the evaporative emission 
standards should be equivalent. We are requiring those same standards 
for the 10,000 to 14,000 pound HDVs because, historically, the 
evaporative emission standards have been consistent throughout the 
8,500 to 14,000 pound weight range. We believe that the HDVs in the 
10,000 to 14,000 pound range are essentially equivalent in evaporative 
emission control system design as the lighter HDVs; therefore, 
continuing this historical approach is appropriate.
    We are finalizing slightly higher evaporative emission standards 
for the over 14,000 pound HDVs because of their slightly larger fuel 
tanks and for non-fuel emissions related to larger vehicle sizes. This 
is consistent with past evaporative emission standards. The levels 
chosen for the over 14,000 pound HDVs maintains the same ratio relative 
to the 8,500 to 14,000 pound HDVs as exists with current evaporative 
standards. To clarify, the current standards for the 3 day diurnal test 
are 3 and 4 grams/test for the 8,500 to 14,000 and the over 14,000 
pound categories, respectively. The ratio of 3:4 is maintained for the 
new 2008 standards, 1.4:1.9.
    The new standard levels are slightly higher than the California 
LEV-II standard levels. The California standard levels are 1.0 and 1.25 
for the 3-day and the 2-day tests, respectively. However, federal 
vehicles are certified using the higher-volatility federal test 
fuel.100 Arguably, the federal and California evaporative 
emission standards are equivalent in stringency despite the difference 
in standard levels. We believe that our standards are appropriate for 
federal heavy-duty vehicles.
---------------------------------------------------------------------------

    \100\ The federal test fuel specification for fuel volatility, 
the Reid Vapor Pressure, is 8.7 to 9.2 psi. The California test fuel 
specification is 6.7 to 7.0 psi.
---------------------------------------------------------------------------

    We are requiring that the new evaporative emission standards be 
implemented on the same schedule as the gasoline engine and vehicle 
exhaust standards shown in Tables III.C-1 and III.C-3. This will allow 
manufacturers to plan any needed changes to new vehicles at the same 
time, although it is not necessary that the exhaust and evaporative 
standards be phased-in on the same vehicles and engines. Also, we are 
finalizing the revised durability provisions finalized in the Tier 2 
rulemaking, which require durability demonstration using fuel 
containing at least 10 percent alcohol. Alcohol can break down the 
materials used in evaporative emission control systems. Therefore, a 
worst case durability demonstration would include a worst case alcohol 
level in the fuel (10 percent) because in some areas of the country 
there is widespread use of alcohol fuels.

D. Incentives for Early Introduction of Clean Engines and Vehicles

    In our proposal, we requested comment on alternative phase-in 
approaches that could provide attractive implementation options to

[[Page 5045]]

manufacturers without compromising air quality. We requested comment on 
a ``declining standard'' approach and a ``cumulative phase-in'' 
approach. We received only limited comment on those approaches with no 
commenters expressing particularly strong support for them. We did 
receive numerous comments suggesting that we provide some form of 
incentive for manufacturers to introduce clean technology engines 
earlier than required by the base program. We are finalizing the 
approach discussed here as an incentive for manufacturers to introduce 
clean diesel engines earlier than the 2007 model year (or the 2008 
model year for gasoline engines and vehicles).
    In our Tier 2 rule, we stated our belief that providing inducements 
to manufacturers to certify vehicles early to very low levels is 
appropriate. We believe that such inducements may help pave the way for 
greater and/or more cost effective emission reductions from future 
vehicles. We believe the program discussed here provides a strong 
incentive for manufacturers to maximize their development and 
introduction of the best available vehicle and engine emission control 
technology. This, in turn, provides a stepping stone to the broader 
introduction of this technology soon thereafter. Early production of 
cleaner vehicles enhances the early benefits of our program. If a 
manufacturer can be induced to certify to the new standards by the 
promise of reasonable extra credits, the benefits of that decision to 
the program may last for many years.
    The incentive program finalized today is analogous to the 
provisions set forth in the final Tier 2 rule. We are finalizing 
provisions that permit manufacturers to take credit for diesel engines 
certified to this rule's final standards prior to the 2007 model year 
(prior to the 2008 model year for gasoline engines or vehicles) in 
exchange for making fewer diesel engines certified to these standards 
in or after the 2007 model year (2008 for gasoline engines or 
vehicles). In other words, a clean engine sold earlier than required 
displaces the requirement to sell a similar engine later. Note that the 
emission standards must be met to earn the early introduction credit. 
That is, emission credits earned under averaging, banking, and trading 
cannot be used to demonstrate compliance. Therefore, the early 
introduction engine credit is an alternative to the ABT program in that 
any early engines or vehicles can earn either the engine credit or the 
ABT emission credit, but not both. The purpose of the incentive is to 
encourage introduction of clean technology engines earlier than 
required in exchange for added flexibility during the phase-in years.
    Any early engine credits earned for a diesel-fueled engine would, 
of course, be predicated on the assurance by the manufacturer that the 
engine would indeed be fueled with low sulfur diesel fuel in the 
marketplace. We expect this would occur through selling such engines 
into fleet applications, such as city buses, school buses, or any such 
well-managed centrally-fueled fleet. For this reason, we believe that 
any engines sold within this early incentive program would be sold 
primarily in urban areas where more centrally-fueled fleets exist. 
Because of the difficulty associated with low sulfur diesel fuel 
availability prior to mid-2006, we believe it is necessary and 
appropriate to provide a greater incentive for early introduction of 
clean diesel technology. Therefore, we will count one early diesel 
engine as 1.5 diesel engines later. This extra early credit for diesel 
engines means that fewer clean diesel engines than otherwise would be 
required may enter the market during the years 2007 and later. But, 
more importantly, it means that emission reductions would be realized 
earlier than under our base program. We believe that providing 
incentives for early emission reductions is a worthwhile goal for this 
program. Therefore, we are finalizing these provisions for 
manufacturers willing to make the early investment in cleaner engines. 
For gasoline engines and vehicles, the early engine credit will be a 
one-for-one credit because the gasoline needed by the engine or vehicle 
will be readily available.
    We are providing this early introduction credit to diesel engines 
that meet all of today's final standards (0.20 g/bhp-hr NOX, 
0.14 g/bhp-hr NMHC, and 0.01 g/bhp-hr PM). We are also providing this 
early introduction credit to diesel engines that pull-ahead compliance 
with only the 0.01 g/bhp-hr PM standard. However, a PM-only early 
engine can offset only PM compliant engines during the phase-in years, 
not NOX, NMHC, and PM compliant engines.
    An important aspect of the early incentive provision is that it 
must be done on an engine or vehicle count basis. That is, a diesel 
engine meeting new standards early counts as 1.5 such diesel engines 
later and a gasoline engine or vehicle early counts as one gasoline 
engine or vehicle later. This contrasts with a provision done on an 
engine percentage basis which would count one percent of diesel engines 
early as 1.5 percent of diesel engines later. Basing the incentive on 
an engine count will alleviate any possible influence of fluctuations 
in engine and vehicle sales in different model years.
    Another important aspect of this program is that it is limited to 
engines sold prior to the 2007 model year (2008 for gasoline). In other 
words, diesel engines sold in the 2007 through 2009 model years that 
exceed the required 50 percent phase-in will not be considered 
``early'' introduction engines and will, therefore, receive no early 
introduction credit. The same is true for gasoline engines and vehicles 
sold in the 2008 model year. However, such engines and vehicles will 
still be able to generate ABT credits. Note that early gasoline 
vehicles can count for later gasoline vehicles, and early gasoline 
engines can count for later gasoline engines, but early gasoline 
vehicles cannot be traded for later gasoline engines and vice versa.
    Table III.D-1 shows an example for a diesel engine manufacturer and 
how it might use this incentive provision on an assumed fleet of 100 
engine sales growing at one percent per year beginning in the 2004 
model year.

                  Table III.D-1.--Example Engine Introduction Under Our Early Incentive Program
----------------------------------------------------------------------------------------------------------------
                                 2004        2005        2006        2007        2008        2009        2010
----------------------------------------------------------------------------------------------------------------
Total Sales                   100         101         102         103         104         105         106
----------------------------------------------------------------------------------------------------------------
Clean Engines under           0           0           0           52          52          53          106
Base program                  ..........  ..........  ..........  ..........  ..........  ..........  ..........
----------------------------------------------------------------------------------------------------------------
Clean Engines under           4           4           4           46          46          47          106
Incentive Program             ..........  ..........  ..........  ..........  ..........  ..........  ..........
----------------------------------------------------------------------------------------------------------------


[[Page 5046]]

    The four engines sold early in each of model years 2004 through 
2006 generate a total credit of 18 engines (4 x 3 x 1.5=18). This 
allows the manufacturer to reduce its compliant engine count in each of 
model years 2007 through 2009 by six engines (18/3=6). This helps the 
manufacturer by reducing total costs through requiring fewer total 
engines at the low-emitting, clean engine level. But, more importantly, 
it introduces clean technology engines early and, by 2010 in this 
example, generates from four to six years of emission reductions that 
otherwise would not have occurred.
    As further incentive to introduce clean engines and vehicles early, 
we are also finalizing a provision that would give manufacturers an 
early introduction credit equal to two engines during the phase-in 
years. This ``Blue Sky'' incentive would apply for diesel engines 
meeting one-half of today's final NOX standard while also 
meeting the NMHC and PM standards. For gasoline engines, the same early 
introduction double engine credit would be available to engines sold 
prior to 2008 and meeting one-half the NOX standard while 
also meeting the NMHC, PM, and evaporative emission standards. For 
gasoline vehicles, the double engine credit would be available to those 
vehicles certified early to the California SULEV levels and today's PM 
and evaporative emission standards.101 Due to the extremely 
low emission levels to which these Blue Sky series engines and vehicles 
would need to certify, we believe that the double engine count credit 
is appropriate. Table III.D-2 shows the emission levels that would be 
required prior to the 2007 model year for diesel engines and the 2008 
model year for gasoline vehicles and engines to earn any early 
introduction engine credits.
---------------------------------------------------------------------------

    \101\ The California SULEV levels are, for 8,500 to 10,000 pound 
vehicles, 0.1 g/mi NOX, 0.100 g/mi NMOG, 0.008 g/mi HCMO, 
and 0.06 g/mi PM; and for 10,000 to 14,000 pound vehicles, 0.2 g/mi 
NOX, 0.117 g/mi NMOG, 0.010 g/mi HCHO, and 0.06 g/mi PM. 
With the exception of the PM standards, these emission levels are 
half or roughly half of this rule's final gasoline vehicle 
standards.

     Table III.D-2.--Emission Levels and Credits Available for Early
                          Introduction Engines
------------------------------------------------------------------------
                                                           Early engine
            Category                   Must meet a           credit b
------------------------------------------------------------------------
Early Diesel PM-only c.........  Phase 2 PM &...........        1.5-to-1
                                 Phase 1 NOX + NMHC.....
Early Diesel Engine c..........  All Phase 2 Standards..        1.5-to-1
Early Gasoline Engine or         Phase 2 Exhaust                  1-to-1
 Vehicle--Exhaust.                Standards.
Early Gasoline Engine or         Phase 2 Evaporative              1-to-1
 Vehicle--Evap.                   Standards.
Blue Sky Series Diesel c or      0.10 g/bhp-hr NOX & All          2-to-1
 Gasoline Engine.                 other Phase 2
                                  Standardsd.
Blue Sky Series Gasoline.......  0.02 g/mi PM &                   2-to-1
                                  California SULEV Level
                                  Standardsd.
Vehicle
------------------------------------------------------------------------
a Phase 1 refers to standards required by 65 FR 59896, October 6, 2000;
  Phase 2 refers to today's final standards.
b  Engine count credits must be earned prior to the phase-in years of
  2007 for diesel and 2008 for gasoline.
c Early diesel engines must also meet the Phase 2 crankcase emissions
  requirements.
d For gasoline engines and vehicles, these must also meet the Phase 2
  evaporative emission standards.

    Alternative fueled vehicles and engines can also play a significant 
role in this incentive program. Any alternative fueled diesel-cycle 
engine certified to today's final standards prior to the 2007 model 
year can generate a 1.5 diesel-cycle engine count credit during the 
diesel phase-in years. Likewise, any alternative fueled Otto-cycle 
engine certified to today's final standards prior to the 2008 model 
year can generate one Otto-cycle engine count credit. Many commenters 
suggested that EPA should do more than was put forward in our proposal 
to encourage the introduction of alternative fuel technologies. To the 
extent that alternative fueled vehicles and engines are cleaner than 
diesels and gasolines, they may have an advantage within today's 
program. We believe that this program and its structure provides 
significant incentives for manufacturers to introduce alternative 
fueled vehicles and engines.
    One final aspect of the incentive program is its interaction with 
our Tier 2 program. The Tier 2 final rule allows some MDPVs to be 
equipped with engine-certified diesel engines through the 2007 model 
year. Any such engines are required to comply with the diesel engine 
standards that apply during the given model year. Given that they are 
certified as heavy-duty diesel engines, any such engines that meet 
today's final diesel standards prior to the 2007 model year would be 
allowed within today's incentive program provided they in no way 
generate any emission or engine count credits within the Tier 2 
program. Further, any MDPVs, whether gasoline or diesel, certified on a 
chassis dynamometer and being counted in any way as part of the Tier 2 
program, cannot be used as part of today's incentive program because 
they are not considered heavy-duty vehicles.

E. Feasibility of the New Engine and Vehicle Standards

    For more detail on the information and analyses supporting our 
assessment of the technological feasibility of today's standards, 
please refer to the Final RIA in the docket for this rule. The 
following discussion summarizes the more detailed discussion found in 
the Final RIA and in the Summary and Analysis of Comments document.
1. Feasibility of Stringent Standards for Heavy-Duty Diesel
    The designers and manufacturers of diesel engines have made 
substantial progress over the last 20 years reducing NOX 
emissions by 60 percent and PM emissions by almost 90 percent through 
better engine design. We believe that, in response to our Phase 1 
heavy-duty rule, industry will have implemented all promising engine-
based emission reduction technologies in order to meet the 2.5 g/bhp-hr 
NOX+NMHC standard and the 0.1 g/bhp-hr PM standard. To get 
the substantial PM and NOX reductions from diesel engines 
needed to solve the air quality problems identified in section II, we 
believe a new technology solution will be required. That solution is 
the application of high efficiency exhaust emission control 
technologies (catalysts) to diesel engines, analogous to the 
application of catalyst technologies to passenger cars in the 1970s. 
These high efficiency catalyst technologies, enabled by the use of 
diesel fuel with sulfur content at or below 15 ppm, can reduce 
NOX and PM emissions by more than 90 percent. This dramatic 
reduction in emissions will

[[Page 5047]]

enable diesel powered vehicles to reach emission levels well below 
today's gasoline emission levels. As detailed in the sections below, 
these technologies are rapidly being developed and will be available 
for application to diesel powered vehicles by, or even before, the 2007 
model year provided the low sulfur diesel fuel required today is widely 
available.
a. Meeting the PM Standard
    Diesel PM consists of three primary constituents: Unburned carbon 
particles (soot), which make up the largest portion of the total PM; 
the soluble organic fraction (SOF), which consists of unburned 
hydrocarbons that have condensed into liquid droplets or have condensed 
onto unburned carbon particles; and sulfates, which result from 
oxidation of fuel and oil derived sulfur in the engine's exhaust. 
Several exhaust emission control devices have been developed to control 
harmful diesel PM constituents--the diesel oxidation catalyst (DOC), 
and the many forms of diesel particulate filters, sometimes called PM 
traps. DOCs have been shown to be durable in use, but they effectively 
control only the SOF portion of the total PM which, on a modern diesel 
engine constitutes only 10 to 30 percent of the total PM. Therefore, 
the DOC on its own would only offer a modest reduction in PM emissions, 
and would not be able to meet the PM standard set here.
    Diesel particulate filters were first investigated some twenty 
years ago as a means to capture solid particles in diesel exhaust. A 
variety of approaches to this technology have been developed most of 
which provide excellent mechanical filtration of the solid particles 
that make up the bulk of diesel PM (60 to 80 percent). The collected 
PM, mostly carbon particles, must then be ``burned off'' of the filter 
before the filter becomes plugged. This burning off of collected PM 
(oxidation of the stored PM, releasing CO2) is referred to 
as ``regeneration,'' and can occur either:
     On a periodic basis by using base metal catalysts 
(including fuel-borne base metal catalysts) or an active regeneration 
system such as an electrical heater, a fuel burner, or a microwave 
heater; or,
     On a continuous basis by using precious metal catalysts.
    Diesel particulate traps that regenerate on a periodic basis 
(referred to here as either uncatalyzed or base metal catalytic PM 
traps) demonstrated high PM trapping efficiencies many years ago, but 
the level of the applicable PM standard was such that it could be met 
through less costly ``in-cylinder'' control techniques. Un-catalyzed 
diesel particulate filters will not be able to meet the 0.01 g/bhp-hr 
PM standard finalized today as they are only moderately effective at 
controlling the SOF fraction of the particulate. In addition, they 
require active regeneration technology which must be engaged frequently 
making the systems expensive to operate (increasing fuel consumption) 
and less reliable.
    We believe the kind of PM trap that would be able to meet the PM 
standard in a reliable, durable, cost effective manner, and the type of 
trap that will prove to the be the industry's technology of choice, is 
one capable of regenerating on an essentially continuous basis. In 
addition these PM traps will be able to achieve very low PM emissions 
because:
     They are highly efficient at controlling the solid carbon 
portion of PM;
     Unlike uncatalyzed filters, they are highly efficient at 
oxidizing the SOF of diesel PM;
     They employ precious metals to produce conditions that 
reduce the temperature at which regeneration occurs, thereby allowing 
for passive regeneration under normal operating conditions typical of a 
diesel engine; 102
---------------------------------------------------------------------------

    \102\ For PM trap regeneration without precious metals, exhaust 
metals, exhaust temperatures in excess of 650 deg.C must be 
obtained. At such high temperatures, carbon will burn (oxidize to 
CO2) provided sufficient oxygen is present. Although the 
largest heavy-duty diesels may achieve exhaust temperatures of 
650 deg.C under some operating conditions, smaller diesel engines, 
particularly light-duty and light heavy-duty diesel engines, will 
rarely achieve such high temperatures. For example, exhaust 
temperatures on the HDE Federal Test Procedure cycle typically range 
from 100 deg.C to 450 deg.C. Precious metal catalyzed traps use 
platinum to oxidize NO in the exhaust to No2, which is 
capable of oxidizing carbon at temperatures as low as 250 deg.C to 
300 deg.C.
---------------------------------------------------------------------------

     Because they regenerate continuously, they have lower 
average backpressure thereby reducing potential fuel economy impacts; 
and,
     Because of their passive regeneration characteristics, 
they need no extra burners or heaters like what would be required by an 
active regeneration system, thereby reducing potential failures and 
fuel economy impacts.
    These catalyzed PM traps are able to provide in excess of 90 
percent control of diesel PM when operated on diesel fuel with sulfur 
levels at or below 15 ppm. However, as discussed in detail in the RIA, 
the catalyzed PM trap cannot regenerate properly with current fuel 
sulfur levels, as such sulfur levels poison the catalytic function of 
the PM trap inhibiting the necessary NO to NO2 reaction to 
the point of stopping trap regeneration.103 Also, because 
SO2 is so readily oxidized to SO3, the 0.01 g/
bhp-hr PM standard cannot be achieved with fuel sulfur levels above 15 
ppm because of the resultant increase in sulfate PM emissions 
(``sulfate make'').104
---------------------------------------------------------------------------

    \103\ Cooper and Thoss, Johnson Matthey, SAE 890404.
    \104\ See the RIA for more detail on the relationship of fuel 
sulfur to sulfate make.
---------------------------------------------------------------------------

    More than one exhaust emission control manufacturer is known to 
have or be developing these precious metal catalyzed, passively 
regenerating PM traps and to have them in broad field test programs in 
areas where low sulfur diesel fuel is currently available. In field 
trials since 1994, they have demonstrated highly efficient PM control 
and good durability with some units accumulating in excess of 360,000 
miles of field use.105 The experience gained in these field 
tests also helps to clarify the need for low sulfur diesel fuel. In 
Sweden, where below 10 ppm diesel fuel sulfur is readily available, 
more than 3,000 catalyzed diesel particulate filters have been 
introduced into retrofit applications without a single failure. These 
retrofit applications include intercity trains, airport buses, mail 
trucks, city buses and garbage trucks.106 The field 
experience in areas where sulfur is capped at 50 ppm has been less 
definitive. In regions without extended periods of cold ambient 
conditions, such as the United Kingdom, field tests on 50 ppm sulfur 
cap fuel have been positive, matching the durability at 10 ppm, but 
would be unable to meet a 0.01 g/bhp-hr PM standard due to a 
substantial increase in sulfate PM. However, field tests on 50 ppm 
sulfur fuel in Finland where colder winter conditions are often 
encountered (similar to northern parts of the United States) have 
experienced a failure rate of 10 percent, due to trap plugging. This 10 
percent failure rate has been attributed to insufficient trap 
regeneration due to fuel sulfur in combination with low ambient 
temperatures.107 Other possible reasons for the high failure 
rate in Finland when contrasted with the Swedish experience appear to 
be unlikely. The Finnish and Swedish fleets were substantially similar, 
with both fleets consisting of transit buses powered by Volvo and 
Scania engines in the 10 to 11 liter range. Further, the buses were 
operated in city areas and none of the vehicles were operated in 
northern extremes such as north of the

[[Page 5048]]

Arctic Circle.108 Given that the fleets in Sweden and 
Finland were substantially similar, and given that ambient conditions 
in Sweden are expected to be similar to those in Finland, we believe 
that the increased failure rates noted here are due to the higher fuel 
sulfur level in a 50 ppm cap fuel versus a 10 ppm cap 
fuel.109 Testing on an even higher fuel sulfur level of 200 
ppm was conducted in Denmark on a fleet of 9 vehicles. In less than six 
months all of the vehicles in the Danish fleet had failed due to trap 
plugging.110 We believe that this real world testing clearly 
indicates that increasing diesel fuel sulfur levels limit trap 
regeneration, leading to plugging of the PM trap even at fuel sulfur 
levels as low as 50 ppm.
---------------------------------------------------------------------------

    \105\ Allansson, et al. SAE 2000-01-0480.
    \106\ Allansson, et al. SAE 2000-01-0480.
    \107\ Letter from Dr. Barry Cooper to Don Kopinski, US EPA, Air 
Docket A-99-06.
    \108\ Telephone conversation between Dr. Barry Cooper, Johnson 
Matthey, and Todd Sherwood, EPA, Air Docket A-99-06.
    \109\ The average temperatrue in Helsinki, Finland, for the 
month of January is 21 deg.F. The average temperature in Stockholm, 
Sweden, for the month of January is 26 deg.F. The average 
temperature at the University of Michigan in Ann Arbor, Michigan, 
for the month of January is 24 deg.F. The temperature reported here 
are from www.worldclimate.com based upon the Global Historical 
Climatology Network (GHCN) produced jointly by the National Climatic 
Data Center and Carbon Dioxide Information Analysis Center at Oak 
Ridge National Laboratory (ORNL).
    \110\ Letter from Dr. Barry Cooper to Don Kopinski US EPA, Air 
Docket A-99-06.
---------------------------------------------------------------------------

    From these results, we can further conclude that lighter 
applications (such as large pick-up trucks and other light heavy-duty 
applications), having lower exhaust temperatures than heavier 
applications, may experience similar failure rates even in more 
temperate climates and would, therefore, need lower sulfur fuel even in 
the United Kingdom. These results are understood to be due to the 
effect of sulfur on the trap's ability to create sufficient 
NO2 to carry out proper trap regeneration. Without the 
NO2, the trap continues to trap the PM at high efficiency, 
but it is unable to oxidize, or regenerate, the trapped PM. The 
possible result is a plugged trap. This vulnerability of the catalyzed 
diesel particulate filter due to sulfur in the fuel and the 
consequences of trap plugging are discussed fully in section III.F and 
the RIA.
    Several commenters raised concerns with our use of the extensive 
fleet experience in Europe, to draw conclusions about the necessary 
sulfur reductions required in order to ensure PM trap durability. Their 
concerns focused generally around the fact that these fleets were made 
up of retrofit applications, and that the nature of the fleet operation 
did not represent a controlled experiment (ideally all things would 
have been equal except for the fuel sulfur level). While we acknowledge 
these limitations in the data, we believe they still provide reasonable 
evidence of the need for low sulfur diesel fuel. The diversity of 
applications, climates, fuel properties, NOX emission 
levels, and sulfur levels help to show the relative robustness of the 
technology. Further, we believe the PM trap manufacturer's analysis of 
the failure mode (i.e., that cold ambient conditions coupled with 
diminished NO to NO2 conversion due to sulfur led to the 
failures that were experienced) is the most likely explanation of the 
observed phenomena. Sulfur in diesel fuel is known to inhibit the 
oxidation of NO to NO2 (as described in section III.F) 
leading to reduced ability to regenerate the PM filter, especially 
under low ambient conditions. For our detailed response to comments 
surrounding catalyzed diesel particulate filter durability refer to the 
RTC document.
    Several progressive refineries have begun to produce diesel fuel 
with sulfur content less than 15 ppm for limited markets in the United 
States. The availability of this low sulfur diesel fuel makes it 
possible to introduce diesel particulate filters into these limited 
markets today. International Truck and Engine Corporation 
(``International'') has announced its intent to commercialize its Green 
Diesel Engine TechnologyTM in 2001 coupled with less than 15 
ppm sulfur fuel to achieve our proposed MY 2007 NMHC and PM emissions 
standards six years in advance of the requirement. International's 
ability to bring a catalyzed diesel particulate filter technology to 
commercialization in such a short period highlights the advanced state 
of this technology.111
---------------------------------------------------------------------------

    \111\ International Truck and Engine Corporation's comments on 
the proposed 2007 heavy duty vehicle standards, Air Docket A-99-06, 
page 2.
---------------------------------------------------------------------------

    Modern catalyzed PM traps have been shown to be very effective at 
reducing PM mass. In addition, recent data show that they are also very 
effective at reducing the overall number of emitted particles when 
operated on low sulfur fuel. Hawker, et. al., found that a modern 
catalyzed PM trap reduced particle count by over 95 percent, including 
some of the smallest measurable particles (50 nm), at most of the 
tested conditions. The lowest observed efficiency in reducing particle 
number was 86 percent. No generation of particles by the PM trap was 
observed under any tested conditions.112 Kittelson, et al., 
confirmed that ultrafine particles can be reduced by a factor of ten by 
oxidizing volatile organics, and by an additional factor of ten by 
reducing sulfur in the fuel. Catalyzed PM traps efficiently oxidize 
nearly all of the volatile organic PM precursors, and elimination of as 
much fuel sulfur as possible will substantially reduce the number of 
ultrafine PM emitted from diesel engines. The combination of catalyzed 
PM traps with low sulfur fuel is expected to result in very large 
reductions in both PM mass and the number of ultrafine particles.
---------------------------------------------------------------------------

    \112\ Hawker, P., et al., Effect of a Continuously Regenerating 
Diesel Particulate Filter on Non-Regulated Emissions and Particle 
Size Distribution, SAE 980189.
---------------------------------------------------------------------------

    The data currently available show that catalyzed particulate 
filters can provide significant reductions in PM. Catalyzed particulate 
filters, in conjunction with low sulfur fuel, have been shown to be 
more than 90 percent efficient over the FTP and at most SET 
modes.113 Testing completed as part of the Diesel Emission 
Control Sulfur Effects (DECSE) program has demonstrated that a heavy 
duty diesel engine can achieve less than 0.01 g/bhp-hr PM emissions 
over the supplemental emission test when equipped with a catalyzed 
diesel particulate filter and operated on diesel fuel with sulfur 
content less than 15 ppm.114 Further testing at NVFEL has 
demonstrated that FTP PM emissions can likewise be controlled below 
0.01 g/bhp-hr provided less than 15 ppm sulfur diesel fuel is used with 
a catalyzed PM trap.115 Based upon these test results, 
extensive field experience throughout the world and International Truck 
and Engine Corporation's commitment to produce vehicles with this 
technology in 2001, we conclude that the 0.01 g/bhp-hr FTP PM standard 
is feasible and that it represents the lowest emission level possible 
having given consideration to cost, energy and safety factors.
---------------------------------------------------------------------------

    \113\ Demonstration of Advanced Emission Control Technologies 
Enabling Diesel-Powered Heavy-Duty Engines to Achieve Low Emission 
Levels, Manufacturers of Emissions Controls Association, June 1999.
    \114\ Testing for the DECSE program was conducted on 3 ppm and 
30 ppm diesel fuel. A straight-line fit to the results between 3 ppm 
and 30 ppm shows that a 15 ppm cap fuel would have emissions less 
than 0.01 g/bhp-hr. Diesel Emission Control Sulfur Effects (DECSE) 
Program, Phase I Interim Data Report No. 4: Diesel Particulate 
Filters--Final Report, January 2000.
    \115\ Memorandum from Charles Schenk, EPA, to Air Docket A-99-
06, ``Summary of EPA PM Efficiency Data,'' May 8, 2000.
---------------------------------------------------------------------------

    With regard to the NTE PM requirements, there is the potential for 
sulfate production during some operating modes covered by the NTE which 
would likely exceed the FTP PM standard. However, the NTE PM standard 
is equal to 1.5  x  FTP standard. Even though the FTP standard of 0.01 
g/bhp-hr PM is very low, the small additional head room provided by a

[[Page 5049]]

NTE multiplier of 1.5 will be sufficient to enable PM trap equipped 
HDDEs to meet the NTE provisions, even when operated on 15 ppm sulfur 
fuel. This is supported by data generated as part of the DECSE test 
program, as well as data generated at our own laboratory, as discussed 
in greater detail in the RIA.116 As discussed in the RIA, 
the expanded ambient condition requirements of the NTE test procedure 
will have little effect on the PM reduction capabilities of a PM trap. 
The SET PM requirements have also been demonstrated in our laboratory 
and are supported by the DECSE test program. A detailed discussion is 
contained in the RIA. Based on this information and assessment, we 
conclude that the PM supplemental requirements will be feasible in the 
2007 time frame.
---------------------------------------------------------------------------

    \116\ Diesel Emission Control Sulfur Effects (DECSE) Program--
Phase II Interim Data Report No. 4, Diesel Particulate Filters--
Final Report, January 2000, Table C1, www.ott.doe.gov/decse.
---------------------------------------------------------------------------

b. Meeting the NOX Standard
    NOX emissions from gasoline-powered vehicles are 
controlled to extremely low levels through the use of the three-way 
catalyst technology first introduced in the 1970s. Today, an 
advancement upon this well-developed three-way catalyst technology, the 
NOX adsorber, has shown that it too can make possible 
extremely low NOX emissions from lean-burn engines such as 
diesel engines. The potential of the NOX adsorber catalyst 
is limited only by its need for careful integration with the total 
vehicle system (as was done for three-way catalyst equipped passenger 
cars in the 1980s and 1990s) and by poisoning of the catalyst from 
sulfur in the fuel. Just as the Tier 2 rulemaking enables advanced 
three-way catalyst equipped vehicles to meet ultra low NOX 
emission levels through the use of low sulfur gasoline, today's 
rulemaking will enable NOX adsorbers through substantial 
reductions in diesel fuel sulfur levels. The NOX adsorber 
has already been commercially introduced in a number of stationary and 
mobile source applications.

NOX Adsorbers in Power Generation

    NOX adsorber catalysts were first introduced in the 
power generation market less than five years ago. Since then, 
NOX adsorber systems in stationary source applications have 
enjoyed considerable success. In 1997, the South Coast Air Quality 
Management District of California determined that a NOX 
adsorber system provided the ``Best Available Control Technology'' 
NOX limit for gas turbine power systems.117 
Average NOX control for these power generation facilities is 
in excess of 92 percent.118 A NOX adsorber 
catalyst applied to a natural gas fired powerplant has demonstrated 
better than 99 percent reliability for more than 21,000 hours of 
operation while controlling NOX by more than 90 
percent.119
---------------------------------------------------------------------------

    \117\ Letter from Barry Wallerstein, Acting Executive Officer, 
SCAQMD, to Robert Danziger, Goal Line Environmental Technologies, 
dated December 8, 1997, www.glet.com.
    \118\ Reyes and Cutshaw, SCONOX Catalytic Absorption 
System, December 8, 1998, www.glet.com.
    \119\ Danziger, R. et al. 21,000 Hour Performance Report on 
SCONOX, 15 September 2000, Air Docket A-99-06.
---------------------------------------------------------------------------

NOX Adsorbers in Lean-Burn Gasoline Vehicles

    The NOX adsorber's ability to control NOX 
under oxygen rich (fuel lean) operating conditions has led the industry 
to begin applying NOX adsorber technology to lean-burn 
engines in mobile source applications. NOX adsorber 
catalysts have been developed and are now in production for lean-burn 
gasoline vehicles in Japan, including several vehicle models sold by 
Toyota Motor Corporation.120 The 2000 model year saw the 
first U.S. application of this technology with the introduction of the 
Honda Insight, certified to the California LEV-I ULEV category 
standard. These lean burn gasoline applications are of particular 
interest because they are similar to diesel vehicle applications in 
terms of NOX storage under lean exhaust conditions and the 
need for periodic NOX regeneration under transient driving 
conditions. The substantial experience already gained and continuing to 
be gained from NOX adsorber use in lean-burn gasoline 
vehicles provides a firm basis from which diesel NOX 
adsorber development is proceeding.
---------------------------------------------------------------------------

    \120\ Toyota requires that their lean burn gasoline engines 
equipped with NOX adsorbers are fueled on premium 
gasoline in Japan, which has an average sulfur content of 6 ppm. 
(See Item IV-E-31 in Air Docket A-99-06.)
---------------------------------------------------------------------------

NOX Adsorbers in Light-Duty Diesel Vehicles

    This rapid development pace of the NOX adsorber 
technology is not limited to gasoline applications but includes markets 
where low sulfur diesel fuel is already available or has been mandated 
to coincide with future emission standards. In Japan, Toyota Motor 
Corporation has recently announced that it will begin introducing 
vehicles using its Diesel Particulate-- NOX Reduction (DPNR) 
system in 2003. This system uses a NOX adsorber catalyst 
applied on the surface of a diesel particulate filter, providing 
greater than 80 percent reductions in both PM and NOX. 
Toyota notes however, that DPNR requires fuel with low sulfur content 
in order to maintain high efficiency for a long duration.121 
In Europe, both Daimler Chrysler and Volkswagen, driven by a need to 
meet stringent Euro IV emission standards, have published results 
showing how they would apply the NOX adsorber technology to 
their diesel-powered passenger cars. Volkswagen reports that it has 
already demonstrated NOX emissions of 0.137 g/km (0.22 g/
mi), a 71 percent reduction, on a diesel powered Passat passenger car 
equipped with a NOX adsorber catalyst.122
---------------------------------------------------------------------------

    \121\ Revolutionary Diesel Aftertreatment System Simultaneously 
Reduces Diesel Particulate Matter and Nitrogen Oxides, Toyota Motor 
Corporation press release, July 25, 2000, contained in Air Docket A-
99-06.
    \122\ Pott, E., et al., ``Potential of NOX-Trap 
Catalyst Application for DI-Diesel Engines,'' Air Docket A-99-06.
---------------------------------------------------------------------------

US DOE Research Programs

    The U.S. Department of Energy (DOE) has funded several test 
programs at national laboratories and in partnership with industry to 
investigate NOX adsorber technology. At Oak Ridge National 
Laboratory, DOE researchers have shown that a NOX adsorber 
and a laboratory regeneration system can reduce NOX by more 
than 90 percent when used on a diesel powered Mercedes A-class 
passenger car. Following 600 miles of driving with 150 ppm sulfur fuel, 
the system performance degraded considerably.123 While the 
system was not production ready, it does demonstrate that very high 
efficiencies are achievable with advanced emission control systems 
operating on low sulfur fuel.124 With additional system 
development over the next several years we are confident that the 
remaining design challenges such as long-term durability will be 
solved.
---------------------------------------------------------------------------

    \123\ Diesel Vehicle Emission Control Sulfur Effects Project at 
Oak Ridge National Laboratory, Phase 1 Overview. Pete Devlin, DOE 
Office of Transportation Technologies, March 29, 2000, Air Docket A-
99-06.
    \124\ Diesel Emission Control Sulfur Effects (DECSE) Program 
Phase II Summary Report: NOX Adsorber Catalysts, October 
2000, Air Docket A-99-06.
---------------------------------------------------------------------------

EPA NVFEL Current Technology Evaluation Program

    As part of an effort to evaluate the rapidly developing state of 
this technology, the Manufacturers of Emission Control Association 
(MECA) provided four different NOX adsorber catalyst 
formulations to EPA for

[[Page 5050]]

evaluation. Testing of these catalysts at NVFEL revealed that all four 
formulations were capable of reducing NOX emissions by more 
than 90 percent over the broad range of operation in the supplemental 
emission test (SET) procedure as summarized in Figure III-1. At 
operating conditions representative of ``road-load'' operation for a 
heavy duty on-highway truck, the catalysts showed NOX 
reductions as high as 99 percent resulting in NOX emissions 
well below 0.1 g/bhp-hr from an engine-out level of nearly 5 g/bhp-
hr.125 Testing on the FTP has shown similarly good results, 
with hot start FTP NOX emissions reduced by more than 90 
percent. These results demonstrate that significant NOX 
reductions are possible over a broad range of operating conditions with 
current NOX adsorber technology, as typified by the FTP and 
the SET.
---------------------------------------------------------------------------

    \125\ For more information on testing conducted at NVFEL, refer 
to the in-depth discussion given in the RIA, and to the initial test 
report contained in Air Docket A-99-06, Item IV-A-29.
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BILLING CODE 6560-50-P

[[Page 5051]]

[GRAPHIC] [TIFF OMITTED] TR18JA01.003


BILLING CODE 6560-50-C

[[Page 5052]]

    This large body of evidence that NOX adsorbers are 
highly effective, that they can be applied to diesel engines (as 
further described in the RIA), and that there is a clear and strong 
prospect for their further development, causes us to conclude that 
NOX adsorbers will provide at least one feasible path to the 
NOX standards we have set today. Further, we can conclude 
from this development experience that the 0.20 g/bhp-hr NOX 
standard represents the lowest standard achievable by the year 2007, 
having given appropriate consideration to cost, energy, and safety as 
described elsewhere in sections III and V of this document and in the 
RIA.

Remaining Engineering Development

    The considerable success in demonstrating NOX adsorber 
technology in laboratory settings, as outlined above, clearly shows 
that the technology is currently capable of achieving the 
NOX standard level. There are several engineering challenges 
that will be addressed in going from this level of demonstration to 
implementation of durable and effective emission control systems on 
production vehicles. One of these technical challenges involves changes 
to the way diesel engines will need to operate in order to take full 
advantage of the NOX adsorber, representing a shift from 
current day engine operation. Working within the engine design and 
operating principles expected for 2004 model year engines, optimization 
of the total system (matching exhaust temperatures to the operating 
window of NOX adsorbers and controlling exhaust air to fuel 
ratios), will be essential to getting the best performance from the 
NOX adsorber. We have estimated in the RIA that diesel 
engine manufacturers collectively will need to invest $385 million in 
order to implement this change. In addition to the generic need to 
optimize operation to match the NOX adsorber performance, 
industry will further need to address NOX adsorber 
desulfation and its associated issues because some sulfur will still 
remain in the fuel and the engine's lubricating oil.
    Clear engineering paths to address these problems can be described 
today, several years in advance of when they will need to be applied. 
The primary thing that must occur is to eliminate most of the sulfur 
from diesel fuel. The fuel sulfur standard set today in this rulemaking 
overcomes this obstacle. The second set of system engineering steps 
needed to accomplish both NOX regeneration and desulfation 
are already being laid out in test programs conducted by DOE in the 
DECSE Phase II program and in our own test program at the National 
Vehicle and Fuel Emissions Laboratory. The DECSE Phase II program 
clearly demonstrates that, through changes in ``in-cylinder'' 
operation, diesel exhaust conditions can be generated that are 
optimized for NOX storage (fuel lean operation), 
NOX regeneration (fuel rich operation), or desulfation (hot, 
fuel rich operation). This in-cylinder approach, discussed more fully 
in the RIA, represents a likely technical solution for light heavy-duty 
vehicles which are expected to already have the necessary EGR and 
common rail fuel system technologies need for this approach by the 2004 
model year. Testing at NVFEL shows yet another engineering path to 
optimizing the NOX control system external to the combustion 
system. This approach segregates the exhaust into separate streams 
external to the engine and manipulates exhaust conditions by changing 
exhaust mass flow (through valves) and by adding supplemental fuel with 
an electronic fuel injector. This approach means that exhaust 
temperatures and air to fuel ratios can be controlled external to the 
engine allowing great flexibility to control and optimize 
NOX regeneration and sulfur regeneration events. This 
approach may prove to be a good solution for heavy heavy-duty vehicles 
because of the freedom it allows for optimization of both the engine 
operation and the aftertreatment operation with fewer tradeoffs with 
regards to fuel consumption and engine durability. A complete 
description of this approach and its merits is given in the RIA.
    Each of the engineering paths described here shows a means for 
compliance with the NOX standard given further optimization 
and development and, given past experiences with the introduction of 
new technologies, other approaches are likely to be devised as well. 
Given industry's demonstrated ability to develop solutions to similar 
issues with gasoline three-way catalysts and gasoline-based 
NOX adsorber technologies, we are confident that the 
NOX emission control system can be designed for the long 
life required for heavy-duty diesel operation. We are not alone in this 
evaluation of NOX adsorber development, as evidenced by the 
strong endorsement of the technology by many in the 
industry.126 For example, one letter we have received 
stated, ``We believe all NOX Adsorber development issues 
have been identified and the technology is proceeding according to 
schedule. We have identified development paths leading toward 
production optimization and do not see insurmountable technical 
barriers. We are confident in our ability and experience in applying 
the science of surface chemistry and catalysis to achieve our 
objective.'' 127
---------------------------------------------------------------------------

    \126\ Letter from Steven Suttle, Corning, Inc., to Margo Oge, 
EPA, dated October 23, 2000, Item IV-G-59; letter from Martin 
Lassen, Johnson Matthey, to Margo Oge, EPA, dated October 19, 2000, 
Item IV-G-55; letter from John Mooney, Engelhard Corporation, to 
Margo Oge, EPA, dated October 3, 2000, Item IV-G-38; MECA press 
release dated October 3, 2000, Item IV-G-53; and Department of 
Energy, dated September 6, 2000, Item IV-G-28; all contained in 
Docket A-99-06.
    \127\ Letter from John J. Mooney, Director, Technical 
Development and Business Groups, Engelhard Corporation, to Margo 
Oge, Director, OTAQ, EPA, dated October 3, 2000, Item IV-G-38, 
Docket A-99-06.
---------------------------------------------------------------------------

NTE NOX Limits

    The broad NOX reduction capability of the NOX 
adsorbers will also enable the NTE NOX requirements to be 
met. As discussed previously, we have established an NTE NOX 
standard of 1.5  x  FTP standard, or 0.30 g/bhp-hr NOX, 
which is 0.10 g/bhp-hr above the FTP standard. The NMHC+NOX 
NTE standard for 2004 technology HDDEs is 1.25  x  2.5 g/bhp-hr NMHC + 
NOX, or 3.125 g/bhp-hr, which is 0.625 g/bhp-hr above the 
2004 FTP standard. As discussed in the RIA for this final rule, we 
would expect that the majority of the NTE standard for a 2004 
technology engine would be comprised of NOX emissions, 
perhaps as much as 3.0 g/bhp-hr (with the remainder, 0.125 g/bhp-hr, 
being HC). Based on available data, including data from our NVFEL test 
facility, we believe a NOX adsorber system will be capable 
of a 90 percent or greater emission reduction across the entire NTE 
control zone, for the test conditions covered by the NTE test 
procedure, by model year 2007. A 90 percent reduction from the ``base'' 
NOX NTE level of 3.0 g/bhp-hr would result in a tailpipe 
emission rate of 0.30 g/bhp-hr, which is 1.5 times the 2007 FTP 
NOX standard. As discussed in the RIA, we have demonstrated 
NOX reductions on the order of 90 percent or greater across 
the NTE control zone in our test program at NVFEL. A complete 
description of the NOX adsorber testing completed at NVFEL 
is provided in the final RIA and in the docket associated with this 
rule. This testing was performed at standard laboratory conditions; 
however, we do not expect the expanded ambient conditions required for 
NTE compliance to have a significant impact on the performance of the 
exhaust emission control systems. Additional discussion of this issue 
is contained in the RTC and the RIA for this rule.

[[Page 5053]]

Sulfur Trap

    The preceding discussion of NOX adsorbers assumes that 
SOX (SO2 and SO3) emissions will be 
``trapped'' on the surface of the catalyst, effectively poisoning the 
device and requiring a ``desulfation'' (sulfur removal event) to 
recover catalyst efficiency. We believe that, at the 15 ppm cap fuel 
sulfur level, this strategy will allow effective NOX control 
with moderately frequent desulfation and with a modest fuel consumption 
of one percent. We believe this fuel consumption impact will be more 
than offset by reduced reliance on current, more fuel inefficient 
NOX control strategies (see discussion in Section III.G for 
estimates of overall fuel economy impacts). In the NPRM for this 
rulemaking, we sought comment on the potential of a separate 
SOX trap catalyst to control sulfur poisoning of the 
NOX adsorber catalyst. As detailed further in the final RIA 
and RTC documents, we believe that even if a separate SOX 
trap system were used, fuel sulfur levels would have to be 15 ppm or 
lower in order for the NOX adsorber technology to function 
properly over the life of a heavy-duty vehicle.

Urea SCR Technology

    SCR Technology has been put forward by some as another means of 
meeting stringent NOX standards. For reasons discussed below 
we do not believe that it provides an adequate basis for establishing 
the feasibility of today's emission standards. Selective Catalytic 
Reduction (SCR), like the NOX adsorber technology, was first 
developed for stationary applications and is currently being refined 
for the transient operation found in mobile applications. With the SCR 
system, a urea solution is injected upstream of the catalyst which 
breaks down the urea into ammonia and carbon dioxide. The ammonia is 
used as a NOX reductant across the SCR catalyst producing 
N2 and water. Catalysts containing precious metals 
(platinum) can be used at the inlet and outlet of SCR systems designed 
for mobile applications to improve low temperature NOX 
reduction performance and to oxidize any ammonia that may pass through 
the SCR, respectively. SCR systems using these oxidation catalysts and 
being developed for mobile applications are more often called ``compact 
SCR'' systems. Generally, reference to SCR throughout this preamble 
should be taken to mean compact SCR. The use of these platinum 
catalysts enables SCR systems to achieve NOX reductions at 
lower temperatures (as required for diesel engine applications), but 
introduces sensitivity to sulfur in much the same way as for diesel 
particulate filter technologies. Sulfur in diesel fuel inhibits low 
temperature performance and results in high sulfate-make, leading 
directly to higher particulate emissions. For a further discussion of 
SCR system sensitivity to sulfur in diesel fuel, and of its need for 
low sulfur diesel fuel, refer to Section III.F.
    Urea SCR catalysts, like NOX adsorbers, need low sulfur 
diesel fuel to achieve high NOX conversion efficiencies and 
to control sulfate PM emissions. If low sulfur fuel is required, SCR 
NOX control may be possible in some applications by 2007. 
However we believe there are significant barriers to its general use 
for meeting the 2007 standards. SCR systems require vehicles to carry a 
supply of urea. The infrastructure for delivering urea at the diesel 
fuel pump would need to be in place for these devices to be feasible in 
the marketplace; and before development of the infrastructure could 
begin, the industry would have to decide upon a standardized method of 
delivery for the urea supply.
    In addition to this, there would need to be adequate safeguards in 
place to ensure the urea is used throughout the life of the vehicle 
since, given the added cost of urea and the fact that urea depletion 
would not normally affect driveability, there would be an incentive not 
to refill the urea tank. This could lead to considerable uncertainties 
regarding the effectiveness of SCR, even if EPA were to promulgate the 
regulations that likely would be needed to require the regular 
replenishment of urea. Some commenters have suggested that this is the 
key issue with regard to urea SCR systems. One commenter further 
concludes that this issue could be addressed by designing engines with 
on-board diagnostic systems utilizing a NOX sensor that 
would observe a loss of NOX control. When observed, the 
engine would be designed to reduce power gradually until a 50 percent 
loss of power was realized. This power loss would serve to encourage 
the user to replenish the urea tank.128 While such an 
approach may be possible, it raises concerns for public safety as poor 
engine performance could lead to inadequate power for safe merging onto 
highways and other related driving situations. We remain hesitant to 
base a national program on such technology when important issues such 
as driver training on the need to refill the urea tank and the 
consequences of failure to do so cannot be appropriately controlled. 
This approach would seem to suggest a need for EPA-mandated spot checks 
of individual vehicles to ensure compliance with the NOX 
standard. How such a program would work and the burden that it might 
place on small business entities was not addressed in the comments. In 
testimony given at the public hearing held for this rulemaking in Los 
Angeles, the California Trucking Association raised concerns about the 
appropriateness of putting this regulatory burden on truckers when a 
simpler technology such as a diesel NOX adsorber was 
available instead.129 Without measures similar to these, we 
would expect that a substantial number of users would not remember to 
fill their urea tanks. Since failure to provide urea for a vehicle 
would lead to a total loss of NOX control for that vehicle, 
we would need to model the loss of NOX control to be 
expected from an SCR based program. Such a loss in NOX 
control most likely would be appreciable and, in effect, the 
NOX standard would not be met on a fleetwide basis.
---------------------------------------------------------------------------

    \128\ API Comments on the 2007 Heavy Duty Engine/Diesel Sulfur 
Proposed Rule, August 14, 2000, Air Docket A-99-06, IV-D-343.
    \129\ Testimony of Stephanie Williams--Director of Environmental 
Affairs, California Trucking Association to EPA public hearing June 
27, 2000, Air Docket A-99-06, IV-F-190.
---------------------------------------------------------------------------

    We believe that these significant obstacles would prevent the 
widespread or general availability of SCR for use as a NOX 
control strategy to meet the 0.20 g/bhp-hr NOX standard. 
These problems may, however, be resolved in some niche applications; 
for example, certain well-managed centrally-fueled fleets. Because of 
the many obstacles to ensure in-use NOX control with the 
SCR, we do not believe that feasibility of the 0.20 g/bhp-hr 
NOX standard can be based upon SCR technology. For further 
discussion of urea SCR's need for low sulfur diesel fuel, refer to 
section III.F of this preamble.

Summary

    Based on the discussion above, we believe that NOX 
exhaust emission control technology, in combination with low sulfur 
diesel fuel of 15 ppm or lower, is capable of meeting the very 
stringent NOX standards finalized today. The certainty 
provided by this rulemaking that low sulfur diesel fuel will be 
available in the future, and the emission standards finalized today 
that necessitate advanced NOX controls, should lead to rapid 
development of these technologies. The NOX adsorber 
technology has shown remarkable advancement in the last five years, 
both in stationary source applications and

[[Page 5054]]

lean-burn gasoline applications, and now for heavy-duty diesel engines. 
Given this rapid progress, the availability of low sulfur diesel fuel, 
the identification of engineering paths to resolving the technological 
issues, and the lead time provided by today's rulemaking, we believe 
that applying NOX adsorbers to heavy-duty diesel engines 
will provide the emission reductions needed to comply with the 2007 HD 
NOX standards. This can be done in a cost effective way, 
with little or no fuel economy impact, and no special concerns of 
safety.
c. Meeting the NMHC Standard
    Historically control of non-methane hydrocarbon (NMHC) emissions on 
diesel engines has been relatively simple, when compared to gasoline 
engines, due to the net fuel lean (abundant oxygen) operation typical 
of diesel engines. In fact, due to this operating characteristic, 
diesel engine NMHC levels have often been significantly below the 
mandated levels. The introduction of catalytic NOX control 
and the subsequent need to operate under alternately net lean and net 
rich conditions is likely to make NMHC control more difficult.
    Meeting the NMHC standards under the lean operating conditions 
typical of the biggest portion of NOX adsorber operation 
should not present any special challenges to diesel manufacturers. 
Since the devices discussed above--catalyzed particulate filters and 
NOX adsorbers, contain platinum and other precious metals to 
oxidize NO to NO2, they are also very efficient oxidizers of 
hydrocarbons. NMHC emission reductions of greater than 95 percent have 
been shown in these devices over the transient FTP and SET 
modes.130 Given that typical engine-out NMHC is expected to 
be in the 0.20 g/bhp-hr range for engines meeting the 2004 standards, 
this level of NMHC reduction will mean that under lean conditions 
emission levels will be well below the standard.
---------------------------------------------------------------------------

    \130\ ``The Impact of Sulfur in Diesel Fuel on Catalyst Emission 
Control Technology,'' report by the Manufacturers of Emission 
Controls Association, March 15, 1999, pp. 9 & 11.
---------------------------------------------------------------------------

    However, the NOX regeneration strategies for the 
NOX adsorber technology may prove difficult to control 
precisely, leading to a possible increase in HC emissions under the 
rich operating conditions required for NOX regeneration. 
Even with precise control of the regeneration cycle, HC slip may prove 
to be a difficult problem due to the need to regenerate the 
NOX adsorber under net rich conditions (excess fuel) rather 
than the stoichiometric (fuel and air precisely balanced) operating 
conditions typical of a gasoline three-way catalyst. It seems likely 
therefore, that in order to meet the HC standards we have set, an 
additional clean up catalyst may be necessary. A diesel oxidation 
catalyst, like those applied historically for HC and partial PM 
control, can reduce HC reductions (including toxic HCs) by more than 80 
percent.131 This amount of additional control along with 
optimized NOX regeneration strategies will ensure very low 
HC emissions. With such a downstream clean-up device to control HC slip 
during the periodic NOX regeneration event, the HC standard 
we have set here can be met. For a complete description of how the 
clean up catalyst functions in conjunction with the NOX 
adsorber technology, please refer to the complete system description 
given below in section III.E.1.e and to the final RIA.
---------------------------------------------------------------------------

    \131\ Demonstration of Advanced Emission Control Technologies 
Enabling Diesel-Powered Heavy-Duty Engines to Achieve Low Emission 
Levels, Manufacturers of Emissions Controls Association, June 1999.
---------------------------------------------------------------------------

    Given industry's extensive experience with diesel oxidation 
catalysts, the long lead time provided by this rulemaking and the 
availability of less than 15 ppm sulfur diesel fuel, we conclude, 
having given consideration to cost, energy impacts and safety, that the 
NMHC standard is feasible.
d. Meeting the Crankcase Emissions Requirements
    The most common way to eliminate crankcase emissions has been to 
vent the blow-by gases into the engine air intake system, so that the 
gases can be recombusted. Until today's rulemaking, we have required 
that crankcase emissions be controlled only on naturally aspirated 
diesel engines. We have made an exception for turbocharged heavy-duty 
diesel engines because of concerns in the past about fouling that could 
occur by routing the diesel particulates (including engine oil) into 
the turbocharger and aftercooler. However, this is an environmentally 
significant exception since most heavy-duty diesel trucks use 
turbocharged engines, and a single engine can emit over 100 pounds of 
NOX, NMHC, and PM from the crankcase over its lifetime.
    Given the available means to control crankcase emissions, we have 
eliminated this exception. We anticipate that the heavy-duty diesel 
engine manufacturers will be able to control crankcase emissions 
through the use of closed crankcase filtration systems or by routing 
unfiltered blow-by gases directly into the exhaust system upstream of 
the emission control equipment. However, the provision has been written 
such that if adequate control can be had without ``closing'' the 
crankcase then the crankcase can remain ``open.'' Compliance would be 
ensured by adding the emission from the crankcase ventilation system to 
the emissions from the engine control system downstream of any emission 
control equipment.
    We expect that in order to meet the stringent tailpipe emission 
standards set here, that manufacturers will have to utilize closed 
crankcase approaches as described here. Closed crankcase filtration 
systems work by separating oil and particulate matter from the blow-by 
gases through single or dual stage filtration approaches, routing the 
blow-by gases into the engine's intake manifold and returning the 
filtered oil to the oil sump. These systems are required for new heavy-
duty diesel vehicles in Europe starting in 2000. Oil separation 
efficiencies in excess of 90 percent have been demonstrated with 
production ready prototypes of two stage filtration 
systems.132 By eliminating 90 percent of the oil that would 
normally be vented to the atmosphere, the system works to reduce oil 
consumption and to eliminate concerns over fouling of the intake system 
when the gases are routed through the turbocharger. Mercedes-Benz 
currently utilizes this type of system on virtually all of its heavy-
duty diesel engines sold in Europe. An alternative approach would be to 
route the blow-by gases into the exhaust system upstream of the 
catalyzed diesel particulate filter which would be expected to 
effectively trap and oxidize the engine oil and diesel PM. This 
approach may require the use of low sulfur engine oil to ensure that 
oil carried in the blow-by gases does not compromise the performance of 
the sulfur-sensitive emission control equipment.
---------------------------------------------------------------------------

    \132\ Letter from Marty Barris, Donaldson Corporation, to Byron 
Bunker US EPA, March 2000. Air Docket A-99-06.
---------------------------------------------------------------------------

e. The Complete System
    We expect that the technologies described above would be integrated 
into a complete emission control system as described in the final RIA. 
The engine-out emissions will be balanced with the exhaust emission 
control package in such a way that the result is the most beneficial 
from a cost, fuel economy and emissions standpoint. The engine-out 
exhaust characteristics will also have a role in assisting the exhaust 
emission control devices used. The NOX

[[Page 5055]]

adsorber, for instance, will require periods of oxygen-depleted exhaust 
flow in order to accomplish NOX regeneration and to allow 
for sulfur control using desulfation events. This may be most 
efficiently done by reducing the air-fuel ratio that the engine is 
operating under during the regeneration to reduce the oxygen content of 
the exhaust, or alternatively by partitioning the exhaust flow such 
that only a small portion of the exhaust flow is used for 
NOX regeneration, thereby reducing the amount of oxygen 
needing to be depleted through fuel addition. Further, it is envisioned 
that the PM device will be integrated into the exhaust system upstream 
of the NOX reduction device. This placement would allow the 
PM trap to take advantage of the engine-out NOX as an 
oxidant for the particulate, while removing the particulate so that the 
NOX exhaust emission control device will not have to deal 
with large PM deposits which may cause a deterioration in performance. 
Further it allows the NOX adsorber to make use of the 
upstream PM filter as a pre-catalyst to oxidize some NO to 
NO2 and to partially oxidize the reductant (diesel fuel or 
exhaust hydrocarbons) to a more desirable reductant form such as CO 
before entering the NOX adsorber. Of course, there is also 
the possibility of integrating the PM and NOX exhaust 
emission control devices into a single unit to replace a muffler and 
save space (Toyota's DNPR system being an example of this 
approach).133 The final component in any of these system 
configurations is likely to be some form of clean up catalyst which can 
provide control of HC slip during NOX regeneration as well 
as H2S slip during SOx regeneration. Particulate free 
exhaust may also allow for new options in EGR system design to optimize 
its efficiency.
---------------------------------------------------------------------------

    \133\ Revolutionary Diesel Aftertreatment System Simultaneously 
Reduces Diesel Particulate Matter and Nitrogen Oxides, Toyota Motor 
Corporation press release, July 25, 2000, Air Docket A-99-06.
---------------------------------------------------------------------------

    We expect that the emission reduction efficiency of the exhaust 
emission control system will vary across the NTE zone as a function of 
exhaust temperature and space velocity.134 Consequently, to 
maintain the NTE emission cap, the engine-out emissions would have to 
be calibrated with exhaust emission control system performance 
characteristics in mind. This would be accomplished by lowering engine-
out emissions where the exhaust emission control system was less 
efficient, for example by retarding fuel injection timing or increasing 
the EGR rate. Conversely, where the exhaust emission control system is 
very efficient at reducing emissions, the engine-out emissions could be 
tuned for higher emissions and better fuel economy. These trade-offs 
between engine-out emissions and exhaust emission control system 
performance characteristics are similar to those of gasoline engines 
with three-way catalysts in today's light-duty vehicles and can be 
overcome through similar system based engineering solutions. Managing 
and optimizing these trade-offs will be crucial to effective 
implementation of exhaust emission control devices on diesel 
applications.
---------------------------------------------------------------------------

    \134\ The term, ``space velocity,'' is a measure of the volume 
of exhaust gas that flows through a device.
---------------------------------------------------------------------------

2. Feasibility of Stringent Standards for Heavy-Duty Gasoline
    Gasoline emission control technology has evolved rapidly in recent 
years. Emission standards applicable to 1990 model year vehicles 
required roughly 90 percent reductions in exhaust NMHC and CO emissions 
and a 75 percent reduction in NOX emissions compared to 
uncontrolled emissions. Today, some vehicles' emissions are well below 
those necessary to meet the current federal heavy-duty gasoline 
standards, the 2004 heavy-duty gasoline standards, and the California 
Low-Emission Vehicle standards for medium-duty vehicles. The continuing 
emissions reductions have been brought about by ongoing improvements in 
engine air-fuel management hardware and software plus improvements in 
exhaust system and catalyst designs.
    We believe that the types of changes being seen on current vehicles 
have not yet reached their technological limits and continuing 
improvement will allow them to meet today's standards. The RIA 
describes a range of specific emission control techniques that we 
believe could be used. There is no need to invent new technologies, 
although there will be a need to apply existing technology more 
effectively and more broadly. The focus of the effort will be in the 
application and optimization of these existing technologies.
    In our light-duty Tier 2 rule, we have required that gasoline 
sulfur levels be reduced to a 30 ppm average, with an 80 ppm maximum. 
This sulfur level reduction is the primary enabler for the Tier 2 
standards. Similarly, we believe that the gasoline sulfur reduction, 
along with refinements in existing gasoline emission control 
technology, will be sufficient to allow heavy-duty gasoline vehicles 
and engines to meet the emission standards sought by today's rule.
    However, we recognize that the emission standards are stringent, 
and considerable effort will have to be undertaken. For example, we 
expect that every engine will have to be recalibrated to improve upon 
its cold start emission performance. Manufacturers will have to migrate 
their light-duty calibration approaches to their heavy-duty offerings 
to provide cold start performance in line with what they will have to 
achieve to meet the Tier 2 standards.
    We also project that today's new heavy-duty gasoline standards 
would require the application of advanced engine and catalyst systems 
similar to those projected for their light-duty counterparts. 
Historically, manufacturers have introduced technology on light-duty 
gasoline applications and then applied those technologies to their 
heavy-duty gasoline applications. Today's standards will allow 
manufacturers to take this same approach. In other words, we expect 
that manufacturers will meet today's new standards through the 
application of technology developed to meet light-duty Tier 2 standards 
for 2004.
    Improved calibration and systems management will be critical in 
optimizing the performance of the engine with the advanced catalyst 
system. Precise air/fuel control must be tailored for emissions 
performance and must be optimized for all types of driving. Calibration 
refinements may also be needed for EGR system optimization and to 
reduce cold start emissions through methods such as spark timing 
retard. We also project that electronic control modules with expanded 
capabilities will be needed on some vehicles and engines.
    We also expect increased use of other technologies in conjunction 
with those described above. We expect some increased use of air 
injection to improve upon cold start emissions. We may also see air-gap 
manifolds, exhaust pipes, and catalytic converter shells as a means of 
improving upon catalyst light-off times thereby reducing cold start 
emissions. Other, non-catalyst related improvements to gasoline 
emission control technology include higher speed computer processors 
which enable more sophisticated engine control algorithms and improved 
fuel injectors providing better fuel atomization thereby improving fuel 
combustion.
    Catalyst system durability is, and will always be, a serious 
concern. Historically, catalysts have deteriorated when exposed to very 
high temperatures. This has long been a concern especially for heavy-
duty work

[[Page 5056]]

vehicles. However, catalyst manufacturers continue to make strides in 
the area of thermal stability and we expect that improvements in 
thermal stability will continue for the next generation of catalysts.
    We believe that, by optimizing all of these technologies, 
manufacturers will be able to achieve today's standards. Advanced 
catalyst systems have already shown potential to reduce emissions to 
close to these levels. Some current California vehicles are certified 
to levels below 0.20 g/mi NOX. California tested an advanced 
catalyst system on a vehicle loaded to a test weight comparable to a 
heavy-duty vehicle test weight and achieved NOX and NMOG 
levels of 0.1 g/mi and 0.16 g/mi, respectively. The California vehicle 
with the advanced catalyst had not been optimized as a system to take 
full advantage of the catalyst's capabilities.
    The compliance flexibility provisions can also be an important tool 
for manufacturers in implementing a new standard. The program allows 
manufacturers to transition to the more stringent standards by 
introducing emissions controls over a longer period of time, as opposed 
to a single model year. Manufacturers plan their product introductions 
well in advance. With the compliance flexibilities, manufacturers can 
better manage their product lines so that the new standards don't 
interrupt their product introduction plans. Also, the program allows 
manufacturers to focus on higher sales volume vehicles first and use 
credits for low sales volume vehicles.
3. Feasibility of the New Evaporative Emission Standards
    The new evaporative emission standards appear to be feasible now. 
Many designs have been certified that already meet these standards. A 
review of 1998 model year certification data indicates that five of 
eight evaporative system families in the 8,500 to 14,000 pound range 
comply with the new 1.4 g/test standard, while all evaporative system 
families in the over 14,000 pound range comply with the new 1.9 g/test 
standard.
    The new evaporative emission standards should not require the 
development of new materials but may, in some cases, require new 
application of existing materials. Low permeability materials and low 
loss connections and seals are already used to varying degrees on 
current vehicles, but that practice may become more widespread. Today's 
new standards would likely ensure their consistent use and discourage 
manufacturers from switching to cheaper materials or designs to take 
advantage of the large safety margins they have had under current 
standards.
    There are two approaches to reducing evaporative emissions for a 
given fuel. One is to minimize the potential for permeation and leakage 
by reducing the number of hoses, fittings and connections. The second 
is to use less permeable hoses and lower loss fittings and connections. 
Manufacturers are already employing both approaches.
    Most manufacturers are moving to ``returnless'' fuel injection 
systems. Through more precise fuel pumping and metering, these systems 
eliminate the return line in the fuel injection system. The return line 
carries unneeded fuel from the fuel injectors back to the fuel tank. 
Because the fuel injectors are in such close contact with the hot 
engine, the fuel returned from the injectors to the fuel tank has been 
heated. This returned fuel is a significant source of fuel tank heat 
and vapor generation. The elimination of the return line also reduces 
the total length of hose on the vehicle though which vapors can 
permeate, and it reduces the number of fittings and connections through 
which fuel can leak.
    Low permeability hoses and seals, and low loss fittings are 
available and are already used on many vehicles. Fluoropolymer 
materials can be added as liners to hose and component materials to 
yield large reductions in permeability over such conventional materials 
as monowall nylon. In addition, fluoropolymer materials can greatly 
reduce the adverse impact of alcohols in gasoline on permeability of 
evaporative components, hoses and seals.

F. Need for Low Sulfur Diesel Fuel

    The following discussion will build upon the brief sulfur 
sensitivity points made earlier in this section by providing a more in-
depth discussion of sulfur's effect on the diesel exhaust emission 
control technologies. In order to evaluate the effect of sulfur on 
diesel exhaust control technologies, we used three key factors to 
categorize the impact of sulfur in fuel on emission control function. 
These factors were efficiency, reliability, and fuel economy. Taken 
together these three factors lead us to believe that diesel fuel sulfur 
levels of 15 ppm will be required in order to make feasible the heavy-
duty vehicle emission standards. Brief summaries of these factors are 
provided below. A more in-depth review is given in the following 
subsections and in the final RIA.
    The efficiency of emission control technologies to reduce harmful 
pollutants is directly affected by sulfur in diesel fuel. Initial and 
long term conversion efficiencies for NOX, NMHC, CO and 
diesel PM emissions are significantly reduced by catalyst poisoning and 
catalyst inhibition due to sulfur. NOX conversion 
efficiencies with the NOX adsorber technology in particular 
are dramatically reduced in a very short time due to sulfur poisoning 
of the NOX storage bed. In addition, total PM control 
efficiency is negatively impacted by the formation of sulfate PM. As 
explained in detail in the following sections, all of the advanced 
NOX and PM technologies described here have the potential to 
make significant amounts of sulfate PM under operating conditions 
typical of heavy-duty vehicles. We believe that the formation of 
sulfate PM will be in excess of the total PM standard, unless diesel 
fuel sulfur levels are at or below 15 ppm. Based on the strong negative 
impact of sulfur on emission control efficiencies for all of the 
technologies evaluated, we believe that 15 ppm represents an upper 
threshold of acceptable diesel fuel sulfur levels.
    Reliability refers to the expectation that emission control 
technologies must continue to function as required under all operating 
conditions for the life of the vehicle. As discussed in the following 
sections, sulfur in diesel fuel can prevent proper operation of both 
NOX and PM control technologies. This can lead to permanent 
loss in emission control effectiveness and even catastrophic failure of 
the systems. Sulfur in diesel fuel impacts reliability by decreasing 
catalyst efficiency (poisoning of the catalyst), increasing diesel 
particulate filter loading, and negatively impacting system 
regeneration functions. Among the most serious reliability concerns 
with sulfur levels greater than 15 ppm are those associated with 
failure to properly regenerate. In the case of the NOX 
adsorber, failure to regenerate will lead to rapid loss of 
NOX emission control as a result of sulfur poisoning of the 
NOX adsorber bed. In the case of the diesel particulate 
filter, sulfur in the fuel reduces the reliability of the regeneration 
function. If regeneration does not occur, catastrophic failure of the 
filter could occur. It is only by the availability of low sulfur diesel 
fuels that these technologies become feasible. The analysis given in 
the following section makes clear that diesel fuel sulfur levels will 
need to be under 15 ppm in order to ensure robust operation of the 
technologies under the variety of operating conditions anticipated to 
be experienced in the field.
    Fuel economy impacts due to sulfur in diesel fuel affect both 
NOX and PM

[[Page 5057]]

control technologies. The NOX adsorber sulfur regeneration 
cycle (desulfation cycle) can consume significant amounts of fuel 
unless fuel sulfur levels are very low. The larger the amount of sulfur 
in diesel fuel, the greater the adverse effect on fuel economy. As 
sulfur levels increase above 15 ppm, the adverse effect on fuel economy 
becomes more significant, increasing above one percent and doubling 
with each doubling of fuel sulfur level. Likewise, PM trap regeneration 
is inhibited by sulfur in diesel fuel. This leads to increased PM 
loading in the diesel particulate filter and increased work to pump 
exhaust across this restriction. With low sulfur diesel fuel, diesel 
particulate filter regeneration can be optimized to give a lower (on 
average) exhaust backpressure and thus better fuel economy. Thus, for 
both NOX and PM technologies the lower the fuel sulfur level 
the lower the operating costs of the vehicle.
1. Catalyzed Diesel Particulate Filters and the Need for Low Sulfur 
Fuel
    Diesel particulate filters (PM traps) function to control diesel PM 
through mechanical filtration of PM from the diesel exhaust stream and 
then oxidation of the stored PM (trap regeneration). Through oxidation 
in the catalyzed diesel particulate filter the stored carbonaceous PM 
is converted to CO2 and released into the atmosphere. 
Failure to oxidize the stored PM leads to accumulation in the trap, 
eventually causing the trap to become so full that it severely 
restricts exhaust flow through the device, leading to trap or vehicle 
failure.
    As discussed earlier in this section, uncatalyzed diesel 
particulate filters require exhaust temperatures in excess of 650 deg. 
C in order for the collected PM to be oxidized by the oxygen available 
in diesel exhaust. That temperature threshold for oxidation of PM by 
exhaust oxygen can be decreased to 450 deg. C through the use of base 
metal catalytic technologies. For a broad range of operating conditions 
typical of in use operation, diesel exhaust is significantly cooler 
than 400 deg. C. If oxidation of the trapped PM could be assured to 
occur at exhaust temperatures lower than 300 deg. C, then diesel 
particulate filters would be expected to be robust for most 
applications and operating regimes. Oxidation of PM (regeneration of 
the trap) at such low exhaust temperatures can occur by using oxidants 
which are more readily reduced than oxygen. One such oxidant is 
NO2.
    NO2 can be produced in diesel exhaust through the 
oxidation of the nitrogen monoxide (NO), created in the engine 
combustion process, across a catalyst. The resulting NO2-
rich exhaust is highly oxidizing in nature and can oxidize trapped 
diesel PM at temperatures as cool as 250 deg.C.135 Some 
platinum group metals are known to be good catalysts to promote the 
oxidation of NO to NO2. Therefore in order to ensure passive 
regeneration of the diesel particulate filters, significant amounts of 
platinum group metals (primarily platinum) are being used in the wash-
coat formulations of advanced diesel particulate filters. The use of 
platinum to promote the oxidation of NO to NO2 introduces 
several system vulnerabilities affecting both the durability and the 
effectiveness of the catalyzed diesel particulate filter when sulfur is 
present in diesel exhaust. The two primary mechanisms by which sulfur 
in diesel fuel limits the robustness and effectiveness of diesel 
particulate filters are inhibition of trap regeneration, through 
inhibition of the oxidation of NO to NO2, and a dramatic 
loss in total PM control effectiveness due to the formation of sulfate 
PM. Unfortunately, these two mechanisms trade-off against one another 
in the design of diesel particulate filters. Changes to improve the 
reliability of regeneration by increasing catalyst loadings lead to 
increased sulfate emissions and, thus, loss of PM control 
effectiveness. Conversely, changes to improve PM control by reducing 
the use of platinum group metals and, therefore, limiting ``sulfate 
make'' leads to less reliable regeneration. We believe the only means 
of achieving good PM emission control and reliable operation is to 
reduce sulfur in diesel fuel, as shown in the following subsections.
---------------------------------------------------------------------------

    \135\ Hawker, P. et al., Experience with a New Particualte Trap 
Technology in Europe, SAE 970182.
---------------------------------------------------------------------------

a. Inhibition of Trap Regeneration Due to Sulfur
    The passively regenerating diesel particulate filter technologies 
rely on the generation of a very strong oxidant, NO2, to 
ensure that the carbon captured by the PM trap's filtering media is 
oxidized under the exhaust temperature range of normal operating 
conditions. This prevents plugging and failure of the PM trap. 
NO2 is produced through the oxidation of NO in the exhaust 
across a platinum catalyst. This oxidation is inhibited by sulfur 
poisoning of the catalyst surface.136 This inhibition limits 
the total amount of NO2 available for oxidation of the 
trapped diesel PM, thereby raising the minimum exhaust temperature 
required to ensure trap regeneration. Without sufficient 
NO2, the amount of PM trapped in the diesel particulate 
filter will continue to increase and can lead to excessive exhaust back 
pressure, low engine power, and even catastrophic failure of the diesel 
particulate filter itself.
---------------------------------------------------------------------------

    \136\ Hawker, P. et al, Experience with a New Particulate Trap 
Technology in Europe, SAE 970182.
---------------------------------------------------------------------------

    The failure mechanisms experienced by diesel particulate filters 
due to low NO2 availability vary significantly in severity 
and long term consequences. In the most fundamental sense, the failure 
is defined as an inability to oxidize the stored particulate at a rate 
fast enough to prevent net particulate accumulation over time. The 
excessive accumulation of PM over time blocks the passages through the 
filtering media, making it more restrictive to exhaust flow. In order 
to continue to force the exhaust through the now more restrictive 
filter, the exhaust pressure upstream of the filter must increase. This 
increase in exhaust pressure is commonly referred to as increasing 
``exhaust backpressure'' on the engine.
    The increase in exhaust backpressure represents increased work 
being done by the engine to force the exhaust gas through the 
increasingly restrictive particulate filter. Unless the filter is 
frequently cleansed of the trapped PM, this increased work can lead to 
reductions in engine performance and increases in fuel consumption. 
This loss in performance may be noted by the vehicle operator in terms 
of poor acceleration and generally poor driveability of the vehicle. In 
some cases, engine performance can be so restricted that the engine 
stalls, stranding the vehicle. This progressive deterioration of engine 
performance as more and more PM is accumulated in the filter media is 
often referred to as ``trap plugging.'' Trap plugging also has the 
potential to cause engine damage. If the exhaust backpressure gets high 
enough to open the exhaust valves prematurely, the exhaust valves can 
then strike the piston causing catastrophic engine failure. Whether 
trap plugging occurs, and the speed at which it occurs, will be a 
function of many variables in addition to the fuel sulfur level; these 
variables include the vehicle application, its duty cycle, and ambient 
conditions. However, if the fuel sulfur level is sufficiently high to 
prevent trap regeneration in any real world conditions experienced, 
trap plugging can occur. This is not to imply that any time a vehicle 
is refueled once with high sulfur fuel trap plugging will occur. 
Rather, it is important to know that the use of fuel with sulfur levels 
higher than 15 ppm significantly

[[Page 5058]]

increases the chances of particulate filter failure.
    Catastrophic failure of the filter can occur when excessive amounts 
of PM are trapped in the filter due to a lack of NO2 for 
oxidation. This failure occurs when excessive amounts of trapped PM 
begin to oxidize at high temperatures (combustion-like temperatures of 
over 1000 deg. C) leading to a ``run-away'' combustion of the PM. This 
can cause temperatures in the filter media to increase in excess of 
that which can be tolerated by the particulate filter itself. For the 
cordierite material commonly used as the trapping media for diesel 
particulate filters, the high thermal stresses caused by the high 
temperatures can cause the material to crack or melt. This can allow 
significant amounts of the diesel particulate to pass through the 
filter without being captured during the remainder of the vehicle's 
life. That is, the trap is destroyed and PM emission control is lost. 
Further the high temperatures generated during this event can destroy 
the downstream catalyst components, such as the NOX 
adsorber, rendering them ineffective as well.
    Full field test evaluations and retrofit applications of these 
catalytic trap technologies are occurring in parts of Europe where low 
sulfur diesel fuel is already available.137 The experience 
gained in these field tests helps to clarify the need for low sulfur 
diesel fuel. In Sweden and some European city centers where below 10 
ppm diesel fuel sulfur is readily available, more than 3,000 catalyzed 
diesel particulate filters have been introduced into retrofit 
applications without a single failure. Given the large number of 
vehicles participating in these test programs, the diversity of the 
vehicle applications which included intercity trains, airport buses, 
mail trucks, city buses and garbage trucks, and the extended time 
periods of operation (some vehicles have been operating with traps for 
more than 5 years and in excess of 300,000 miles138), there 
is a strong indication of the robustness of this technology on 10 ppm 
low sulfur diesel fuel. The field experience in areas where sulfur is 
capped at 50 ppm has been less definitive. In regions without extended 
periods of cold ambient conditions, such as the United Kingdom, field 
tests on 50 ppm cap low sulfur fuel have also been positive, matching 
the durability at 10 ppm, although sulfate PM emissions are much 
higher. However, field tests on 50 ppm fuel in Finland, where colder 
winter conditions are sometimes encountered (similar to many parts of 
the United States), showed a significant number of failures (~10 
percent) due to trap plugging. This 10 percent failure rate has been 
attributed to insufficient trap regeneration due to fuel sulfur in 
combination with low ambient temperatures.139 Other possible 
reasons for the high failure rate in Finland when contrasted with the 
Swedish experience appear to be unlikely. The Finnish and Swedish 
fleets were substantially similar, with both fleets consisting of 
transit buses powered by Volvo and Scania engines in the 10 to 11 liter 
range. Further, the buses were operated in city areas and none of the 
vehicles were operated in northern extremes such as north of the Arctic 
Circle.140 Given that the fleets in Sweden and Finland were 
substantially similar, and given that ambient conditions in Sweden are 
expected to be similar to those in Finland, we believe that the 
increased failure rates noted here are due to the higher fuel sulfur 
level in a 50 ppm cap fuel versus a 10 ppm cap fuel.141 
Testing on an even higher fuel sulfur level of 200 ppm was conducted in 
Denmark on a fleet of 9 vehicles. In less than six months all of the 
vehicles in the Danish fleet had failed due to trap 
plugging.142 The failure of some fraction of the traps to 
regenerate when operated on fuel with sulfur caps of 50 ppm and 200 ppm 
is believed to be primarily due to inhibition of the NO to 
NO2 conversion as described here. Similarly the increasing 
frequency of failure with higher fuel sulfur levels is believed to be 
due to the further suppression of NO2 formation when higher 
sulfur level diesel fuel is used.
---------------------------------------------------------------------------

    \137\ Through tax incentives 50 ppm cap sulfur fuel is widely 
available in the United Kingdom and 10 ppm sulfur is available in 
Sweden and in certain European city centers.
    \138\ Allansson, et al. SAE 2000-01-0480
    \139\ Letter from Dr. Barry Cooper, Johnson Matthey, to don 
Kopinski, US EPA, Air Docket A-99-06.
    \140\ Telephone conversation between Dr. Barry Cooper, Johnson 
Matthey, and Todd Sherwood, EPA, Air Docket A-99-06.
    \141\ The average temperature in Helsinki, Finland, for the 
month of January is 21 deg. F. The average temperature in Stockholm, 
Sweden, for the month of Juanuary is 21 deg. F. The average 
temperature at the University of Michigan in Ann Arbor, Michigan, 
for the month of January is 24 deg. F. The temperatures reported 
here are from www.worldclimate.com based upon the Global Historical 
Climatology Network (GHCN) produced jointly by the National Climatic 
Data Center and Carbon Dioxide Information Analysis Center at Oak 
Ridge National Laboratory (ORNL).
    \12\ Letter from Dr. Barry Cooper to Don Kopinski US EPA, Air 
Docket A-99-06.
---------------------------------------------------------------------------

    As shown above, sulfur in diesel fuel inhibits NO oxidation leading 
to increased exhaust backpressure, reduced fuel economy, compromised 
reliability, and potentially engine damage. Therefore, we believe that, 
in order to ensure reliable and economical operation over a wide range 
of expected operating conditions, diesel fuel sulfur levels should be 
at or below 15 ppm. With these low sulfur levels we believe, as 
demonstrated by experience in Europe, that catalyzed diesel particulate 
filters will prove to be both durable and effective at controlling 
diesel particulate emissions. We did receive comments from the refining 
industry suggesting that PM filters could work on fuel sulfur levels as 
high as 50 ppm. The commenters pointed to some specific test programs 
where fuel with an approximate average sulfur level of 30 ppm was used 
as evidence of the robustness of the technology on higher sulfur fuels. 
While we do not deny that it is possible to operate some vehicles in 
limited applications over defined driving cycles on fuel as high as 30 
ppm, we do not believe that this limited data should be the basis for a 
national program. The reality that some vehicles do fail on 50 ppm cap 
fuel, as demonstrated by the Finish fleet results mentioned above, 
shows that durability is not assured with the use of higher sulfur 
diesel fuel. We believe that the evidence, as a whole, shows that 
oxidation of NO to NO2 will be poisoned due to these higher 
fuel sulfur levels with a resulting significant possibility of PM trap 
failures that is too great a concern for us to feel confident about a 
fuel sulfur level higher than 15 ppm.
b. Loss of PM Control Effectiveness
    In addition to inhibiting the oxidation of NO to NO2, 
the sulfur dioxide (SO2) in the exhaust stream is itself 
oxidized to sulfur trioxide (SO3) at very high conversion 
efficiencies by the precious metals in the catalyzed particulate 
filters. The SO3 serves as a precursor to the formation of 
hydrated sulfuric acid (H2SO4+H2O), or 
sulfate PM, as the exhaust leaves the vehicle tailpipe. Virtually all 
of the SO3 is converted to sulfate under dilute exhaust 
conditions in the atmosphere as well in the dilution tunnel used in 
heavy-duty engine testing. Since virtually all sulfur present in diesel 
fuel is converted to SO2, the precursor to SO3, 
as part of the combustion process, the total sulfate PM is directly 
proportional to the amount of sulfur present in diesel fuel. Therefore, 
even though diesel particulate filters are very effective at trapping 
the carbon and the SOF portions of the total PM, the overall PM 
reduction efficiency of catalyzed diesel particulate filters drops off 
rapidly with increasing sulfur levels due to the formation of sulfate 
PM downstream of the trap.

[[Page 5059]]

    SO2 oxidation is promoted across a catalyst in a manner 
very similar to the oxidation of NO, except it is converted at higher 
rates, with peak conversion rates in excess of 50 percent. The 
SO2 oxidation rate for a platinum based oxidation catalyst 
typical of the type which might be used in conjunction with, or as a 
washcoat on, a catalyzed diesel particulate filter can vary 
significantly with exhaust temperature. At the low temperatures typical 
of some urban driving and the heavy-duty federal test procedure (HD-
FTP), the oxidation rate is relatively low, perhaps no higher than ten 
percent. However at the higher temperatures that might be more typical 
of highway driving conditions and the Supplemental Emission Test (also 
called the EURO III or 13 mode test), the oxidation rate may increase 
to 50 percent or more. These high levels of sulfate make across the 
catalyst are in contrast to the very low SO2 oxidation rate 
typical of diesel exhaust (typically less than 2 percent). This 
variation in expected diesel exhaust temperatures means that there will 
be a corresponding range of sulfate production expected across a 
catalyzed diesel particulate filter.
    The US Department of Energy in cooperation with industry conducted 
a study entitled DECSE to provide insight into the relationship between 
advanced emission control technologies and diesel fuel sulfur levels. 
Interim report number four of this program gives the total particulate 
matter emissions from a heavy-duty diesel engine operated with a diesel 
particulate filter on several different fuel sulfur levels. A straight 
line fit through this data is presented in Table III.F-1 below showing 
the expected total direct PM emissions from a heavy-duty diesel engine 
on the supplemental emission test cycle.143 The data can be 
used to estimate the PM emissions from heavy-duty diesel engines 
operated on fuels with average fuel sulfur levels in this range.
---------------------------------------------------------------------------

    \143\ Note that direct emisisons are those pollutants emitted 
directly from the engine or from the tailpipe depending on the 
context in which the term is used, and indirect emissions are those 
pollutants formed in the atmosphere through chemical reactions 
between direct emissions and other atmospheric constituents.

 Table III.F-1.--Estimated PM Emissions From a Heavy-Duty Diesel Engine
                   at the Indicated Fuel Sulfur Levels
------------------------------------------------------------------------
                                            Supplemental emission test
-----------------------------------------           performance
                                         -------------------------------
                                                            PM increase
           Fuel sulfur  [ppmm]             Tailpipe PM b   relative to 3
                                            [g/bhp-hr]       to 3 ppm
                                                              sulfur
------------------------------------------------------------------------
3.......................................           0.003  ..............
7 a.....................................           0.006            100%
15a.....................................           0.009            200%
30......................................           0.017            470%
150.....................................           0.071          2300%
------------------------------------------------------------------------
a The PM emissions at these sulfur levels are based on a straight-line
  fit to the DECSE data; PM emissions at other sulfur levels are actual
  DECSE data. (Diesel Emission Control Sulfur Effects (DECSE) Program--
  Phase II Interim Data Report No. 4, Diesel Particulate Filters-Final
  Report, January 2000. Table C1.) Although DECSE tested diesel
  particulate filters at these fuel sulfur levels, they do not conclude
  that the technology is feasible at all levels, but they do note that
  testing at 150 ppm is a moot point as the emission levels exceed the
  engine's baseline emission level.
b b Total exhaust PM (soot, SOF, sulfate).

    Table III.F-1 makes it clear that there are significant PM emission 
reductions possible with the application of catalyzed diesel 
particulate filters and low sulfur diesel fuel. At the observed sulfate 
PM conversion rates, the DECSE program results show that the 0.01 g/
bhp-hr total PM standard is feasible for diesel particulate filter 
equipped engines operated on fuel with a sulfur level at or below 15 
ppm. The results also show that diesel particulate filter control 
effectiveness is rapidly degraded at higher diesel fuel sulfur levels 
due to the high sulfate PM make observed with this technology. It is 
clear that PM reduction efficiencies are limited by sulfur in diesel 
fuel and that, in order to realize the PM emissions benefits sought in 
this rule, diesel fuel sulfur levels must be at or below 15 ppm. The 
data further indicates that were the fuel sulfur level set at a 30 ppm 
average, as some commenters suggested, the PM emissions from the 
controlled vehicles would be nearly three times the emissions from a 
vehicle operating on fuel with a 7 ppm average.
c. Increased Maintenance Cost for Diesel Particulate Filters Due to 
Sulfur
    In addition to the direct performance and durability concerns 
caused by sulfur in diesel fuel, it is also known that sulfur can lead 
to increased maintenance costs, shortened maintenance intervals, and 
poorer fuel economy for particulate filters. Diesel particulate filters 
are highly effective at capturing the inorganic ash produced from 
metallic additives in engine oil. This ash is accumulated in the filter 
and is not removed through oxidation, unlike the trapped carbonaceous 
PM. Periodically the ash must be removed by mechanical cleaning of the 
filter with compressed air or water. This maintenance step is 
anticipated to occur on intervals of well over one hundred thousand 
miles. However, sulfur in diesel fuel increases this ash accumulation 
rate through the formation of metallic sulfates in the filter, which 
increases both the size and mass of the trapped ash. By increasing the 
ash accumulation rate, the sulfur shortens the time interval between 
the required maintenance of the filter and negatively impacts fuel 
economy.
2. Diesel NOX Catalysts and the Need for Low Sulfur Fuel
    All of the NOX exhaust emission control technologies 
discussed previously in Section III are expected to utilize platinum to 
oxidize NO to NO2 to improve the NOX reduction 
efficiency of the catalysts at low temperatures or as in the case of 
the NOX adsorber, as an essential part of the process of 
NOX storage. This reliance on NO2 as an integral 
part of the reduction process means that the NOX exhaust 
emission control technologies, like the PM exhaust emission control 
technologies, will have problems with sulfur in diesel fuel. In 
addition, NOX adsorbers have the added problem that the 
adsorption function itself is poisoned by the presence of sulfur. The 
resulting need to remove the stored sulfur (desulfate) leads to a need 
for extended high temperature operation which can deteriorate the 
NOX adsorber. These limitations due to sulfur in the fuel 
affect the overall performance and feasibility of the technologies.
a. Sulfur Poisoning (Sulfate Storage) on NOX Adsorbers
    The NOX adsorber technology relies on the ability of the 
catalyst to store NOX as a nitrate (MNO3) on the 
surface of the catalyst, or adsorber (storage) bed, during lean 
operation. Because of the similarities in chemical properties of 
SOX and NOX, the SO2 present in the 
exhaust is also stored by the catalyst surface as a sulfate 
(MSO4). The sulfate compound that is formed is significantly 
more stable than the nitrate compound and is not released and reduced 
during the NOX release and reduction step (NOX 
regeneration step). Since the NOX adsorber is essentially 
100 percent effective at capturing SO2 in the adsorber bed, 
the sulfur build up on the adsorber bed occurs rapidly. As a result, 
sulfate compounds quickly occupy all of the NOX storage 
sites on the catalyst

[[Page 5060]]

thereby rendering the catalyst ineffective for NOX storage 
and subsequent NOX reduction (poisoning the catalyst).
    The stored sulfur compounds can be removed by exposing the catalyst 
to hot (over 650 deg.C) and rich (air-fuel ratio below the 
stoichiometric ratio of 14.5 to 1) conditions for a brief 
period.144 Under these conditions, the stored sulfate is 
released and reduced in the catalyst.145 While research to 
date on this procedure has been very favorable with regards to sulfur 
removal from the catalyst, it has revealed a related vulnerability of 
the NOX adsorber catalyst. Under the high temperatures used 
for desulfation, the metals that make up the storage bed can change in 
physical structure. This leads to lower precious metal dispersion, or 
``metal sintering,'' (a less even distribution of the catalyst sites) 
reducing the effectiveness of the catalyst.146 This 
degradation of catalyst efficiency due to high temperatures is often 
referred to as thermal degradation. Thermal degradation is known to be 
a cumulative effect. That is, with each excursion to high temperature 
operation, some additional degradation of the catalyst occurs.
---------------------------------------------------------------------------

    \144\ Dou, Danan and Bailey, Owen, ``Investigation of 
NOX Adsorber Catalyst Deactivation,'' SAE 982594.
    \145\ Guyon M. et al, ``Impact of Sulfur on NOX Trap 
Catalyst Activity--Study of the Regeneration Conditions'', SAE 
982607.
    \146\ though it was favroable to decompose sulfate at 800 deg.C, 
performance of the NSR (NOX Storage Reduction catalyst, 
i.e. NOX Adsorber) catalyst decreased due to sintering of 
precious metal.--Asanuma, T. et al, ``Influence of Sulfur 
Concentration in Gasoline on NOX Storage--Reduction 
Catalyst'', SAE 1999-01-3501.
---------------------------------------------------------------------------

    One of the best ways to limit thermal degradation is by limiting 
the accumulated number of desulfation events over the life of the 
vehicle. Since the period of time between desulfation events is 
expected to be determined by the amount of sulfur accumulated on the 
catalyst (the higher the sulfur accumulation rate, the shorter the 
period between desulfation events) the desulfation frequency is 
expected to be proportional to the fuel sulfur level. In other words 
for each doubling in the average fuel sulfur level, the frequency and 
accumulated number of desulfation events are expected to double. We 
believe, therefore, that the diesel fuel sulfur level must be set as 
low as possible in order to limit the frequency and duration of 
desulfation events. Without control of fuel sulfur levels below 15 ppm, 
we can no longer conclude with any confidence that sulfur poisoning can 
be controlled without unrecoverable thermal degradation. Some 
commenters have suggested that the NOX adsorber technology 
could meet the NOX standard using diesel fuel with a 30 ppm 
average sulfur level. This would imply that the NOX adsorber 
could tolerate as much as a four fold increase in desulfation frequency 
(when compared to an expected seven to 10 ppm average) without any 
increase in thermal degradation. This conclusion is inconsistent with 
our understanding of the technology that, with each desulfation event, 
some thermal degradation occurs. Therefore, we believe that diesel fuel 
sulfur levels must be at or below 15 ppm in order to limit the number 
and frequency of desulfation events. Limiting the number and frequency 
of desulfation events will limit thermal degradation and, thus, enable 
the NOX adsorber technology to meet the NOX 
standard.
    Sulfur in diesel fuel for NOX adsorber equipped engines 
will also have an adverse effect on fuel economy. The desulfation event 
requires controlled operation under hot and net fuel rich exhaust 
conditions. These conditions, which are not part of a normal diesel 
engine operating cycle, can be created through the addition of excess 
fuel to the exhaust. This addition of excess fuel causes an increase in 
fuel consumption. We have developed a spreadsheet model that estimates 
the frequency of desulfation cycles from published data and then 
estimates the fuel economy impact from this event.147 Table 
III-F.2 shows the estimated fuel economy impact for desulfation of a 
NOX adsorber at different fuel sulfur levels assuming a 
desired 90 percent NOX conversion efficiency. The estimates 
in the table are based on assumed average fuel sulfur levels associated 
with different sulfur level caps. Note that, although we can estimate 
the fuel consumption penalty of operation on diesel fuel sulfur levels 
higher than 15 ppm, this analysis does not consider the higher degree 
of thermal degradation due to the more frequent desulfation events 
which are required for operation on these higher sulfur levels.
---------------------------------------------------------------------------

    \147\ Memo from Byron Bunker, to docket A-99-06, ``Estimating 
Fuel Economy Impacts of NOX Adsorber De-Sulfurization.''

 Table III.F-2.--Estimated Fuel Economy Impact From Desulfation of a 90%
                         Efficient NOX Adsorber
------------------------------------------------------------------------
                                                                 Fuel
                                                  Average      economy
            Fuel sulfur cap  (ppm)              fuel sulfur    penalty
                                                    (ppm)        (in
                                                               percent)
------------------------------------------------------------------------
500...........................................          350           27
50............................................           30            2
25............................................           15            1
15............................................            7            1
5.............................................            2            1
------------------------------------------------------------------------

    The table highlights that the fuel economy penalty associated with 
sulfur in diesel fuel is noticeable even at average sulfur levels as 
low as 15 ppm and increases rapidly with higher sulfur levels. It also 
shows that the use of a NOX adsorber with a 15 ppm sulfur 
cap fuel would be expected to result in a fuel economy impact due to 
the need for desulfation of the catalyst of less than one percent, 
absent other changes in engine design. However, as discussed in Section 
G below, we anticipate that other engine modifications could be made to 
offset this fuel economy impact. For example, a NOX control 
device in the exhaust system could allow use of fuel saving engine 
strategies, such as advanced fuel injection timing, that could be used 
to offset the increased fuel consumption associated with the 
NOX adsorber. The result is that low sulfur fuel enables the 
NOX adsorber which, in turn, enables fuel saving engine 
modifications. The total emission control system fuel economy impact, 
which we estimate to be zero under a 15 ppm cap program, is discussed 
below in Section III.G.
    Future improvements in the NOX adsorber technology are 
expected and needed if the technology is to provide the environmental 
benefits we have projected today. Some of these improvements are likely 
to include improvements in the means and ease of removing stored sulfur 
from the catalyst bed. However because the stored sulfate species are 
inherently more stable than the stored nitrate compounds (from stored 
NOX emissions), we expect that a separate release and 
reduction cycle (desulfation cycle) will always be needed in order to 
remove the stored sulfur. Therefore, we believe that fuel with a sulfur 
level at or below 15 ppm sulfur will be necessary in order to control 
thermal degradation of the NOX adsorber catalyst and to 
limit the fuel economy impact of sulfur in diesel fuel.
b. Sulfate Particulate Production and Sulfur Impacts on Effectiveness 
of NOX Control Technologies
    The NOX adsorber technology relies on a platinum based 
oxidation function

[[Page 5061]]

in order to ensure high NOX control efficiencies. As 
discussed more fully in section III.F.1, platinum based oxidation 
catalysts form sulfate PM from sulfur in the exhaust gases 
significantly increasing PM emissions when sulfur is present in the 
exhaust stream. The NOX adsorber technology relies on the 
oxidation function to convert NO to NO2 over the catalyst 
bed. For the NOX adsorber this is a fundamental step prior 
to the storage of NO2 in the catalyst bed as a nitrate. 
Without this oxidation function the catalyst will only trap that small 
portion of NOX emissions from a diesel engine which is 
NO2. This would reduce the NOX adsorber 
effectiveness for NOX reduction from in excess of 90 percent 
to something well below 20 percent. The NOX adsorber relies 
on platinum to provide this oxidation function due to the need for high 
NO oxidation rates under the relatively cool exhaust temperatures 
typical of diesel engines. Because of this fundamental need for a 
catalytic oxidation function, the NOX adsorber inherently 
forms sulfate PM when sulfur is present in diesel fuel, since sulfur in 
fuel invariably leads to sulfur in the exhaust stream.
    The Compact-SCR technology, like the NOX adsorber 
technology, uses an oxidation catalyst to promote the oxidation of NO 
to NO2 at the low temperatures typical of much of diesel 
engine operation. As discussed above, there are substantial questions 
regarding the ability of SCR systems to be implemented successfully to 
meet the requirements finalized today. By converting a portion of the 
NOX emissions to NO2 upstream of the ammonia SCR 
reduction catalyst, the overall NOX reductions are improved 
significantly at low temperatures. Without this oxidation function, low 
temperature SCR NOX effectiveness is dramatically reduced 
making compliance with the NOX standard impossible. As 
discussed previously in Section III, platinum group metals are known to 
be good catalysts to promote NO oxidation, even at low 
temperatures.148 Therefore, future Compact-SCR systems would 
need to rely on a platinum oxidation catalyst in order to provide the 
required NOX emission control. This use of an oxidation 
catalyst in order to enable good NOX control means that 
Compact SCR systems will produce significant amounts of sulfate PM when 
operated on anything but the lowest fuel sulfur levels due to the 
oxidation of SO2 to sulfate PM promoted by the oxidation 
catalyst.
---------------------------------------------------------------------------

    \148\ Platinum group metals include platinum, palladium, 
rhodium, and other precious metals.
---------------------------------------------------------------------------

    Without the oxidation catalyst promoted conversion of NO to 
NO2, neither of these NOX control technologies 
can meet the NOX standard set here. Therefore each of these 
technologies will require low sulfur diesel fuel to control the sulfate 
PM emissions inherent in the use of oxidation catalysts. The 
NOX adsorber technology may be able to limit its impact on 
sulfate PM emissions by releasing stored sulfur as SO2 under 
rich operating conditions. The Compact-SCR technology, on the other 
hand, has no means to limit sulfate emissions other than through lower 
catalytic function or lowering sulfur in diesel fuel. The degree to 
which the NOX emission control technologies increase the 
production of sulfate PM through oxidation of SO2 to 
SO3 varies somewhat from technology to technology, but it is 
expected to be similar in magnitude and environmental impact to that 
for the PM control technologies discussed previously in section 
III.F.1, since both the NOX and the PM control catalysts 
rely on precious metals to achieve the required NO to NO2 
oxidation reaction.
    Thus, we believe that diesel fuel sulfur levels will need to be at 
or below 15 ppm in order to apply any of these NOX control 
technologies. Without this low sulfur fuel, the NOX control 
technologies are expected to create PM emissions well in excess of the 
PM standard regardless of the engine-out PM levels. Again, as noted 
with the PM control technologies, test results to date on catalysts 
with high oxidation potential indicate that were the fuel sulfur level 
set with a 30 ppm average, as some commenters suggested, the PM 
emissions from the controlled vehicles would increase nearly three fold 
over the level expected from fuel with a 7 ppm average, the average 
fuel sulfur level we would expect from a 15 ppm cap fuel (see Table 
III.F.1).
3. What About Sulfur in Engine Lubricating Oils?
    Current engine lubricating oils have sulfur contents which can 
range from 2,500 ppm to as high as 8,000 ppm by weight. Since engine 
oil is consumed by heavy-duty diesel engines in normal operation, it is 
important that we account for the contribution of oil derived sulfur in 
our analysis of the need for low sulfur diesel fuel. One way to give a 
straightforward comparison of this effect is to express the sulfur 
consumed by the engine as an equivalent fuel sulfur level. This 
approach requires that we assume specific fuel and oil consumption 
rates for the engine. Using this approach, estimates ranging from two 
to seven ppm diesel fuel sulfur equivalence have been made for the 
sulfur contribution from engine oil.149 150 If values at the 
upper end of this range accurately reflect the contribution of sulfur 
from engine oil to the exhaust this would be a concern as it would 
represent 50 percent of the total sulfur in the exhaust under a 15 ppm 
diesel fuel sulfur cap (with an average sulfur level assumed to be 
approximately seven ppm). However, we believe that this simplified 
analysis, while valuable in demonstrating the need to investigate this 
issue further, overstates the likely sulfur contribution from engine 
oil by a significant amount due to its inclusion of engine oil lost 
through the open crankcase system in the estimate of oil consumption to 
the exhaust.
---------------------------------------------------------------------------

    \149\ Whitacre, Shawn. ``Catalyst Compatible'' Diesel Engine 
Oils, DECSE Phase II, Presentation at DOE/NREL Workshop ``Exploring 
Low Emission Diesel Engine Oils.'' January 31, 2000.
    \150\ This estimate assumes that a heavy-duty diesel engine 
consumes 1 quart of engine oil in 2,000 miles of operation, consumes 
fuel at a rate of 1 gallon per 6 miles of operation and that engine 
oil sulfur levels range from 2,000 to 8,000 ppm.
---------------------------------------------------------------------------

    Current heavy-duty diesel engines operate with open crankcase 
ventilation systems which ``consume'' oil by carrying oil from the 
engine crankcase into the environment. This consumed oil is correctly 
included in the total oil consumption estimates, but should not be 
included in estimates of oil entering the exhaust system for this 
analysis, since as currently applied this oil is not introduced into 
the exhaust. At present we estimate that the majority of lube oil 
consumed by an engine meeting the 0.1 g/bhp-hr PM standard is lost 
through crankcase ventilation, rather than through the exhaust. Based 
on assumed engine oil to PM conversion rates and historic soluble 
organic fraction breakdowns we have estimated the contribution of 
sulfur from engine oil to be less than two ppm fuel equivalency. With 
our action to close the crankcase, coupled with the use of closed 
crankcase ventilation systems that separate in excess of 90 percent of 
the oil from the blow-by gases, we believe that this very low 
contribution of lube oil to sulfur in the exhaust can be maintained. 
For a further discussion of our estimates of the sulfur contribution 
from engine oil refer to the final RIA in the docket.

G. Fuel Economy Impact of High Efficiency Control Technologies

    The high efficiency emission control technologies expected to be 
applied in order to meet the NOX and PM standards involve 
wholly new system components integrated into engine designs and 
calibrations, and as such

[[Page 5062]]

may be expected to change the fuel consumption characteristics of the 
overall engine design. After reviewing the likely technology options 
available to the engine manufacturers, we believe that the integration 
of the engine and exhaust emission control systems into a single 
synergistic emission control system will lead to heavy-duty vehicles 
which can meet demanding emission control targets without increasing 
fuel consumption beyond today's levels.
1. Diesel Particulate Filters and Fuel Economy
    Diesel particulate filters are anticipated to provide a step-wise 
decrease in diesel particulate (PM) emissions by trapping and oxidizing 
the diesel PM. The trapping of the very fine diesel PM is accomplished 
by forcing the exhaust through a porous filtering media with extremely 
small openings and long path lengths.151 This approach 
results in filtering efficiencies for diesel PM greater than 90 percent 
but requires additional pumping work to force the exhaust through these 
small openings. The additional pumping work is anticipated to increase 
fuel consumption by approximately one percent.152 However, 
we believe this fuel economy impact can be regained through 
optimization of the engine--PM trap--NOX adsorber system, as 
discussed below.
---------------------------------------------------------------------------

    \151\ Typically, the filtering media is a porous ceramic 
monolith or a metallic fiber mesh.
    \152\ Engine, Fuel, and Emissions Engineering, Incorporated, 
``Economic Analysis of Diesel Aftertreatment System Changes Made 
Possible by Reduction of Diesel Fuel Sulfur Content,'' December 14, 
1999, Air Docket A-99-06.
---------------------------------------------------------------------------

2. NOX Control Technologies and Fuel Economy
    NOX adsorbers are expected to be the primary 
NOX control technology introduced in order to provide the 
reduction in NOX emissions envisioned in this rulemaking. 
NOX adsorbers work by storing NOX emissions under 
fuel lean operating conditions (normal diesel engine operating 
conditions) and then by releasing and reducing the stored 
NOX emissions over a brief period of fuel rich engine 
operation. This brief periodic NOX release and reduction 
step is directly analogous to the catalytic reduction of NOX 
over a gasoline three-way catalyst. In order for this catalyst function 
to occur the engine exhaust constituents and conditions must be similar 
to normal gasoline exhaust constituents. That is, the exhaust must be 
fuel rich (devoid of excess oxygen) and hot (over 250 deg.C). Although 
it is anticipated that diesel engines can be made to operate in this 
way, it is assumed that fuel economy while operating under these 
conditions will be worse than normal. We have estimated that the fuel 
economy impact of the NOX release and reduction cycle would, 
all other things being equal, increase fuel consumption by 
approximately one percent. Again, we believe this fuel economy impact 
can be regained through optimization of the engine--PM trap--
NOX adsorber system, as discussed below.
    In addition to the NOX release and regeneration event, 
another step in NOX adsorber operation may affect fuel 
economy. As discussed earlier, NOX adsorbers are poisoned by 
sulfur in the fuel even at the low sulfur levels mandated here. As 
discussed in the RIA, we anticipate that the sulfur poisoning of the 
NOX adsorber can be reversed through a periodic 
``desulfation'' event. The desulfation of the NOX adsorber 
is accomplished in a similar manner to the NOX release and 
regeneration cycle described above. However it is anticipated that the 
desulfation event will require extended operation of the diesel engine 
at rich conditions.153 This rich operation will, like the 
NOX regeneration event, require an increase in the fuel 
consumption rate and will cause an associated decrease in fuel economy. 
With a 15 ppm fuel sulfur cap, we are projecting that fuel consumption 
for desulfation would increase by one percent or less, which we believe 
can be regained through optimization of the engine-PM trap- 
NOX adsorber system as discussed below.
---------------------------------------------------------------------------

    \153\ Dou, D. and Bailey, O., ``Investigation of NOX 
Adsorber Catalyst Deactivation'' SAE982594.
---------------------------------------------------------------------------

    While NOX adsorbers require non-power producing 
consumption of diesel fuel in order to function properly and, 
therefore, have an impact on fuel economy, they are not unique among 
NOX control technologies in this way. In fact NOX 
adsorbers are likely to have a very favorable NOX to fuel 
economy trade-off when compared to other NOX control 
technologies like cooled EGR and injection timing retard that have 
historically been used to control NOX emissions. Today, most 
diesel engines rely on injection timing control (retarding injection 
timing) in order to meet the 4.0 g/bhp-hr NOX emission 
standard. For 2004 model year compliance, we expect that engine 
manufacturers will use a combination of cooled EGR and injection timing 
control to meet the 2.0 g/bhp-hr NOX standard. Because of 
the more favorable fuel economy trade-off for NOX control 
with EGR when compared to timing control, we have forecast that less 
reliance on timing control will be needed in 2004. Therefore, fuel 
economy will not be changed even at this lower NOX level.
    NOX adsorbers have a significantly more favorable 
NOX to fuel economy trade-off when compared to cooled EGR or 
timing retard alone, or even when compared to cooled EGR and timing 
retard together.154 Current NOX adsorber data 
show greater than 90 percent reduction in NOX emissions over 
the SET, while only increasing fuel consumption by a very reasonable 
two percent. Further the data show that, for significant portions of 
the engine's typical operating range, NOX control in excess 
of 98 percent is possible even with engine-out emissions as high as 5 
g/bhp-hr.155 Therefore, we expect manufacturers to take full 
advantage of the NOX control capabilities of the 
NOX adsorber and project that they will decrease reliance on 
technologies with a less favorable emissions to fuel economy trade-off, 
especially injection timing retard, when operating at conditions where 
the NOX adsorber performance is significantly greater than 
90 percent. We would therefore predict that the fuel economy impact 
currently associated with NOX control from timing retard 
would be decreased by at least three percent. In other words, through 
the application of advanced NOX emission control 
technologies, which are enabled by the use of low sulfur diesel fuel, 
we expect the NOX trade-off with fuel economy to continue to 
improve significantly when compared to today's technologies. This will 
result in both much lower NOX emissions, and potentially 
overall improvements in fuel economy. Improvements could easily offset 
the fuel consumption of the NOX adsorber itself and, in 
addition, the one percent fuel economy loss projected to result from 
the application of PM filters. Consequently, we are projecting no fuel 
economy penalty to result from this rule.
---------------------------------------------------------------------------

    \154\ Zelenka, P. et al, Cooled EGR--A Key Technology for Future 
Efficient HD Diesels, SAE 980190, Society of Automotive Engineers 
1998. Figure 2 from this paper gives a graphical representation of 
how new technologies (including exhaust emission control 
technologies) can shift the trade-off between NOX 
emissions and fuel economy.
    \155\ ``2007 Diesel Emission Test Program, Initial Test 
Report,'' December 11, 2000, Air Docket A-99-06, Item IV-A-29.
---------------------------------------------------------------------------

3. Emission Control Systems for 2007 and Net Fuel Economy Impacts
    We anticipate that, in order to meet the stringent NOX 
and PM emission standards set today, the engine manufacturers will 
integrate engine-based emission control technologies and

[[Page 5063]]

post-combustion emission control technologies into a single systems-
based approach that will fundamentally shift historic trade-offs 
between emissions control and fuel economy. As outlined in the 
preceding two sections, individual components in this system will 
introduce new constraints and opportunities for improvements in fuel 
efficient control of emissions. Having considered the many 
opportunities to fundamentally improve these relationships, we believe 
that it is unlikely that fuel economy will be lower than today's levels 
and, in fact, may improve through the application of these new 
technologies and this new systems approach. Therefore, for our analysis 
of economic impacts in Section V, no penalty or benefit for changes to 
fuel economy are considered.

H. Review of the Status of Heavy-Duty Diesel NOX Emission 
Control Technology

    In the NPRM, we provided a detailed technical evaluation of test 
data and other information that concluded that the proposed program 
would be technologically feasible for all heavy-duty engines. During 
the public comment period, we received many comments as well as 
additional information about the likely status and capability of 
emission control technology development in the 2007 time frame. To this 
information we have added our own updated evaluation of test data as 
well as technical information developed by ourselves and others.
    Based on this information, and as discussed in Sections III.E and 
III.F above, we now have an even higher degree of confidence that 
manufacturers will be able to meet the new heavy-duty standards. 
Manufacturers of heavy-duty gasoline engines will apply essentially the 
same technology that is being developed for light-duty trucks under the 
Tier 2 program and should not have major problems doing so, especially 
given the significant available lead time. Regarding diesels, although 
the technological challenges are somewhat greater than for gasoline 
engines, we believe that manufacturers will achieve the engine 
standards adopted today for 2007 and later years, in conjunction with 
the low sulfur diesel fuel we are also requiring.
    As we discussed earlier, there are two primary technologies that 
diesel engine manufacturers expect to use to meet the standards adopted 
in today's rule, and they are at different stages of commercial 
development. Catalyzed diesel PM trap technologies are in widespread 
fleet testing today, we have shown that there are no serious 
impediments to the widespread application of this technology to heavy-
duty diesel engines that can meet our new standards by 2007, if not 
earlier. Diesel NOX adsorber technology, the emission 
control technology we believe will be used for heavy-duty diesel 
engines to meet the very low NOX emission standards adopted 
today, is less developed relative to PM control technology. Still, as 
we discussed earlier, we have identified a clear technological pathway 
to compliance with the NOX standards using NOX 
adsorber technology. While we do not anticipate major obstacles in 
commercializing these systems by 2007, it is important that the various 
parties in the industry continue to make good progress in their 
development of NOX adsorber technology for heavy-duty diesel 
engines.
    As a mechanism for monitoring and evaluating this technological 
progress, we believe it will be important to publicly reassess the 
status of heavy-duty diesel NOX adsorber systems on an 
ongoing basis. To accomplish this, we will conduct regular biennial 
reviews of the status of heavy-duty NOX adsorber technology. 
For each review, we will collect and analyze information from engine 
manufacturers, NOX adsorber manufacturers, our own testing, 
and other sources. At the end of each review cycle, we will release 
(and post on the Web) a report discussing the status of the technology 
and any implications for the heavy-duty engine emission control 
program. We will release the first report by December 31, 2002 and 
subsequent reports at the end of each second year through December 31, 
2008. This biennial process is similar to that used by the State of 
California to monitor and evaluate their emission control programs.

IV. Our Program for Controlling Highway Diesel Sulfur

    With today's action, we are requiring substantial reductions in 
highway diesel fuel sulfur levels nationwide, because sulfur 
significantly inhibits the ability of the diesel emission control 
devices to function which are necessary to meet the emission standards 
finalized today. With the highway diesel fuel sulfur standard we are 
finalizing today, we have concluded that there will be technology 
available to achieve the reductions required by the stringent emission 
standards we are implementing for model year 2007 and later heavy-duty 
engines.
    In developing the provisions of the fuel program being adopted 
today, we identified several goals that we want the program to achieve. 
First, we must ensure that there will be an adequate supply of highway 
diesel fuel for all vehicles. Second, we must ensure that low sulfur 
diesel fuel will be readily available nationwide for the 2007 and later 
model year heavy-duty vehicles that need it. Finally, we want to ensure 
a smooth transition to low sulfur fuel.
    In the NPRM, we proposed that refiners be required to start 
producing all of their highway diesel fuel at the 15 ppm sulfur level 
beginning in 2006. We also requested comment on a range of options for 
transitioning to the low sulfur diesel fuel over time. With regard to 
the programmatic goals noted above, the proposed approach, which would 
have required all highway diesel fuel to meet the 15 ppm sulfur 
standard in 2006, guaranteed availability of the low sulfur diesel fuel 
throughout the nation. However, many commenters stated concerns that 
the proposed program would not ensure adequate overall supplies of 
highway diesel fuel, especially if some refiners chose not to continue 
producing highway diesel fuel to avoid the changes needed to meet the 
low sulfur levels.
    The final diesel fuel program we are adopting today includes 
flexibilities for the refining industry as a whole, as well as 
additional flexibilities for refiners experiencing hardship 
circumstances. First, the program gives refiners a temporary compliance 
option for low sulfur diesel fuel beginning in mid-2006. The final 
program also includes additional flexibilities for refineries located 
in certain western states (the Geographic Phase-In Area (GPA) 
156), provisions for qualifying small refiners, and a 
general hardship provision for which any refiner may apply under 
certain conditions. These flexibilities ensure that the vast majority 
of refiners nationwide can fully comply at the earliest possible date 
while avoiding an excessive burden on a subset of refiners. The 
following section details each of the requirements of the highway 
diesel fuel program for refiners and importers, summarizes the analyses 
we have performed on the impacts of the temporary compliance option 
being adopted today, and describes additional information we have 
received that supports the changes made to the proposed program. 
Section VII provides additional information about the

[[Page 5064]]

compliance and enforcement provisions that will accompany these 
requirements.
---------------------------------------------------------------------------

    \156\ As defined in the Tier 2 final rulemaking (see 65 FR 6698, 
February 10, 2000), the GPA encompasses the states of Alaska, 
Colorado, Idaho, Montana, New Mexico, North Dakota, Utah and 
Wyoming. Note that minor changes to this area are currently under 
consideration. Any such changes subsequent to today's rule are 
intended to be carried over into today's rule as well.
---------------------------------------------------------------------------

    We believe the highway diesel fuel program we are adopting today 
meets all of the programmatic goals noted above. We believe that the 
final program will ensure that the overall supply of highway diesel 
fuel will be sufficient for all vehicles. To the extent there may have 
been supply concerns with a complete fuel turnover to low sulfur diesel 
in 2006 as some commenters have suggested, the flexibilities for 
refiners contained in the final program will serve as a ``safety 
valve'' by allowing up to 25 percent of the highway diesel fuel to 
remain at the current 500 ppm sulfur standard and providing additional 
time, if needed, for some refiners to fully convert over to low sulfur 
fuel. The combination of flexibilities provided to refiners in today's 
final rule should eliminate any concerns about the potential for supply 
shortfalls of highway diesel fuel. The final diesel fuel program is 
carefully structured so that we are confident there will be widespread 
availability of low sulfur fuel across the nation for 2007 and later 
model heavy-duty vehicles. In this way, the important health benefits 
of this program to people throughout the country can be achieved 
expeditiously, at a reasonable cost, while minimizing the burden on the 
affected industries.
    This section also summarizes our technical feasibility analysis of 
the low sulfur highway diesel fuel program, and the impact of the 
program on other fuel properties and specialty fuels. Finally, the 
following section describes how state programs will be affected by 
today's action including a provision that allows the State of Alaska 
the option of developing an alternative transition plan for 
implementing low sulfur fuel.

A. Highway Diesel Sulfur Standards for Refiners and Importers

    The requirements of the highway diesel fuel sulfur control program 
will become effective in time to be available with the introduction of 
the first heavy-duty engines meeting the model year 2007 and later 
engine standards we are adopting today. The following paragraphs 
describe the requirements, standards, and deadlines that apply to 
refiners and importers of highway diesel fuel and the options available 
to all refiners.
1. Standards and Deadlines That Refiners and Importers Must Meet
    As described earlier in Section III.H. above, the new standards 
being adopted today for heavy-duty engines will begin with the 2007 
model year. With today's action, we are adopting specific dates when 
fuel intended to be marketed as low sulfur diesel fuel must be produced 
at the refinery, distributed at the terminal level, and marketed at the 
retail level. Refiners and importers are required to produce highway 
diesel fuel meeting the 15 ppm sulfur standard beginning June 1, 
2006.157 At the terminal level, highway diesel fuel sold as 
low sulfur fuel is required to meet the 15 ppm sulfur standard 
beginning July 15, 2006. For retail stations and wholesale purchaser-
consumers, highway diesel fuel sold as low sulfur fuel must meet the 15 
ppm sulfur standard by September 1, 2006.
---------------------------------------------------------------------------

    \157\ Highway diesel fuel (referred to as motor vehicle diesel 
fuel in the regulatory language to be consistent with language in 
existing laws and regulations) includes any diesel fuel or any 
distillate product that is used, intended for use, or made available 
for use as a fuel in highway diesel vehicles or engines that are 
subject to the standards finalized today. However, kerosene or other 
distillates such as JP-8 are only considered to be highway diesel 
fuel and thus subject to our program at the point in the production 
or distribution system that they are either designated as such, or 
otherwise used, intended for use, or made available for use in 
highway diesel vehicles. Thus, if refiners do not designate these 
other distillates as highway diesel fuel, they are not subject to 
the 15 ppm sulfur standard.
---------------------------------------------------------------------------

    In the NPRM, we proposed a set of compliance dates slightly earlier 
than the dates contained in today's final rule. Under the proposal, 
refiners, terminals and retailers would have had to begin producing low 
sulfur diesel fuel by April 1, 2006, May 1, 2006 and June 1, 2006, 
respectively. Several commenters pointed out that the April 
introduction date for refiners occurred at the same time refiners would 
be changing over from winter to summer gasoline to comply with Reid 
Vapor Pressure (RVP) requirements. They recommended that the 
introduction of low sulfur diesel fuel be delayed for a couple of 
months to provide refiners and the distribution system the opportunity 
to focus on the two conversions separately and ensure that each occurs 
as designed. Commenters also suggested that we extend the time period 
between the refinery and downstream deadlines to better allow for the 
time it may take the distribution system to make a complete transition 
to the 15 ppm sulfur level.
    In response to these concerns, today's action provides a few 
additional months for introduction of the low sulfur diesel fuel 
compared to the NPRM and provides an additional month between the 
refinery and retail compliance dates, to provide a smoother transition 
through the distribution system. We believe the additional time 
provides appropriate relief for the refiners, while still assuring that 
low sulfur diesel fuel will be available at the retail level no later 
than September 1, 2006. This schedule will allow manufacturers to 
introduce 2007 and later model year diesel engines and vehicles as 
early as September 1, 2006. While a slight delay from the dates of the 
proposal, the Agency does not believe this delay will place any undue 
burden on the engine manufacturers. Historically, new heavy-duty 
vehicle models were introduced on or around January 1 (of the same 
calendar year as the model year). Only recently, manufacturers have 
begun introducing some model lines earlier, particularly light heavy-
duty vehicles.
    In the NPRM, we proposed that all highway diesel fuel be required 
to comply with the 15 ppm sulfur standard starting in 2006. Today's 
program includes a combination of flexibilities available to refiners 
to ensure a smooth transition to low sulfur highway diesel fuel. 
Refiners can take advantage of a temporary compliance option, including 
an averaging, banking and trading component, beginning in June 2006 and 
lasting through 2009, with credit given for early compliance before 
June 2006. Under this option, up to 20 percent of highway diesel fuel 
may continue to be produced at the existing 500 ppm sulfur maximum 
standard, though it must be segregated from 15 ppm fuel in the 
distribution system, and may only be used in pre-2007 model year heavy-
duty vehicles. We are providing additional hardship provisions for 
small refiners to minimize their economic burden in complying with the 
15 ppm sulfur standard and giving additional flexibility to refiners 
subject to the Geographic Phase-in Area (GPA) provisions of the Tier 2 
gasoline sulfur program, which will allow them the option of staggering 
their gasoline and diesel investments. Finally, we are adopting a 
general hardship provision for which any refiner may apply on a case-
by-case basis under certain conditions. These hardship provisions, 
coupled with the temporary compliance option, will provide a ``safety 
valve'' allowing up to 25 percent of highway diesel fuel produced to 
remain at 500 ppm for these transitional years to effectively address 
the concerns over highway diesel fuel supply.
    It should be noted that the requirements of the fuel program 
described below apply to refiners and importers only.158 We 
are not adopting any retailer availability requirements

[[Page 5065]]

with these provisions. In other words, we are not requiring that diesel 
retailers sell the 15 ppm fuel. Rather, retailers may sell 15 ppm 
sulfur diesel fuel, 500 ppm sulfur diesel fuel, or both. We believe the 
program being adopted today for refiners and importers will ensure that 
adequate supplies of low sulfur diesel fuel are available throughout 
the nation. The voluntary compliance and hardship provisions have been 
designed with a required level of production that we believe will 
ensure that 15 ppm fuel is distributed widely through pipelines and at 
terminals throughout the country without the need for a retailer 
availability requirement. Our analysis supporting the design of these 
provisions can be found in Chapter IV of the RIA for today's action.
---------------------------------------------------------------------------

    \158\ As described above, distributors and retailers marketing 
low sulfur diesel fuel have deadlines for compliance with the sulfur 
standards, as well as other requirements such as pump labeling. 
Section VII of today's action provides further details on the 
downstream requirements for distributors and retailers.
---------------------------------------------------------------------------

2. Temporary Compliance Option for Refiners and Importers
    We believe there are several advantages to allowing some 
flexibility in the early years of the program such that not all of the 
highway diesel fuel pool must be converted to low sulfur diesel fuel at 
one time. First, some commenters expressed concerns over adequate 
supplies of highway diesel fuel if the entire pool converted to low 
sulfur diesel fuel in 2006, because they believe some refiners might 
produce less total highway diesel fuel volume or choose to leave the 
highway diesel fuel market altogether. Allowing the temporary 
compliance option lowers this concern because a portion of the highway 
diesel pool can remain at the current 500 ppm sulfur standard, if 
necessary, providing additional time for the market to adjust. This 
portion of the highway diesel pool that refiners choose to delay will 
likely be the portion that is more costly for them to desulfurize and, 
thus, most likely to raise concerns with respect to shortfalls. Second, 
a temporary compliance option can benefit refiners by reducing the fuel 
production costs in the early years of the program, because refiners 
are able to spread out their capital investments. The option also 
benefits refiners by spreading out the industry-wide demand for 
engineering and construction resources over several years, and also by 
allowing more time between the gasoline sulfur and diesel sulfur 
compliance dates. Third, refiners that are able to delay investment 
could attain lower costs for such equipment as technology improvements 
are realized during that time and as refiners see how well the 
desulfurization technologies achieve the 15 ppm sulfur standard.
    The primary emissions benefits of low sulfur highway diesel fuel 
are the emissions reductions that will occur over time as new vehicles 
designed to meet the emission standards adopted today are introduced 
into the vehicle fleet. Consequently, in the NPRM we requested comment 
on several options that would allow refiners and importers to phase in 
the production of low sulfur highway diesel fuel. With today's action, 
we are adopting a temporary compliance option for refiners and 
importers that will allow them to produce less than 100 percent of 
their highway diesel fuel at the 15 ppm sulfur level. Refiners and 
importers may choose to participate in the compliance option on a 
refinery-by-refinery basis. A refiner must demonstrate compliance with 
the compliance option on an annual basis. Refiners with special 
financial hardships have additional flexibility provisions, which are 
described further in Section IV.C.
    We believe today's temporary compliance option in combination with 
the hardship provisions discussed in Section IV.C. has the potential to 
provide flexibility to more than half of all U.S. refineries by 
allowing up to 25 percent159 of the highway diesel fuel 
volume in the country to continue to be produced at the current sulfur 
level of 500 ppm. We estimate that refiners will be able to save as 
much as $1.7 billion over the duration of the optional compliance 
program compared to the proposed requirement that all highway diesel 
fuel comply with 15 ppm sulfur in 2006. Much, but not all, of this 
potential savings will be offset by increased costs in the distribution 
system. We project that in total a small overall savings should result 
from refiners taking advantage of the temporary compliance option.
---------------------------------------------------------------------------

    \159\ Up to 5 percent of which is small refiner production.
---------------------------------------------------------------------------

    Under the temporary compliance option finalized today, a refinery 
may produce up to 20 percent of its total highway diesel fuel at the 
existing highway diesel fuel sulfur standard of 500 ppm, determined on 
an annual basis. The remaining 80 percent of the highway diesel fuel 
produced at that refinery during the year must meet a sulfur standard 
of 15 ppm.160 As part of this temporary compliance option, a 
PADD-based averaging, banking, and trading (ABT) program will be 
available. Figure IV-1 presents the five PADDs into which the United 
States is divided.161 For example, a refinery could produce 
more than 80 percent of its highway diesel fuel as low sulfur diesel 
fuel and generate credits based on the volume of highway diesel fuel 
produced at 15 ppm that exceeded the 80 percent requirement. Within 
that same PADD (within the limits noted below for California, Alaska, 
Hawaii, and any state with an EPA-approved waiver from the federal 
program), these credits may be averaged with another refinery owned by 
that refiner, banked for use in future years, or sold to another 
refinery.
---------------------------------------------------------------------------

    \160\ We are aware that today there are refiners that produce 
one grade of diesel fuel for both highway and off-highway purposes, 
where dye is added by parties downstream if it is to be sold as off-
highway diesel fuel. To the extent possible, we do not want to 
interfere with this practice. Consequently, for purposes of 
determining compliance with these optional requirements, a refiner 
producing all 15 ppm fuel may include the entire volume it produces 
in the calculation. Furthermore, a refiner producing all 500 ppm 
fuel must count any diesel fuel produced with a sulfur content of 
500 ppm or less unless it has been dyed by the refiner to be used as 
nonroad diesel fuel. A refiner would only include kerosene in its 
volume calculation if the kerosene is less than 500 ppm sulfur 
content and the kerosene is blended at the refinery into non-dyed 
fuel with a sulfur content of less than 500 ppm.
    \161\ The Department of Energy divides the United States into 
five Petroleum Administrative Districts for Defense, or PADDs. The 
states encompassed by each of the five PADDs are defined in the Code 
of Federal Regulations at Title 40, Sec. 80.41.
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BILLING CODE 6560-50-P

[[Page 5066]]

[GRAPHIC] [TIFF OMITTED] TR18JA01.004

BILLING CODE 6560-50-C
    Also, a refinery may produce less than 80 percent of its highway 
diesel fuel at the 15 ppm sulfur level, as long as it obtains enough 
credits from another refinery within the PADD to offset the volume of 
500 ppm sulfur fuel produced that exceeded the 20 percent of highway 
diesel fuel allowed to be produced at the 500 ppm sulfur level. As 
noted above, any credit trading will be limited to those refineries 
within the same PADD (within the limits noted below for California, 
Alaska, Hawaii, and any state with an EPA-approved waiver from the 
federal program). This restriction is necessary to limit the 
possibility that any area of the country is dominated by refineries 
complying via purchases of credits and, thus, producing a small volume 
of low sulfur diesel fuel, which could lead to concerns that the low 
sulfur diesel fuel would not be sufficiently available throughout the 
country.
    Based on an extensive analysis which incorporates the hardship 
provisions and GPA refiner provisions discussed in Section IV.B. and 
C., we have chosen a level of 80 percent to have confidence that there 
will be widespread availability of 15 ppm fuel throughout the United 
States. Given the requirements of today's program, we believe that all 
pipelines are likely to carry the 15 ppm fuel. Pipelines that may be 
able to carry only one grade of highway diesel fuel are likely to carry 
15 ppm as the majority diesel fuel in the market.162 Those 
that are able to carry more than one grade of highway diesel fuel will 
facilitate the distribution of the remaining 500 ppm fuel. In addition, 
to ensure widespread availability of low sulfur diesel fuel throughout 
the nation, we have found it necessary to set the 15 ppm production 
threshold high enough so that there is a sufficient geographic 
scattering of refineries producing low sulfur diesel fuel around the 
country. At a lower threshold, there could be isolated regions of the 
country where 15 ppm fuel would not be available in sufficient 
quantities.
---------------------------------------------------------------------------

    \162\ Today, many pipelines carry only one grade of distillate 
(e.g., only 500 ppm sulfur high diesel fuel) rather than both 500 
ppm sulfur highway fuel and off-highway fuel which has even higher 
levels of sulfur (e.g., on the order of 3,000 ppm).
---------------------------------------------------------------------------

    We have analyzed the refinery/pipeline distribution system in the 
United States in the context of the small refiner hardship and other 
provisions of the rule and believe a 80 percent temporary compliance 
option level for 15 ppm is necessary to achieve widespread availability 
and avoid shortages in specific areas. At levels below an 80 percent 
level, we would have concerns over whether 15 ppm sulfur diesel fuel 
would be the primary highway diesel fuel distributed through pipelines 
and whether the low sulfur diesel fuel would be available to all areas 
of the country in sufficient quantities. The reader is directed to 
Chapter IV of the RIA for today's action for our complete analysis 
supporting the development of the temporary compliance option.
    While we have set the minimum requirement under the compliance 
option at 80 percent, we believe most refineries will focus on 
production of one grade or the other. We expect that certain refineries 
will find it more economically advantageous to install the necessary 
equipment to produce all of their highway diesel fuel at the 15 ppm 
sulfur level and generate credits. Conversely, other refineries may 
find it advantageous to continue producing all of their highway diesel 
fuel at the 500 ppm sulfur fuel through the period of the compliance 
option, by obtaining credits to demonstrate compliance. This will 
provide additional time for those refiners that have not converted to 
low sulfur fuel. This will allow refiners to spread out their capital 
investments and provide more time to arrange for engineering and 
construction resources. In addition, the refiners that are able to 
delay investment could attain lower costs for such equipment as 
technology improvements are realized during that time and as refiners 
see how well the range of desulfurization technologies works to achieve 
the 15 ppm sulfur standard.
    Foreign refiners may choose to participate in the temporary 
compliance option. For purposes of determining compliance with the low 
sulfur diesel requirements, foreign refiners must demonstrate 
compliance based on the amount of highway diesel fuel they import into 
the United States. Therefore, a given foreign refiner must demonstrate 
that at least 80 percent of the highway diesel fuel it imported into 
each PADD

[[Page 5067]]

meets a 15 ppm sulfur level, or show that it has enough credits from 
other refiners in the PADD into which it imported the fuel to cover the 
volume of fuel below the 80 percent requirement. Foreign refineries may 
also generate credits if they exceed the 80 percent requirement in a 
given PADD, and may sell those credits within the same PADD. A foreign 
refiner may also choose to not participate in the temporary compliance 
option and, as described below, let the fuel importer be the party 
which demonstrates compliance.
    Importers of highway diesel fuel (i.e., companies that import fuel 
but are not solely refiners) may also participate in the temporary 
compliance option. Importers must demonstrate that at least 80 percent 
of the highway diesel fuel imported into each PADD (within the limits 
noted below for California, Alaska, Hawaii, and any state with an EPA-
approved waiver from the federal program) meets a 15 ppm sulfur level, 
or show that they have enough credits from other refiners in the PADD 
into which the fuel is imported to cover the volume of fuel below the 
80 percent requirement. Importers may also generate credits if they 
exceed the 80 percent requirement in a given PADD. Importers that 
import highway diesel fuel from foreign refiners that are participating 
in the temporary compliance option must exclude the volume of fuel 
purchased from those refiners in their compliance calculations or 
credit generation calculations.
    Because we expect most refineries to choose to produce fuel either 
all at the 15 ppm sulfur level or all at the 500 ppm sulfur level, 
credits will be generated by some refiners and desired by others. Thus, 
the ABT program will play an important part in achieving overall 
compliance. The details of the ABT program are described below.
a. Generating Credits
    Beginning on June 1, 2006 and continuing through December 31, 2009, 
refineries and importers may generate credits based on the volume of 
low sulfur diesel fuel produced above the required percentage (i.e., 80 
percent). One credit will be generated for every gallon of highway 
diesel fuel produced at 15 ppm sulfur that exceeds the 80 percent 
requirement. Credits will be calculated on a calendar-year basis. For 
example, if a refinery produces 10 million gallons of highway diesel 
fuel in 2007, it must produce 80 percent of its highway diesel volume 
(8 million gallons) as low sulfur during 2007. If the refinery actually 
produces 100 percent of its highway diesel fuel as low sulfur during 
2007, it can generate credits based on the volume of the ``extra'' 20 
percent of low sulfur fuel it produced above the required minimal 
percentage--that is, two million gallons of credits. Because the 
requirements for low sulfur fuel begin in the middle of 2006, a 
refinery will generate credits in 2006 based on the volume of low 
sulfur fuel produced beginning June 1, 2006 that exceeds 80 percent of 
the highway diesel fuel produced at its facility between June 1, 2006 
and December 31, 2006. Once credits are generated by a refinery, they 
may be used by the refinery for averaging purposes with other 
refineries owned by the same refiner, traded to another refinery, or 
banked for use in future calendar year averaging or trading. Credits 
may only be used in the PADD in which they are generated, with the 
further limitations on credit generation and use in PADD V noted below 
for California, Alaska, and Hawaii.
    Refineries may no longer generate credits after December 31, 2009. 
Beginning January 1, 2010, every refinery must either comply with the 
low sulfur diesel fuel requirements by (1) producing 100 percent of its 
highway diesel fuel at the 15 ppm sulfur level or (2) by using credits 
through May 31, 2010 to demonstrate compliance with the 100 percent 
requirement, provided that banked credits are available to the refinery 
(described in more detail below). Starting June 1, 2010, all refineries 
must produce 100 percent of their highway diesel fuel as low sulfur 
fuel (without the use of credits).
    Finally, early credits, or credits from low sulfur fuel produced at 
a refinery prior to June 1, 2006, may be generated, but only under 
limited circumstances. Unlike in the Tier 2 program, where significant 
emission benefits accrued with the early introduction of low sulfur 
gasoline, very little emission benefit (only a small reduction in 
sulfate PM emissions from the in-use fleet) will result from the early 
introduction of 15 ppm diesel fuel. Consequently, the main purpose in 
allowing early credits under the diesel program is to smooth program 
implementation beginning June 1, 2006, by allowing a pool of credits to 
be available upon program startup. By allowing the generation of early 
credits, both purchasers and sellers of credits can have confidence in 
the legitimacy of the credits traded, which, in turn, allows for the 
purchaser to have increased confidence in their ability to rely on the 
ABT program for compliance. Consequently, beginning June 1, 2005 we 
will allow refineries to generate credits for any volume of highway 
diesel fuel produced which meets the 15 ppm cap. Any refiner that 
chooses to do so may bank these credits for later use during the 
compliance option years, or may trade them to other refineries within 
the same PADD for use during the compliance option years. The one 
restriction placed on the generation of these credits is that refiners 
will have to demonstrate that the 15 ppm fuel produced early is 
segregated in the distribution system and not commingled with current 
500 ppm sulfur fuel. Only that volume that the refiner verifies was 
actually sold as 15 ppm fuel at retail or into centrally-fueled fleets 
will be eligible for early credits.
    Providing refiners with an incentive to produce diesel fuel 
complying with the 15 ppm cap earlier than required will not only 
instill confidence in the ABT program under the temporary compliance 
option, but will also provide both refiners and the distribution system 
the opportunity to gain valuable experience prior to the start of the 
program with producing and distributing fuel meeting the 15 ppm cap. We 
believe that allowing early credit generation for one year prior to the 
start of the program will provide the opportunity for the generation of 
sufficient early credits to provide refiners with the program 
implementation flexibility they will need. If we allowed early credits 
to be generated in this manner for a longer time period, we are 
concerned that the significant amounts of early credits that could be 
generated could compromise availability of 15 ppm fuel at the startup 
of the program. Use of these credits after June 1, 2006 could affect 
the availability of low sulfur highway diesel fuel across the country 
when the 2007 model year heavy-duty engines are introduced in the 
market, because the amount of 500 ppm fuel could significantly exceed 
the 20 percent threshold allowed under our temporary compliance option.
    The only situation in which we will allow for the generation of 
credits prior to June 1, 2005 is if a refiner demonstrates that the 
fuel will be used in vehicles certified to meet the 2007 particulate 
matter standard being adopted today for heavy-duty engines (0.01 g/bhp-
hr) or in vehicles with retrofit technologies that achieve emission 
levels equivalent to the 2007 NOX or PM standard verified as 
part of a retrofit program administered by EPA or a state. (Refer to 
section I.C.7 for more discussion on retrofit programs.) Under this 
situation, we will have confidence that emission benefits are in fact 
accruing early, along with the fuel sulfur credits. The early credit 
provision of this fuel program will complement the provisions that 
encourage the

[[Page 5068]]

introduction of cleaner vehicles earlier than the 2007 model year, as 
discussed in Section III.D.
b. Using Credits
    If a refinery does not meet the 80 percent minimum requirement for 
low sulfur highway diesel fuel with actual production at that refinery, 
the refinery will be able to use credits to demonstrate compliance with 
the 80 percent requirement. The use of credits is limited to credits 
generated by refineries within the same PADD (within the limits noted 
below for California, Alaska, Hawaii, and any state with an EPA-
approved waiver from the federal program). Under the temporary 
compliance option, for every gallon of 500 ppm sulfur fuel produced by 
a refinery that exceeds the maximum allowed limit of 20 percent, the 
refinery must obtain one credit from another refinery within the same 
PADD or use banked credits (that were generated within the same PADD).
    Although credits will not officially exist until the end of the 
calendar year (based on the generating refinery's actual low sulfur 
fuel production for that calendar year), refineries may contract with 
each other for credit sales prior to the end of the year, based on 
anticipated production. The actual trading of credits will not take 
place until the end of the year. All credit transfer transactions will 
have to be concluded by the last day of February after the close of the 
annual compliance period and each refinery must submit documentation 
(as described in Section VII.E.) demonstrating compliance with the 
appropriate volume of low sulfur highway diesel fuel. For example, a 
refinery that wishes to purchase credits from another refinery to 
comply with the 2007 required percentage of low sulfur fuel can do so 
based on the generating refinery's projections of low sulfur fuel 
production. By the end of February 2008, both the credit-purchasing 
refinery and the credit-selling refinery must reconcile the validity of 
the credits, and demonstrate compliance with the 80 percent 
requirement. As noted earlier, at the beginning of the program, the 
initial compliance period will begin on June 1, 2006 and end on 
December 31, 2006. For this initial period, refineries must submit 
documentation, by February 28, 2007, demonstrating compliance with the 
appropriate levels of low sulfur highway diesel fuel for the period 
between June 1, 2006 and December 31, 2006.
    Because there could be situations where a refinery planning to use 
credits to comply with the minimum percentage of fuel required comes up 
short at the end of the year, we are adopting provisions that allow a 
limited amount of carryover, or ``credit deficits.'' A refinery that 
does not meet the required percentage of low sulfur fuel production in 
a given year will be allowed to carry forward a credit deficit for one 
year, as long as the deficit does not exceed five percent of its annual 
highway diesel fuel production. However, the refinery will have to make 
up the credit deficit and come into compliance with the required low 
sulfur production percentage in the next calendar year, or the refinery 
will be in violation of the program requirements. This provision is 
intended to give some relief to refineries faced with an unexpected 
shutdown or that otherwise are unable to obtain sufficient credits to 
meet the required percentage of low sulfur fuel production.
    With regard to credit trading, any person can act as a broker in 
facilitating credit transactions, whether or not such person is a 
refiner and/or importer, so long as the title to the credits are 
transferred directly from the refinery generating the credits to the 
refinery purchasing the credits. Whether credits are transferred 
directly from the generating refinery to the purchasing refinery, or 
through a broker, the refinery purchasing the credits should have 
sufficient information to fully assess the likelihood that credits are 
valid. Any credits that are traded to another refinery may, in turn, be 
traded to another refinery; however, the credits cannot be traded more 
than twice. We believe this provision is necessary because repeated 
transfers of credits would significantly reduce our ability to verify 
the validity of credits.
c. How Long Will Credits Last?
    The goal of the ABT provisions is to provide additional flexibility 
to refiners in the early years of the low sulfur diesel fuel program. 
After the first few years of the program, there will be a significantly 
greater proportion of after-treatment-equipped vehicles in the fleet. 
It will be important to ensure a full transition to the new low sulfur 
fuel to prevent misfueling of those vehicles and preserve the 
environmental benefits of the program. Therefore, the ability of 
refineries to generate credits will end on December 31, 2009. 
Refineries will be allowed to use any available banked credits, 
including early credits, for fuel produced through May 31, 2010. Any 
remaining credits not used for the compliance period until May 31, 2010 
will expire. Beginning June 1, 2010, all refineries must produce 100 
percent of their highway diesel fuel at the 15 ppm sulfur level without 
the use of credits, and the ABT program will end.
d. Additional Limitations on Credit Trading for Some States
    At this time we are adopting a low sulfur highway diesel fuel 
program that will apply throughout the United States, with trading of 
credits limited to those refineries located within the same PADD. 
Although we are adopting a diesel fuel program that currently will 
apply nationwide, it is possible that the State of California, or some 
other state, may adopt in the future a different highway diesel fuel 
program than that adopted today.163 To assure that adequate 
supplies of low sulfur diesel fuel will be available throughout all 
regions of the country, we are adopting provisions that do not allow 
refineries located in states with a state-approved 15 ppm highway 
diesel sulfur program to participate in the credit program. In other 
words, credit trading is limited only to those refineries complying 
with the federal program. For example, without such provisions, if 
California were to adopt its own state program requiring the production 
of 15 ppm diesel fuel, we are concerned that it might be possible for 
California refineries to generate enough credits such that areas 
outside of California in PADD V are dominated by the production of 500 
ppm sulfur diesel fuel, with little or no 15 ppm fuel available. This 
would be problematic for the model year 2007 and later heavy-duty 
engines designed to be operated on low sulfur fuel. The reader is 
directed to Chapter IV of the RIA for today's action for our complete 
analysis supporting the development of the temporary compliance option.
---------------------------------------------------------------------------

    \163\ See Section IV.F. for a discussion of preemption of state 
diesel sulfur requirements.
---------------------------------------------------------------------------

    As discussed in Section IV.F. of this preamble, the State of 
Alaska, which is a part of PADD V, will have the opportunity to 
develop, and submit to us for approval, an alternative transition plan 
for implementing the low sulfur highway diesel fuel program. Such a 
plan will allow Alaska to develop a transition program tailored to its 
isolated market. If, for some reason, Alaska does not submit an 
alternative plan, or we do not approve the plan submitted by Alaska, 
then the federal program described in today's action will apply. In the 
event we do not approve an alternative plan for Alaska, based on our 
analysis of the likely response of refineries in Alaska to the 
temporary compliance option and because its fuel distribution system is 
essentially isolated from the rest of PADD V, we are

[[Page 5069]]

concerned that all of the fuel offered for sale in Alaska could be 500 
ppm sulfur fuel if refineries in Alaska were allowed to purchase 
credits from other PADD V refineries. For this reason, under today's 
program, refineries in Alaska will be allowed to generate credits as 
described earlier. However, they may only sell credits to, or purchase 
credits from, other refineries in or importers of fuel to Alaska. We 
believe this will provide assurance that low sulfur highway diesel fuel 
will be sufficiently available in Alaska and will also reduce the 
chance that credits from Alaska will result in significantly less low 
sulfur diesel fuel in PADD V areas outside of Alaska. Again, these 
default provisions of the national program will only be effective in 
the event that we do not approve an alternate transition plan for 
Alaska.
    Hawaii is in a similar situation to Alaska with regard to fuel 
distribution. Hawaii, which is part of PADD V, is an isolated market 
and we have similar concerns with regard to whether low sulfur diesel 
fuel would be available in Hawaii if the two refineries currently 
operating were able to purchase credits from other PADD V refineries 
and produce all 500 ppm sulfur fuel. For this reason, under today's 
program, the refineries in Hawaii will be allowed to generate credits 
as described earlier. However, they may only sell credits to, or 
purchase credits from, other refineries in or importers of fuel to 
Hawaii. We believe this will ensure that low sulfur highway diesel fuel 
will be available in Hawaii.
3. What Information Must Refiners/Importers Submit to Us?
    To ensure a smooth transition to the program and to evaluate 
compliance once the program has begun, we are requiring refiners and 
importers to submit a variety of information to us. Section VII.E of 
this document and the regulatory language for today's action provide 
detailed description of the information that must be submitted and the 
dates when such submittals are due.164
---------------------------------------------------------------------------

    \164\ As described in Sections IV.B., IV.C. and VII.E., small 
refiners and GPA refiners have special supplementary reporting 
requirements relating to the optional program they are participating 
in.
---------------------------------------------------------------------------

    First, refiners and importers that currently or in 2006 expect to 
produce or supply highway diesel fuel are required to register with us 
by December 31, 2001. This will inform us on the universe of refiners 
that we expect to participate in the highway diesel market once the 
program begins.
    Second, to help facilitate the market for credit trading under the 
temporary compliance option, any refiner or importer planning to 
produce or import highway diesel in 2006, is required to submit to us 
an annual pre-compliance report. Refiners and importers are required to 
submit these annual pre-compliance reports from 2003 through 2005. 
These reports must contain estimates of the volumes of 15 ppm sulfur 
fuel and 500 ppm sulfur fuel that will be produced at each refinery, 
and, for those refineries planning to participate in the trading 
program, a projection of how many credits will be generated or must be 
used by each refinery. These pre-compliance reports must also contain 
information outlining each refinery's timeline for compliance and 
provide information regarding engineering plans (e.g., design and 
construction), the status of obtaining any necessary permits, and 
capital commitments for making the necessary modifications to produce 
low sulfur highway diesel fuel. Based on the information submitted by 
refiners and importers, we plan to issue an annual report that 
summarizes, in a way that protects the confidentiality of individual 
refiners and importers, the information contained in the pre-compliance 
reports. Our annual report will provide information, summarized and 
aggregated on a PADD basis, describing the volumes of 15 ppm and 500 
ppm highway diesel planned to be produced, and estimates of the number 
of credits that refineries expect to generate or use. We believe this 
information will be important to refiners as they make plans for 
complying with the temporary compliance option. For example, this 
information will be useful in giving refiners a better indication of 
the potential market for credits and availability of credits in their 
PADD. To prevent the release of confidential information, our annual 
report will not contain any information on individual refinery 
compliance plans.
    Third, refiners and importers are required to submit annual 
compliance reports that demonstrate compliance with the requirements of 
this final rule. The first annual compliance report is due by the end 
of February 2007 (for the period of June 1, 2006 through December 31, 
2006) and is required annually through February 2011. The reports must 
show, on a refinery basis, the volumes of 15 ppm and 500 ppm sulfur 
highway diesel fuel produced at each refinery during the compliance 
period, the number of credits used (or generated) at each refinery to 
demonstrate compliance with the 80 percent requirement for low sulfur 
diesel fuel, and the sources of the credits used. The information 
submitted in the annual compliance reports must be segregated by PADD.
4. Impacts of the Highway Diesel Fuel Program
    Based on analyses we have performed, as described in more detail 
below, we believe the temporary compliance provisions contained in 
today's final rule will assure adequate supplies of highway diesel 
fuel, will provide flexibility for refiners, and should result in lower 
costs for both refiners and consumers. In addition, we believe the 
temporary compliance provisions as adopted today will ensure sufficient 
availability of low sulfur highway diesel fuel to new vehicle owners 
who need it without the need for a retailer availability requirement, 
and should not lead to significant levels of misfueling and the 
associated loss of emission benefits. We have analyzed each of these 
issues in developing the final fuel program. A summary of our analyses 
and the conclusions we have drawn are discussed below. A detailed 
description of these analyses are contained in the RIA for today's 
action. In addition, a complete list of the comments related to a 
possible phase-in program and our response to those comments is 
included in the Response to Comments document for this final rule.
a. Ensures Adequate Supplies of Highway Diesel Fuel
    We received several comments on the NPRM fuel program that 
suggested there would be a shortfall in the amount of highway diesel 
supply if all of the highway diesel fuel were required to meet a 15 ppm 
sulfur limit beginning in 2006. As described later in Section V.C., in 
response to these comments we analyzed the capability of the entire 
diesel fuel refining industry in the U.S. to adjust to the low sulfur 
fuel requirements. Based on this analysis, we believe that supplies of 
highway diesel fuel will be sufficient even if all highway diesel fuel 
were required to comply with the 15 ppm standard in 2006. The temporary 
compliance option included in today's rule is intended as a ``safety 
valve'' that, along with the hardship provisions discussed in Section 
IV.C.,will further help to ensure adequate supplies of highway diesel 
fuel beginning in 2006.
    In performing the analysis of diesel fuel supply, we examined all 
diesel fuel refiners (including those that currently make only off-
highway diesel fuel but not highway diesel fuel) to assess the 
likelihood of their investing in the production of 15 ppm highway 
diesel

[[Page 5070]]

fuel. Using a refinery cost model, we made projections of the likely 
response by refineries to today's low sulfur requirements by estimating 
the cost for each refinery to produce low sulfur diesel fuel. The 
results of our analysis show that the overall supply of highway diesel 
fuel will continue to be adequate to meet market demands as refiners 
are required to start producing low sulfur highway diesel fuel. Most 
refineries that currently produce highway diesel fuel will produce 
about the same volume of low sulfur diesel fuel once the program takes 
effect. However, several refineries could economically expand their 
current highway diesel fuel production by shifting some of their off-
highway production today, and a few others currently producing only 
off-highway diesel fuel could economically shift to some highway diesel 
production. Consequently, our analysis indicates that there is ample 
capability in the refining industry to continue to economically supply 
sufficient quantities of highway diesel fuel when today's program goes 
into effect. For a fuller discussion of this analysis, see Section V of 
this preamble and Chapter IV of the RIA.
    If any potential for highway diesel fuel shortfalls exists by 
requiring all fuel to meet 15 ppm sulfur in 2006, as CRA's analysis 
suggests, we believe that allowing some continued supply of 500 ppm, as 
we are doing under the temporary compliance option and hardship 
provisions contained in today's action, addresses this concern. Since 
the final rule allows some transition period before the entire highway 
diesel pool is required to meet the 15 ppm sulfur standard, some 
refiners will not need to change their current operations and will be 
able to continue producing 500 ppm fuel during these years. Those 
refiners that delay production of low sulfur diesel fuel until the 
later years of the program will tend to be the refiners with the 
highest cost to comply and, thus, refiners that would otherwise have 
the greatest tendency not to invest and thereby impact supply. Refiners 
that begin producing low sulfur diesel fuel in the later years of the 
program will also be able to take advantage of ongoing improvements in 
desulfurization technology. Together, these factors will help avoid or 
reduce any potential losses in highway diesel fuel production when the 
program requires full compliance with low sulfur diesel fuel.
b. Ensures Widespread Availability of Low Sulfur Diesel Fuel
    A major concern we noted in the NPRM regarding a fuel phase-in 
program was ensuring the widespread availability of low sulfur diesel 
fuel. Without an assurance of widespread availability, there would be 
concerns whether the 2007 and later model year heavy-duty vehicles that 
were designed to operate on low sulfur fuel would be able to purchase 
it in all parts of the country. If such vehicles were fueled with 500 
ppm diesel fuel, the emission control systems could be irreversibly 
damaged and any benefit of the new emission standards could be 
eliminated (see Section III.F. above). Therefore, in setting the 
requirements for the temporary compliance option, we have analyzed the 
likelihood that fuel will be widely available so that 2007 and later 
model year heavy-duty vehicles will be able to find low sulfur fuel in 
all local markets across the country. To achieve this goal, we believe 
there need to be assurances that refineries producing 15 ppm fuel are 
sufficiently scattered throughout each of the PADDs and that most 
pipelines will carry 15 ppm fuel (either as the only highway diesel 
fuel or in addition to 500 ppm highway fuel).
    In determining what fraction of highway diesel fuel would need to 
be low sulfur under the temporary compliance option provision, taking 
into account the potential impact of the hardship provisions, we used a 
refinery cost model to estimate the costs of producing 15 ppm fuel for 
all refineries. We then assumed that the refineries with the lowest 
costs would convert to 15 ppm fuel and assumed the other refineries 
would purchase credits and continue producing 500 ppm fuel through the 
compliance option period. We then overlaid the information on which 
refineries were estimated to be producing 15 ppm fuel with the highway 
diesel fuel distribution system in the United States. We examined 
different levels for the temporary compliance option beginning as low 
as 20 percent and ranging as high as 90 percent. The results of the 
analysis show that at temporary compliance option levels for 15 ppm 
below 80 percent, there are local regions of the country where we 
believe there would likely be shortages of low sulfur diesel fuel. The 
areas where we believe there would be shortages are either (1) served 
by pipelines that we believe would not carry 15 ppm fuel, because the 
refineries serving those pipelines are projected to produce primarily 
500 ppm; or (2) dominated by refineries we believe would continue 
producing 500 ppm fuel under the temporary compliance option and are 
not currently capable of receiving significant supplies of a second 
grade of diesel fuel through other reasonable means. At the 80 percent 
level, we believe that all pipelines will carry low sulfur diesel fuel, 
since there are a sufficient number of refineries scattered across the 
country producing low sulfur diesel fuel and at sufficient volumes for 
pipelines to choose to carry it. We also believe that the program 
ensures that low sulfur diesel fuel will be sufficiently available to 
retail outlets at a reasonable cost either at a local terminal or by 
trucking the fuel a limited distance.
    As noted earlier, we are not adopting any retailer availability 
requirements with today's fuel program. Given the amount of low sulfur 
diesel fuel required under today's temporary compliance option, we 
believe the distribution system will make low sulfur diesel fuel widely 
available without any requirements on retail outlets to supply low 
sulfur diesel fuel.
c. Provides Lower Costs to Refineries
    One benefit of the temporary compliance option being adopted today 
is that a significant number of refiners will have the ability to delay 
the date when they convert their highway diesel fuel production to 15 
ppm, allowing the refining industry to stretch out its engineering and 
construction resources. Given the flexibilities being adopted today, we 
believe that many large refineries, and other refineries for which 
diesel desulfurization is least expensive, will make the commitment to 
convert their entire highway diesel pool to 15 ppm sulfur in 2006 and 
sell credits to other refineries that will continue to produce all of 
their fuel at the 500 ppm sulfur level. Using a refinery cost model to 
estimate how refineries will respond to the temporary compliance option 
requirements, we believe that more than half of the refineries will 
delay capital investment by buying credits and continue producing 500 
ppm sulfur diesel fuel under the temporary compliance option and small 
refiner hardship provisions. We estimate that refiners will be able to 
save as much as $1.7 billion over the transition period compared to a 
requirement that all highway diesel fuel comply with 15 ppm sulfur in 
2006. As noted earlier, much of this potential savings will be offset 
by increased costs in the distribution system. Nevertheless, we project 
that in total, an overall savings of approximately $0.65 billion could 
result.
d. Misfueling Concerns Should Be Minimized
    By allowing a 500 ppm and 15 ppm sulfur highway diesel fuels to be 
in the

[[Page 5071]]

market at the same time, there is the possibility that model year 2007 
and later heavy-duty vehicles will be misfueled with 500 ppm sulfur 
fuel, either accidentally or intentionally. As discussed above, if such 
vehicles are fueled with 500 ppm diesel fuel, the emission control 
systems could be irreversibly damaged and any benefit of the new 
emission standards could be eliminated. To minimize the possibility of 
misfueling, we are adopting labeling requirements that apply to both 
retail stations and vehicle manufacturers. Under these provisions, 
labels will be applied at the diesel fuel pumps at retail stations and 
at the fuel tank inlet on the vehicle. The labels must indicate that 
only 15 ppm sulfur highway diesel fuel may be used in 2007 and later 
model year heavy-duty vehicles. The labeling requirements for fuel 
pumps and vehicles are described in detail in Sections VII.C. and 
VI.G., respectively.
    Given the program being adopted today, we believe that intentional 
misfueling will not be a serious problem. The main incentive vehicle 
owners may have for using 500 ppm sulfur fuel would likely be cost 
savings. In general, producing 500 ppm sulfur should be cheaper than 
producing 15 ppm fuel. However, given the requirements adopted today, 
we believe there should not be a large cost differential between the 15 
ppm sulfur fuel and the 500 ppm sulfur fuel at retail outlets. Under 
the credit trading program, to produce 500 ppm fuel, most refiners will 
have to purchase credits from other refiners producing 15 ppm fuel, 
increasing the cost of the 500 ppm fuel, while decreasing the cost of 
the 15 ppm fuel. At the refinery gate, the cost of both fuels should be 
approximately the same. In addition, given the amount of 15 ppm fuel 
required under the temporary compliance option, 15 ppm fuel will be 
distributed through essentially the entire pipeline system. The 
distribution of 500 ppm fuel, on the other hand, will be more limited, 
due to its much lower volume. We expect that the 500 ppm fuel will be 
distributed by truck in the areas nearby refineries producing this fuel 
and through a few major pipelines to a limited number of major fuel 
consuming areas. Overall, the better economies of scale of transporting 
15 ppm fuel should compensate for any additional handling cost due to 
the need to more carefully avoid contamination with higher sulfur 
fuels. For these reasons, we expect the price to consumers of 500 ppm 
sulfur fuel to be generally close to that of 15 ppm sulfur fuel and, 
therefore, there should not be a significant economic incentive to 
misfuel with 500 ppm sulfur fuel. Finally, because vehicle owners will 
likely void the manufacturer's warranty if they misfuel with 500 ppm 
sulfur fuel, they will have an additional incentive not to misfuel. 
Owners of heavy-duty vehicles make significant investments in these 
vehicles and will not want to take the chance of voiding their warranty 
for a relatively small savings in fuel cost.
    In addition to our concern about intentional misfueling, we also 
have some concerns about accidental misfueling during the optional 
compliance program years. This concern is lessened to some extent 
because of the limited amount of 500 ppm sulfur fuel that will be 
available, the short duration of the optional compliance program, the 
knowledgeable owners and operators of trucks and most importantly, the 
labels that will be required on both the vehicle and the fuel pumps. 
Thus, we do not expect either type of misfueling to be a significant 
problem.
e. Summary
    In summary, today's program has been structured to ensure a smooth 
transition to low sulfur highway diesel fuel. We believe this will 
allow the refining industry the ability to spread out capital 
investments and provide more time for the market to transition to the 
low sulfur diesel fuel. This, in turn, will help to mitigate any 
potential for concerns about highway diesel fuel supply shortfalls. We 
also believe the provisions included in the program will continue to 
provide assurance that adequate supplies of low sulfur highway diesel 
fuel will be available throughout the nation for the 2007 and later 
model year heavy-duty vehicles that will require the fuel to comply 
with the emission standards. Moreover, because the flexibilities 
included in the program should reduce the economic impact on refiners, 
we will also expect there to be a reduction in the costs to highway 
diesel fuel users.

B. What Provisions Apply in the Geographic Phase-in Area?

1. What Is the Geographic Phase-in Area and How Was it Established?
    In the low sulfur gasoline rule, we established the GPA provision 
which provides temporarily less stringent standards for gasoline sold 
in certain parts of the West and Alaska (40 CFR 80.215). A map of the 
area is shown in Figure IV-2, below.165 As described in the 
preamble to the low sulfur gasoline final rule, we used two criteria to 
develop and evaluate the GPA approach: (1) Relative environmental need 
and (2) the ability of U.S. refiners and the distribution system to 
provide compliant gasoline.
---------------------------------------------------------------------------

    \165\ Alaska, Colorado, Idaho, Montana, New Mexico, North 
Dakota, Utah, and Wyoming. Note that minor changes to this area are 
currently under consideration. Any such changes subsequent to 
today's rule are intended to be carried over into today's rule as 
well.
---------------------------------------------------------------------------

BILLING CODE 6560-50-P


[[Page 5072]]


[GRAPHIC] [TIFF OMITTED] TR18JA01.005


BILLING CODE 6560-50-C

    In part, we defined the GPA based on the relative difficulty of 
producing or obtaining complying low sulfur gasoline (see preamble to 
the low sulfur gasoline rule at 65 FR 6698, February 10, 2000). The 
refining industry in the GPA is dominated by small capacity, 
geographically-isolated refineries located within that area. As a 
general rule, refineries in this area will (because of their crude oil 
capacity, corporate size, and location) have the most difficult time of 
all refineries nationwide in competing for the engineering and 
construction resources needed to modify their refineries to comply with 
the low sulfur gasoline standards.
    Furthermore, an assessment of gasoline production and use data and 
information on the products pipeline system shows that states and 
counties in the GPA are solely or predominantly dependent on gasoline 
produced by these refineries and have limited or no access to gasoline 
from other parts of the country. Specifically, Department of Energy 
data for 1998 indicate that over 80 percent of the gasoline sold in 
this area is produced by the relatively small refineries located within 
the region. Much of this gasoline is produced by small volume 
refineries that are not owned by small businesses, and are therefore 
not afforded the flexibility of the small refiner provisions described 
in Section IV.C. Providing low sulfur gasoline to these states and 
counties is expected to be more difficult and costly in the near term.
    The temporary gasoline provisions for the GPA apply for three 
years, 2004 through 2006. Since the low sulfur gasoline standards for 
the rest of the country require compliance in January 2006 with a 30 
ppm refinery average standard and an 80 ppm gallon cap, the geographic 
phase-in provides an additional year for refiners to reach those 
standards. This extra year and the somewhat less stringent standards 
during the gasoline phase-in will provide the refining industry the 
opportunity for a more orderly transition to the 30/80 ppm gasoline 
sulfur standards by January 2007.
    The gasoline GPA provision covers all gasoline produced (or 
imported) for use in the GPA166, whether refined within the 
area or distributed within the area via pipeline, barge, truck, or 
rail. Foreign refiners are involved in this program through importers, 
which are the regulated entities.
---------------------------------------------------------------------------

    \166\ As stated in the Tier 2/Gasoline Sulfur final rule (See 
Sec. 80.215(a)(2)), we plan to expand the GPA to include counties 
and tribal lands in states adjacent to the eight core GPA states.
---------------------------------------------------------------------------

2. Highway Diesel Provisions for GPA Refiners
    In response to our proposal, we received many comments from the 
refining industry and others regarding the timing of our proposed 
highway diesel fuel sulfur program. Commenters argued that the proposed 
schedule for diesel sulfur compliance, beginning in mid-2006, would be 
a problem since it directly coincides with the December 2006 gasoline 
sulfur compliance date for the GPA. Some said that the timing of the 
diesel program could effectively negate the benefit to refiners of the 
GPA program since desulfurization investments would need to take place 
during essentially the same time period. This could thus increase the 
difficulty of refiners in this region to raise capital and to engage 
engineering and construction resources. Some also said that an 
extension of the GPA gasoline program would allow more rational 
planning without unduly reducing the air quality benefits of the 
program.
    We agree with many of the commenters in this regard--refineries 
supplying the GPA tend to be disproportionately challenged compared to 
other refiners with respect to capital formation, the availability of 
engineering and construction resources, and the isolated nature of many 
of the markets. Moreover, the introduction of low sulfur highway diesel 
fuel in June 2006 indeed overlaps with the conclusion of the interim 
low sulfur gasoline standards for GPA refiners.
    In consideration of these comments, we believe that it is 
appropriate to grant additional flexibility to refiners that supply 
gasoline to the GPA while also meeting the low sulfur diesel standards. 
Additional flexibility for GPA refiners will allow them to spread out 
their capital investments for producing low sulfur gasoline and highway 
diesel fuel. In light of the above, we are modifying

[[Page 5073]]

the GPA gasoline program while still achieving significant 
environmental benefits. We expect this provision will have little long-
term impact on the environmental benefits of the Tier 2/Gasoline Sulfur 
program, while providing for considerable near-term implementation 
flexibility and improved feasibility of the highway diesel fuel 
program.
    Refiners that produce both gasoline and highway diesel fuel and are 
subject to the GPA gasoline sulfur program may choose to stagger their 
desulfurization investments for the two fuels. Refiners that comply 
with the low sulfur diesel fuel standard by June 1, 2006 for all of 
their highway diesel fuel production may receive a two-year extension 
of their interim GPA gasoline standards for 2006, that is through 
December 31, 2008. In addition to allowing refiners the opportunity to 
spread out their desulfurization investments, we believe this provision 
will encourage the production of 15 ppm diesel fuel by some refiners 
producing fuel for the GPA, which will further help to ensure the new 
fuel is widely available for new vehicles throughout the area. Although 
the GPA gasoline program applies to both refiners and importers, the 
extension of the GPA gasoline program under today's program applies 
only to refiners. This reflects the fact that only refiners have to 
make capital investments to comply with the diesel sulfur standard.
    To receive the two-year extension of the GPA standards, a U.S. 
refinery must by June 1, 2006 produce 100 percent of its highway diesel 
fuel at 15 ppm sulfur (including refineries that supply only a fraction 
of their gasoline production to the GPA). In addition, the refinery 
must maintain a production volume of 15 ppm highway diesel fuel that is 
at least 85 percent of the baseline highway diesel volume that was 
produced at that refinery on average during calendar years 1998 and 
1999. We believe that it is very important that the extension of a GPA 
refinery's interim gasoline sulfur standard be linked to a substantial 
environmental benefit from the production of 15 ppm diesel fuel in 
2006. We have established a minimum volume requirement to prevent the 
extension of the GPA gasoline program from applying in situations where 
a refinery changes its refinery product slate to produce very little 
highway diesel fuel--even though this production is at 15 ppm sulfur. 
We believe the 85 percent level is sufficient to reflect a substantial 
investment in desulfurization technology. At the same time the 85 
percent level should allow for any reasonable variation in production 
of highway diesel fuel that would be expected to occur in typical 
situations between now and 2006, particularly given the continued 
growth of the highway diesel market.
    Similarly, a foreign refinery that meets the same conditions as a 
domestic GPA refiner may also sell gasoline into the GPA that meets a 
less stringent sulfur standard during 2007 and 2008.167 That 
is, a foreign refinery that by June 1, 2006 sells 100 percent of the 
highway diesel fuel it imports into the U.S. as 15 ppm fuel (and that 
maintains the 85 percent of baseline volume requirement) may sell 
somewhat higher-sulfur gasoline into the GPA in 2007 and 2008. The 
actual gasoline sulfur standard during this period, as with domestic 
refiners, would be based on the foreign refinery's gasoline sulfur 
baseline.
---------------------------------------------------------------------------

    \167\ Prior to 2007, foreign refiners can participate in the GPA 
program through importers. Under today's provisions for 2007 and 
2008, importers are not eligible and foreign refiners can 
participate directly as refiners.
---------------------------------------------------------------------------

    If a situation arises where a GPA refinery did not produce highway 
diesel fuel in 1998 or 1999 but later begins to produce 15 ppm diesel 
fuel, use of the GPA gasoline phase-in extension will require case-by-
case EPA approval. In its application for such approval, a refinery 
must show us that the loss of emission reductions will not be 
significant and must propose an appropriate minimum production volume. 
In evaluating such a proposed minimum volume, we may consider, among 
other factors, the typical ratio between highway diesel and gasoline 
production for other refineries in the industry. Again, the reason for 
the two-year extension of the gasoline interim program is to allow the 
GPA refinery to spread out its capital investments while increasing the 
quantity of 15 ppm fuel being produced. We expect that GPA refineries 
using this option will make a substantive capital investment in diesel 
desulfurization and have thus set this minimum 15 ppm diesel production 
volume limit.
    Since refiners participating in this program are required to 
produce 100 percent of their highway diesel at 15 ppm, those that 
choose this option cannot participate in the highway diesel temporary 
compliance option, and, therefore, are not permitted to generate 
credits on the low sulfur diesel fuel that they produce. If, after June 
1, 2006, a foreign refinery is not producing 100 percent of its highway 
diesel fuel imported into the U.S. at 15 ppm sulfur in the required 
volume, it forfeits the two-year extension or any remaining portion of 
the extension of its interim gasoline program.
3. How Do Refiners Apply for an Extension of the GPA Gasoline Program?
    Any refinery that seeks an extension of its GPA gasoline standards 
must apply to us as a part of its registration, due by December 31, 
2001. In this application, the refinery must indicate its intention to 
produce 100 percent of its highway diesel fuel at 15 ppm (and at a 
volume at least 85 percent of the highway diesel fuel volume it 
produced on average during calendar years 1998 and 1999) by June 1, 
2006.
4. Required Reporting for GPA Refiners
    As described in Section VII.E below, refiners that plan to use the 
extension of the GPA gasoline standard must report their plans and 
progress several times over the course of the program. In addition to 
their initial registration and application discussed above, a refinery 
must submit pre-compliance reports in 2003, 2004, and 2005, describing 
its progress toward the capacity to produce 100 percent of its highway 
diesel fuel at 15 ppm sulfur (at a volume at least 85 percent of its 
baseline volume). Then, by July 1, 2006, such a refinery must confirm 
to us that by June 1, 2006 it was producing 100 percent of its highway 
diesel fuel at 15 ppm, at the appropriate volume.168 After 
the diesel sulfur program is underway in 2006, the refinery must 
provide us with annual compliance reports by the end of February of 
2007, 2008, and 2009 (i.e., until after the end of the extended interim 
gasoline sulfur program for GPA refiners on December 31, 2008).
---------------------------------------------------------------------------

    \168\ If the refiner was not producing 15 ppm fuel for all its 
highway diesel production at that refinery by June 1, 2006, the July 
1, 2006 letter must confirm that the refiner is forfeiting the 
``automatic'' two-year extension of that refinery's interim gasoline 
program.
---------------------------------------------------------------------------

C. Hardship Provisions for Qualifying Refiners

    This section describes various provisions for certain qualifying 
refiners, both domestic and foreign, that may face hardship 
circumstances.
1. Hardship Provisions for Qualifying Small Refiners
    In developing our diesel sulfur program, we evaluated the need and 
the ability of refiners to meet the 15 ppm standard as expeditiously as 
possible. This analysis is described in detail in Chapter IV of the 
RIA. As a part of this analysis, we found that while the majority of 
refiners would be able to meet the needed air quality goals in the

[[Page 5074]]

2006 time frame, there would be some refiners that would face 
particularly challenging circumstances which would cause them to have 
more difficulty, in comparison to the industry as a whole, in meeting 
the standards.
    We believe it is feasible and necessary for the vast majority of 
the program to be implemented reasonably quickly to achieve the air 
quality benefits as soon as possible. To do otherwise would be to base 
the time frame of the entire program on the lowest common denominator. 
Thus, we have provided special flexibility provisions for a subset of 
refiners that qualify as ``small refiners,'' which represent about five 
percent of the overall highway diesel volume. As described in more 
detail below, and in the Regulatory Impact Analysis (Chapter VIII of 
the RIA), we concluded that refineries owned by small businesses face 
unique hardship circumstances, compared to larger companies.
a. Qualifying Small Refiners
    The primary reason for special small refiner provisions is that 
small businesses generally lack the resources available to large 
companies which enable the large companies (including those large 
companies that own small volume refineries) to raise capital for 
investing in desulfurization equipment. The small businesses are also 
likely to have more difficulty in securing loans, competing for 
engineering resources, and completing construction of the needed 
desulfurization equipment in time to meet the standards adopted today 
which begin in 2006. In addition, the implementation of the low sulfur 
diesel program will occur in the same general time frame as the 
implementation of the low sulfur gasoline program, since most of those 
small refiners that are covered by the interim standards under the Tier 
2/Gasoline Sulfur program (40 CFR Part 80, Subpart H) are also covered 
by today's diesel fuel sulfur program.
    The emissions benefits of the low sulfur diesel program are needed 
as soon as possible--to allow the implementation of new emission 
reduction requirements on heavy-duty engines and vehicles and, thus, to 
reduce ozone, particulate matter, and other harmful air pollutants. 
Since our analysis showed that small businesses in particular face 
hardship circumstances, we are adopting temporary provisions that will 
provide refineries owned by small businesses additional time to meet 
the ultimate 15 ppm sulfur cap or balance investments of this program 
with those related to the Tier 2/Gasoline Sulfur program. This approach 
allows us to achieve the earliest implementation date for advanced 
technology diesel vehicles (i.e., the 2007 model year) and the needed 
emission reductions they will bring.
    We believe that the temporary flexibilities described below are an 
effective way to begin the broad implementation of the standards as 
expeditiously as is feasible and thereby achieve significant air 
quality benefits in an expeditious manner. This section describes the 
special provisions we are offering small businesses to mitigate the 
impacts of our program on them and generally explains the analysis we 
undertook of those impacts. Please refer to the Response to Comments 
document for a detailed discussion of comments we received on these 
provisions, and to the RIA for a more detailed discussion of our 
analysis of small refiner circumstances.
    As explained in the discussion of our compliance with the 
Regulatory Flexibility Act in Section X.B. and in the Regulatory 
Flexibility Analysis in Chapter VIII of the RIA, we considered the 
impacts of our proposed regulations on small businesses. We have 
historically, as a matter of practice, considered the potential impacts 
of our regulations on small businesses. We believe that the temporary 
flexibilities we are adopting for small refiners contributed to our 
development of a framework to achieve significant environmental 
benefits from lower sulfur diesel in the most expeditious manner that 
is reasonably practicable.
    A large part of the analysis of small business impacts conducted 
for this rulemaking was performed in conjunction with a Small Business 
Advocacy Review (SBAR) Panel we convened, pursuant to the Regulatory 
Flexibility Act as amended by the Small Business Regulatory Enforcement 
Fairness Act of 1996 (SBREFA). In the SBREFA amendments, Congress 
stated that ``uniform Federal regulatory requirements have in numerous 
instances imposed unnecessary and disproportionately burdensome demands 
including legal, accounting, and consulting costs upon small businesses 
. . . with limited resources[,]'' and directed agencies to consider the 
impacts of certain actions on small entities. The final report of the 
Panel is available in the docket. Through the SBREFA process, the Panel 
provided information and recommendations regarding:
     The significant economic impact of the proposed rule on 
small entities;
     Any significant alternatives to the proposed rule which 
would ensure that the objectives of the proposal were accomplished 
while minimizing the economic impact of the proposed rule on small 
entities;
     The projected reporting, recordkeeping, and other 
compliance requirements of the proposed rule; and,
     Other relevant federal rules that may duplicate, overlap, 
or conflict with the proposed rule.
    In addition to our participation in the SBREFA process, we 
conducted our own outreach, fact-finding, and analysis of the potential 
impacts of our regulations on small businesses. Some of the small 
refiners with whom we and the Panel met indicated their belief that 
their businesses may close due to the substantial costs, capital and 
other impacts of meeting the 15 ppm diesel fuel standard without either 
additional time or flexibility with respect to gasoline sulfur 
compliance. Based on these discussions and analyses, the Panel and we 
agree that small refiners would likely experience a significant and 
disproportionate financial hardship in reaching the objectives of our 
diesel fuel sulfur program. However, the Panel also noted that the 
burden imposed upon the small refiners by our sulfur requirements 
varied from refiner to refiner and could not be alleviated with a 
single provision. We agree with the Panel and are offering qualifying 
small refiners three options to choose from in moving toward compliance 
with the low sulfur diesel fuel requirements.
    For today's action, we have structured a selection of temporary 
flexibilities for qualifying small refiners, both domestic and foreign, 
based on the factors described below. Generally, we structured these 
provisions to address small refiner hardship while expeditiously 
achieving air quality benefits and ensuring that the low sulfur diesel 
fuel coincides with the introduction of 2007 model year diesel 
vehicles.
    First, the compliance deadlines in the program, combined with 
flexibility for small refiners, will quickly achieve the air quality 
benefits of the program, while helping to ensure that small refiners 
will have adequate time to raise capital for new or revamped equipment. 
Most small refiners have limited additional sources of income beyond 
refinery earnings for financing the equipment necessary to produce low 
sulfur diesel. Because these small refiners typically do not have the 
financial backing that larger and generally more integrated companies 
have, they can benefit from additional time to secure capital financing 
from their lenders.

[[Page 5075]]

    Second, we believe that allowing time for refinery sulfur-reduction 
technologies to be proven out by larger refiners before small refiners 
have to put them in place will reduce the risks incurred by small 
refiners that utilize these technologies to meet the standards. The 
added time will likely allow for lower costs of these improvements in 
desulfurization technology (e.g., better catalyst technology or lower-
pressure hydrotreater technology). Because of the poorer economies of 
scale and the higher relative capital and operating costs faced by 
small refiners, more time for technology development and 
commercialization will limit the economic consequences for small 
refiners. Small refiners are disadvantaged by the economies of scale 
that exist for the larger refining companies-capital costs and per-
barrel fixed operating costs are generally higher for small refiners.
    Third, providing small refiners more time to comply will increase 
the availability of engineering and construction resources. Since most 
large and small refiners must install additional processing equipment 
to meet the sulfur requirements, there will be a tremendous amount of 
competition for technology services, engineering manpower, and 
construction management and labor. Our analysis shows that there are 
limits to the price elasticity of these resources. In addition, vendors 
will be more likely to contract their services with the major companies 
first, as their projects will offer larger profits for the vendors.
    Finally, because the gasoline and diesel sulfur requirements will 
occur in approximately the same time frame, small refiners that produce 
both fuels will have a greater difficulty than most other refiners in 
securing the necessary financing. Hence, any effort that increases 
small refiners' ability to stagger investments for low sulfur gasoline 
and diesel will facilitate compliance with the two programs.
    Providing these options to assist small refiners experiencing 
hardship circumstances enables us to go forward with the 15 ppm sulfur 
standard beginning in 2006. Without this flexibility, the benefits of 
the 15 ppm standard would possibly not be achieved as quickly. By 
providing temporary relief to those refiners that need additional time, 
we are able to adopt a program that expeditiously reduces diesel sulfur 
levels in feasible manner for the industry as a whole. In addition, we 
believe the volume of diesel that will be affected by this hardship 
provision is marginal. We estimate that small refiners contribute 
approximately five percent of all domestic diesel fuel production.
b. How Do We Define Small Refiners?
    The following definition of small refiner is based closely on our 
small refiner definition in the Tier 2/Gasoline Sulfur rule. We define 
a refiner that meets both of the following criteria as a ``small 
refiner'' for purposes of this rule:
     No more than 1,500 employees corporate-wide, based on the 
average number of employees for all pay periods from January 1, 1999 to 
January 1, 2000.
     A corporate crude oil capacity less than or equal to 
155,000 barrels per calendar day (bpcd) for 1999.
    In determining the total number of employees and crude oil 
capacity, a refiner must include the number of employees and crude oil 
capacity of any subsidiary companies, any parent company and 
subsidiaries of the parent company, and any joint venture partners. We 
define a subsidiary of a company to mean any subsidiary in which the 
company has a 50 percent or greater ownership interest. This definition 
of small refiner is the same definition used under the recently 
promulgated Tier 2/Gasoline Sulfur program (40 CFR 80.225), except that 
we have included additional regulatory language to clarify our 
interpretation of the term ``subsidiary'' and we have updated the time 
period used to determine the employee number and crude oil capacity 
criteria to reflect data for the most recent calendar years. This 
approach is consistent with the Small Business Administration's 
regulations, which specify that, where the number of employees is used 
as a size standard, the size determination is to be based on the 
average number of employees for all pay periods during the preceding 12 
months (13 CFR 121.106).
    The gasoline sulfur standards and the diesel sulfur standards will 
impact small refiners in approximately the same time frame. For this 
reason, we will consider any refiner that we approve as meeting the 
small refiner definition under the gasoline sulfur program (40 CFR 
80.235) to be a small refiner under the highway diesel sulfur rule as 
well without further demonstration.
    In addition, a company that after January 1, 2000 either acquires 
or reactivates a refinery that was shutdown or non-operational between 
January 1, 1999 and January 1, 2000 may also apply for small refiner 
status. Such an application needs to be submitted to us no later than 
June 1, 2003. In this case, we will judge eligibility under the 
employment and crude oil capacity criteria based on the most recent 12 
consecutive months unless data provided by the refiner indicates that 
another period of time is more appropriate. Companies with refineries 
built after January 1, 2000 are not eligible for the small refiner 
hardship provisions.
    If a refiner with approved small refiner status later exceeds the 
1,500 employee threshold or the corporate crude oil capacity of 155,000 
bpcd without merger or acquisition, it may keep its small refiner 
status. This is to avoid stifling normal company growth and is subject 
to our finding that the company did not apply for and receive the small 
refiner status in bad faith. On the other hand, if a refiner with 
approved small refiner status later exceeds the small refiner criteria 
through merger or acquisition, its refineries must forfeit their small 
refiner status and begin complying with the national standards by 
January 1 of the next calendar year. For example, if a small refiner 
with two refineries purchases a third refinery in 2007 and that 
purchase causes the refiner to exceed the employee or corporate crude 
oil capacity thresholds for small refiner status, then that refiner 
must forgo its small refiner status and begin complying with the 
national standards by January 1, 2008 at all its refineries.
c. What Options Are Available for Small Refiners?
    All refiners producing highway diesel fuel are able to take 
advantage of the temporary compliance option discussed in Section IV.A. 
Diesel producers that also market gasoline in the GPA may receive 
additional flexibility under today's rule (Section IV.B.). As an 
alternative, refiners that seek and are granted small refiner status 
may choose from the following three options under the diesel sulfur 
program. These three options have evolved from concepts on which we 
requested and received comment in the proposal. In most cases, we 
believe that small refiners will find these options preferable to 
either the broader diesel fuel temporary compliance option or the GPA 
provision discussed above.
    500 ppm Option. A small refiner may continue to produce and sell 
diesel fuel meeting the current 500 ppm sulfur standard for four 
additional years, until May 31, 2010, provided that it reasonably 
ensures the existence of sufficient volumes of 15 ppm fuel in the 
marketing area(s) that it serves.
    Small Refiner Credit Option. A small refiner that chooses to 
produce 15 ppm fuel prior to June 1, 2010 may generate and sell credits 
under the broader

[[Page 5076]]

temporary compliance option. Since a small refiner has no requirement 
to produce 15 ppm fuel under this option, any fuel it produces at or 
below 15 ppm sulfur will qualify for generating credits.
    Diesel/Gasoline Compliance Date Option. For small refiners that are 
also subject to the Tier 2/Gasoline sulfur program (40 CFR Part 80, 
Subpart H), the refiner may choose to extend by three years the 
duration of its applicable interim gasoline standards, provided that it 
also produces all its highway diesel fuel at 15 ppm sulfur beginning 
June 1, 2006.
    All refiners producing diesel fuel are required to provide us with 
basic data on their progress toward compliance in 2003-2005 under the 
pre-compliance reporting requirements described above in Section IV.A. 
As a part of their pre-compliance reports, small refiners must provide 
a limited amount of additional information specific to the option they 
choose. We discuss each option, and the special pre-compliance 
reporting requirements for each option, in the next paragraphs and in 
Section VII.E below.
i. 500 ppm Option
    The 500 ppm option is available for any refiner that qualifies as a 
small refiner. Under this option, small refiners may continue selling 
highway diesel fuel with sulfur levels meeting the current 500 ppm 
standard for four additional years, provided that they supply 
information showing that sufficient alternate sources of 15 ppm diesel 
fuel in their market area will exist for fueling new heavy-duty highway 
vehicles. Under this option, small refiners may supply current 500 ppm 
highway diesel fuel to any markets for use only in vehicles with older 
(pre-2007) technology until May 31, 2010. In other words, small 
refiners that choose this option may delay production of highway diesel 
fuel meeting the 15 ppm standard for four years.
    This 500 ppm option for small refiners is similar to the option 
provided to all refiners under the temporary compliance option 
described in Section IV.A above in that it allows a refiner to continue 
producing and selling the current 500 ppm fuel for a period of time. 
However, this option differs from the broader compliance option in that 
small refiners may produce and sell 100 percent of their highway fuel 
at 500 ppm without needing to buy credits. In contrast, under the 
broader temporary compliance option, refiners must buy credits to 
produce any volume of 500 ppm fuel over 20 percent of their total 
highway diesel production.
    At the retail level, retailers will not be subject to any 
availability requirements and thus may sell 500 ppm fuel, 15 ppm 
highway fuel, or both (as is the case under the broader diesel 
temporary compliance option described in Section IV.A). All parties in 
the diesel fuel distribution system will have to maintain the 
segregation of 15 ppm fuel and 500 ppm fuel and only 15 ppm fuel may be 
sold for use in model year 2007 and later heavy-duty diesel vehicles.
    As a part of their pre-compliance reporting due June 1, 2003 (see 
Section IV.A. above), any small refiners taking advantage of this 500 
ppm option must show that sufficient sources of 15 ppm fuel will likely 
exist in the area served by the small refiner in the absence of 
production of 15 ppm fuel by that refiner.169 A small 
refiner could approach this showing in different ways. For example, 
depending on the circumstances, the refiner might point to the presence 
of other refiners in the area that are expected to produce 15 ppm fuel, 
or to the refiner's proximity to a major pipeline that will be carrying 
15 ppm fuel. Similarly, the refiner might show that its market share in 
the area's highway diesel market will be too small to significantly 
affect the volume of 15 ppm fuel regardless of the small refiner's 
actions.
---------------------------------------------------------------------------

    \169\ If circumstances arise that cause the availability of 15 
ppm fuel in the refiner's market area to decline, the refiner must 
provide a supplemental showing in its pre-compliance reports due in 
June 1, 2004 and/or June 1, 2005. As with the 2003 report, we will 
either approve or disapprove these additional showings within four 
months or, if we take no action, the showing will be deemed 
approved.
---------------------------------------------------------------------------

    Another approach could be to indicate practical steps that the 
refiner itself is prepared to take to help ensure that 15 ppm diesel 
fuel will be available. One commenter suggested a plan to add a 
separate tank and expand its fuel loading rack for handling 15 ppm 
diesel fuel that would be supplied by a different refiner--thus making 
low sulfur fuel available, at least at the wholesale level, at its 
refinery gate even though it produced no 15 ppm fuel.
    Because of the wide distribution of 15 ppm fuel that we believe 
will occur under the industry-wide optional compliance program 
discussed in Section IV.A. above, we expect that few if any small 
refiners wishing to use the 500 ppm option will find it difficult to 
make the showing that 15 ppm fuel will exist in the area. If we do not 
take action on this showing within four months of receiving a refiner's 
2003 pre-compliance report (i.e., by October 1, 2003 at the latest), 
the refiner's showing will be considered approved.
    Finally, we are providing this option so that small refiners may 
use the temporary flexibility provided by the 500 ppm option as a 
pathway toward compliance with the 15 ppm standard and not as an 
opportunity for those refiners to greatly expand their production of 
fuel meeting the 500 ppm sulfur standard. To help ensure that any 
significant expansion of refining capacity that a small refiner 
undertakes in the future will be accompanied by an expansion of 
desulfurization capacity, we are limiting the volume of 500 ppm sulfur 
fuel that a small refiner may produce under this option to a baseline 
level. Specifically, small refiners selecting this 500 ppm option must 
limit the volume they produce of highway diesel fuel meeting the 500 
ppm sulfur standard to the lesser of the following values: (1) 105 
percent of the average highway diesel volume it produced from crude oil 
in calendar years 1998 and 1999 or (2) the average highway diesel 
volume it produced from crude oil in calendar years 2004 and 2005. Any 
volume of 500 ppm highway diesel fuel (averaged over the previous 12 
consecutive months) that exceeds this limitation after 2006 must comply 
with the diesel sulfur standards that apply to other refiners under the 
broader program (i.e., the standards described in Section IV.A. above, 
including the 80% requirement of the temporary compliance option).
ii. Small Refiner Credit Option
    We believe that the relative difficulty for small refiners to 
comply with today's program warrants compliance flexibility for these 
refiners. At the same time, we want to encourage all refiners to 
produce low sulfur diesel fuel as early and in as many geographic areas 
as possible. As an incentive for small refiners to invest in 
desulfurization capacity, those that choose to produce 15 ppm fuel 
earlier than required under the 500 ppm option may generate credits for 
each gallon of diesel fuel produced that meets the 15 ppm standard. 
This includes the ability to generate credits prior to the start of the 
program on June 1, 2006 under the provisions described in Section 
IV.A.1.a. They could then sell these credits to other refiners for use 
in the broader optional diesel fuel compliance program described above 
in Section IV.A, helping to offset some low sulfur diesel fuel 
production costs.
    Under this option, credits may be generated based on the volume of 
any diesel fuel that meets the 15 ppm standard. Refiners may then sell 
their remaining highway diesel fuel under the 500 ppm option above.

[[Page 5077]]

    Pre-compliance reporting for small refiners choosing this Small 
Refiner Credit option is identical to that for the 500 ppm option (that 
is, if the small refiner is also producing 500 ppm highway diesel 
fuel), with the additional requirement that the refiner also report on 
any credits it expects to generate and sell. If the quantity of 15 ppm 
fuel that the refiner is preparing to produce is significant, this 
factor may be useful in making the necessary showing that 15 ppm fuel 
will be available in the refiner's market area.
iii. Diesel/Gasoline Compliance Date Option
    The Tier 2/Gasoline Sulfur program included a special provision 
that applies for refiners that qualify as small refiners (40 CFR Part 
80, Subpart H). Under that program, each small refiner is assigned an 
interim gasoline sulfur standard for each of its refineries. This 
interim standard for each refinery is established based on the baseline 
sulfur level of that refinery. The standards are designed to require 
each small refiner to either make a partial reduction in their gasoline 
sulfur levels or, if they already produce low sulfur fuel, to maintain 
their current levels. The interim program lasts for four years, 2004 
through 2007, and the refiner can apply for an extension of up to three 
years. After the interim program expires, small refiners must produce 
the same low sulfur gasoline as other refiners.
    Today's diesel sulfur program takes effect in the same time frame 
as the small refiner interim program for low sulfur gasoline. To avoid 
the need for simultaneous investments in both gasoline and diesel fuel 
desulfurization, several small refiners subject to both programs raised 
the concept of allowing those investments to be staggered in time. 
Because of the relative difficulty small refiners will face in 
financing desulfurization projects, especially for both diesel and 
gasoline desulfurization in the same time frame, we agree that this 
concept has merit and have adopted it for this rule. Under this 
concept, small refiners may extend the duration of their gasoline 
sulfur interim standards and, thus, potentially postpone some or all of 
their gasoline desulfurization investments while they work to achieve 
the low sulfur diesel standard ``on time'' in 2006. To the extent that 
small refiners choose this Diesel/Gasoline Compliance Date option, this 
provision will benefit the overall diesel program by increasing the 
availability of 15 ppm diesel fuel in the small refiners' market areas.
    Specifically, this option provides that a small refiner can receive 
a three-year extension of a refinery's interim gasoline standard, until 
January 1, 2011, if it meets two criteria: (1) It produces both 
gasoline and diesel fuel at a refinery and chooses to comply with the 
15 ppm diesel fuel sulfur standard by June 1, 2006 for all its highway 
diesel production at that same refinery, and (2) it produces a minimum 
volume of 15 ppm fuel at that refinery that is at least 85 percent of 
the average volume of highway diesel fuel that it produced at that 
refinery during calendar years 1998 and 1999. We believe that it is 
very important that the extension of a small refiner's interim low 
sulfur gasoline standard be linked to a substantial environmental 
benefit from the production of low sulfur diesel fuel in 2006. We have 
established a minimum volume requirement to prevent the Diesel/Gasoline 
Compliance Date option from applying in situations where a refiner 
changes its refinery product slate to produce very little highway 
diesel fuel--even though this production is at a 15 ppm sulfur level--
and yet receives an extension of its interim gasoline sulfur 
standard.170 We believe the 85 percent level is sufficient 
to reflect a substantial investment in desulfurization technology. At 
the same time the 85 percent level should allow for any reasonable 
variation in production of highway diesel fuel that would be expected 
to occur in typical situations between now and 2006, particularly given 
the continued growth of the highway diesel market. Again, the three-
year extension of the gasoline interim program is to allow small 
refiners to stretch out their capital investments while increasing the 
quantity of 15 ppm fuel being produced. We expect that small refiners 
using this option will make a substantive capital investment in diesel 
desulfurization and have thus set this minimum 15 ppm diesel volume 
limit.
---------------------------------------------------------------------------

    \170\ If a situation arises where a small refiner did not 
produce highway diesel fuel in 1998 or 1999 but later begins to 
produce 15 ppm diesel fuel, use of the Diesel/Gasoline Compliance 
Date option will require case-by-case EPA approval. In its 
application for such approval, a refiner must show us that the net 
loss of emission reductions will not be significant and must propose 
an appropriate minimum production volume. In evaluating such a 
proposed minimum volume, we may consider, among other factors, the 
typical ratio between highway diesel and gasoline production for 
small-to-medium sized refineries in the industry.
---------------------------------------------------------------------------

    We believe that the additional three-year extension of the interim 
gasoline sulfur standards provided today is warranted without any 
further action by small refiners, provided that they assume the 
financial burden of full low sulfur diesel compliance in 2006 (i.e., 
instead of choosing the flexibility of the broader temporary compliance 
program). The diesel and gasoline desulfurization investments for those 
refiners can thus be staggered in time. We believe a three-year 
extension is appropriate due to the substantial investment in highway 
diesel fuel that these small refiners will be undertaking.
    By July 1, 2006, small refiners that plan to use the Diesel/
Gasoline Compliance Date option for one or more refineries must send a 
letter to us confirming that by June 1, 2006 they were producing 100 
percent of their highway diesel fuel in compliance with the 15 ppm 
sulfur standard at their refinery(ies). These refiners must make 
similar confirmations each year through 2011 in their annual compliance 
reports (due by the end of February of each year)--until after the end 
of the extended interim low sulfur gasoline program for small refiners 
on December 31, 2010.
    If a given small refiner was not producing 15 ppm fuel for all its 
highway diesel production at that refinery by June 1, 2006, the July 1, 
2006 letter must confirm that the refiner is forfeiting the 
``automatic'' three-year extension of that refinery's interim gasoline 
program (although the refiner may still apply for a case-by-case 
extension through the Tier 2/Gasoline Sulfur program under 40 CFR 
80.260). In this case, we will consider a request that the refiner be 
allowed to use either the 500 ppm option or the Small Refiner Credit 
option, or both, provided that information addressing the conditions of 
these options as described above are included in the July 1, 2006 
letter. If the refiner does not request the use of the 500 ppm option 
or the Small Refiner Credit option, the letter must confirm that the 
refiner is complying with the diesel sulfur requirements applicable to 
refiners that are not small refiners.
    The Tier 2/Gasoline Sulfur program includes a general hardship 
provision for which refiners may apply. (Today's program also includes 
a similar provision). Depending on the nature of its hardship, a small 
refiner that applies for this general hardship provision under the 
gasoline program may be granted a ``tailor-made'' interim gasoline 
sulfur program different from the ``default'' program established in 
the rule. If such a small refiner were then to be covered by today's 
diesel fuel requirements and chose this Diesel/Gasoline Compliance Date 
option, we will allow it an extension of its special interim program 
for gasoline (as established under the general hardship provision) for 
three years beyond the scheduled end date (although no later than 
December 31, 2010) so long as it

[[Page 5078]]

met the 15 ppm diesel fuel standard and production volume requirements 
in 2006.
    As with the other two options, refiners expecting to use the 
Diesel/Gasoline Compliance Date option and thus to produce their 
highway diesel fuel exclusively at 15 ppm fuel will have to report 
certain information beginning in 2003. As a part of their pre-
compliance reporting due June 1, 2003 (see Section IV.A. above), any 
small refiners taking advantage of this option must provide information 
showing that diesel desulfurization plans are on track. The information 
supplied under this requirement must include, but will not be limited 
to, the following: (1) Status of applying for and receiving any 
necessary air pollution control permits, (2) financing that is in place 
or being sought, and (3) the status of engineering or construction 
contracts. As a part of the pre-compliance reporting due in 2004 and 
2005, the refiner must provide more complete information as it becomes 
available to update its earlier report (e.g., the status of beginning 
or completing construction of desulfurization equipment).
iv. Relationship of the Options to Each Other
    By definition, since a small refiner must produce 100 percent of 
its highway diesel as 15 ppm under the Diesel/Gasoline Compliance Date 
option, that option is not compatible with either the 500 ppm option or 
the Small Refiner Credit option. Thus a refiner choosing the Diesel/
Gasoline Compliance Date option may not choose either of the other two 
options. However, the 500 ppm option and the Small Refiner Credit 
option are compatible with each other, and so a refiner may choose 
either or both of these options.
d. How Do Small Refiners Apply for Small Refiner Status?
    Refiners that are not small refiners under the gasoline sulfur 
program but that are seeking small refiner status under the diesel 
sulfur program must apply to us as a part of their registration for the 
general diesel sulfur program, due no later than December 31, 2001. The 
application must include the following information: 171
---------------------------------------------------------------------------

    \171\ See the Section VII.E below and regulatory language 
associated with this rule for detailed requirements for registration 
and application for small refiner status.
---------------------------------------------------------------------------

     The name and address of each location at which any 
employee of the company, including any parent companies or 
subsidiaries,172 worked during the 12 months preceding 
January 1, 2000;
---------------------------------------------------------------------------

    \172\ ``Subsidiary'' here covers entities of which the parent 
company has 50 percent or greater ownership.
---------------------------------------------------------------------------

     The average number of employees at each location, based on 
the number of employees for each of the company's pay periods for the 
12 months preceding January 1, 2000;
     The type of business activities carried out at each 
location; and
     The total crude oil refining capacity of its corporation. 
We define total capacity as the sum of all individual refinery 
capacities for multiple-refinery companies, including any and all 
subsidiaries, as reported to the Energy Information Administration 
(EIA) for 1999, or in the case of a foreign refiner, a comparable 
reputable source, such as professional publication or trade 
journal.173 Refiners do not need to include crude oil 
capacity used in 1999 through a lease agreement with another refiner in 
which it has no ownership interest.
---------------------------------------------------------------------------

    \173\ We will evaluate each foreign refiner's documentation of 
crude oil capacity on an individual basis.
---------------------------------------------------------------------------

    The crude oil capacity information reported to the EIA or 
comparable reputable source is presumed to be correct. However, in 
cases where a company disputes this information, we will allow 60 days 
after the company submits its application for small refiner status for 
that company to petition us with detailed data it believes shows that 
the EIA or other source's data was in error. We will consider this data 
in making a final determination about the refiner's crude oil capacity.
    We will consider any refiner that was granted small refiner status 
under the Tier 2/Gasoline Sulfur program to also qualify as a small 
refiner under today's program, provided that it also produced highway 
diesel fuel in 1999. Such a refiner only needs to indicate as a part of 
its registration for this program that it is covered by the gasoline 
sulfur small refiner program and that it expects to be eligible for any 
small refiner optioins available in today's diesel program.
2. Farmer Cooperative Refiners Will Benefit From the Flexible 
Provisions Available to Other Refiners
    Some refineries in the U.S. are owned by farmer cooperatives. In 
the NPRM, we asked for comment on whether it would be appropriate to 
extend hardship relief to farmer cooperatives, similar to the 
flexibility options for small refiners. Representatives of farmer 
cooperative refiners have commented to us that as refiners they face 
unique challenges under a diesel fuel sulfur program. As described in 
more detail below and in the Response to Comments document, we have 
carefully considered the situation of farmer cooperative refiners. We 
have concluded that while there are clearly differences in how farmer 
cooperative refiners are organized and are financed compared to other 
refiners, we are not able to make a determination that farmer 
cooperative refiners, as a class, face unique economic hardship. As 
discussed further below, we believe that the combination of 
flexibilities built into today's diesel program will be valuable to 
farmer cooperative refiners. To the extent any of the farmer 
cooperative refiners face economic hardship in complying with the 
diesel sulfur program, this determination can best be made on a case-
by-case basis for each farmer cooperative refiner, as discussed further 
below.
    As is the case for all refiners, we believe that farmer cooperative 
refiners will be able to benefit significantly from the several 
flexibility provisions discussed elsewhere in Section IV of this 
preamble. As we mentioned above, the farmer cooperative refiner with 
the smallest refinery appears to meet the criteria for status as a 
``small refiner,'' and thus will likely be eligible for the special 
provisions discussed earlier (Section IV.C.1. above). The second 
smallest refinery owned by a farmer cooperative is located and markets 
all or most of its gasoline within the geographic GPA and, as such, is 
eligible for GPA low sulfur gasoline extension described in Section 
IV.B. above (if it meets the production and volume requirements for 15 
ppm fuel). Alternatively, this refinery could participate in the 
temporary compliance option for diesel fuel described in Section IV.A. 
above.
    The two other farmer cooperative refiners (as well as any other 
refiner) may participate in the temporary compliance option for diesel 
fuel and the averaging, banking, and trading provisions described above 
(Section IV.A.), potentially allowing them to postpone diesel 
desulfurization investments. If needed, any of the farmer cooperative 
refiners may also apply for case-by-case hardship relief (Section 
IV.C.3. below). Through such a case-by-case review, we will be in a 
better position to make a determination of whether a particular farmer 
cooperative refiner faced an economic hardship situation, as we would 
then have available to us specific financial information about each 
cooperative owner. If we determine that a cooperative refiner faced an 
economic

[[Page 5079]]

hardship situation, we could then tailor any temporary hardship 
provisions to best suit the needs of that refiner. Given this 
combination of options and ``safety valves'' built into the diesel 
sulfur program, and the factors discussed below, we do not believe it 
is necessary to provide special provisions specifically for farmer 
cooperative refiners as a class.
    Farmer cooperatives that own refineries, like all farmer 
cooperatives, are organized as a means for individual farmers (or local 
cooperatives owned by individual farmers) to collectively gain benefits 
in important aspects of their farming businesses--in this case, the 
production and distribution of the fuel needed for their operation. It 
should also be noted that the diesel fuel produced by farmer 
cooperative refiners is sold not only to farmers, but also to the 
wholesale petroleum market, for sale at service stations, truck stops, 
or fleets. Individual farmers and others become members of local 
cooperatives that provide a range of products and services to their 
members. These local cooperatives in turn often form the membership of 
larger, regional cooperatives, including those that own three of the 
four farmer cooperative refineries in the U.S.
    Refiners that are also cooperative businesses are significantly 
different from other refiners in several respects. The key aspect is 
that several avenues for accessing capital used by many other refiners 
(in this case, the capital needed to carry out diesel fuel 
desulfurization projects in their refineries) are not available to, or 
are not practical for, cooperative refiners. In particular, farmer 
cooperatives, unlike publicly-held corporations, are generally not 
permitted to raise equity capital in the securities markets (that is, 
by selling stock). At the same time, the equity financing provided by 
the membership, usually a modest amount assessed from each member as a 
condition of membership, provides a return for the members only to the 
extent that the members purchase the products or services of the 
cooperative. Conventional investors that do not regularly patronize the 
cooperative have little incentive to provide investment from the 
outside, since their investment will not appreciate in value.
    For farmer cooperatives, money for capital projects is generally 
raised internally as equity from members and as loans from banks or 
other financial institutions. In this sense, farmer cooperative 
refiners are similar to privately-held refining companies, which are 
also unable to raise capital by selling public stock. In the case of 
farmer cooperatives, equity capital is raised either by assessment of 
the members or, more often, by retaining a portion of the cooperative's 
earnings that would otherwise be distributed to the members (on the 
basis of how much business they have done with the cooperative). The 
amount of equity available to the cooperative, as well as the earning 
prospects of the cooperative, usually determine whether financial 
institutions will lend additional capital, how much money will be lent, 
and what terms the cooperative will have to agree to. For example, when 
a cooperative's equity is low and/or the farm economy is stressed (and 
thus the prospects for strong earnings performance by the cooperative 
are diminished) cooperatives can have difficulty competing among other 
potential borrowers for loans for large capital projects.
    While the unique structural and financial characteristics of farmer 
cooperative refiners can present special challenges to these refiners, 
their status as cooperatives can also provide advantages not shared by 
other refiners. The same federal and state laws and regulations that 
place limitations on the financial avenues available to cooperatives 
also tend to include special provisions only available to cooperatives. 
These include special treatment for cooperatives under securities laws, 
antitrust laws, contractual marketing laws, and restrictive corporate 
entity laws, some or all of which may come into play in efforts to 
capitalize refinery desulfurization projects.
    Also, the relatively large regionally-based cooperatives that own 
refineries have a variety of other business interests as well. This 
broader business base, which involves not only the refining and 
distribution of fuels but also a variety of other agricultural supply, 
processing, and related operations, may often provide an advantage to 
these larger cooperative refiners as compared to competing refiners 
that have little or no business beyond refining and fuel marketing. 
Finally, the three larger farmer cooperative refiners have developed 
several economic relationships among one another--including joint 
refinery ownership, a joint refinery operating agreement, and a joint 
fuel distribution and marketing organization--that together create 
greater options for financing than are available to many other 
refiners.
    Based on the compliance option provisions in this action we do not 
believe that farmer cooperative refiners as a class face a 
disproportionate economic burden in complying with the diesel sulfur 
program. However, certain cooperative refiners may face additional 
economic obstacles, therefore the potential need exists for some 
financial assistance to farmer cooperative refiners from U.S. 
government programs. During interagency review, concerns were discussed 
relating to the uniqueness of the structure of farmer cooperative 
refineries and the key issue of accessing capital was identified. The 
U.S. Department of Agriculture (USDA) has indicated an interest and 
willingness to review its existing authorities for the potential 
mechanisms to provide financial assistance to refiner cooperatives who 
do invest in desulfurization programs. Congress and USDA have long 
recognized the unique circumstances of farmers and rural communities by 
establishing programs to provide assistance. This assistance would be 
primarily in the form of guaranteed loans, which could provide a 
significant source of funding for cooperative refiners to make capital 
investment in desulfurization. However, USDA's loan program is subject 
to limitations, including a $25 million annual cap on individual loans, 
so the cooperative refiners may have to acquire additional financing. 
EPA understands that USDA supports efforts, where appropriate, to 
provide assistance to farmer-owned cooperatives from other sources.
    In conclusion, after reviewing this information, we have not been 
able to clearly distinguish a unique economic burden that today's 
program will place on farmer cooperative refiners, as a class, apart 
from other refiners, especially other refiners of similar size and/or 
those that are privately-held companies. However, as described above, 
several of the flexible provisions we have incorporated into the 
overall diesel sulfur program will be valuable to farmer cooperative 
refiners.
3. General Hardship Provisions
a. Temporary Waivers from Low Sulfur Diesel Requirements in Extreme 
Unforseen Circumstances
    In this final rule, we are adopting a provision which, at our 
discretion, will permit domestic or foreign refiners to seek a 
temporary waiver from the highway diesel sulfur standards under certain 
rare circumstances. This waiver provision is similar to provisions in 
the reformulated gasoline (RFG) and low sulfur gasoline regulations. It 
is intended to provide refiners short-term relief in unanticipated 
circumstances--such as a refinery fire or a natural disaster--that 
cannot be reasonably foreseen now or in the near future.

[[Page 5080]]

    Under this provision, a refiner may seek permission to distribute 
highway diesel fuel that does not meet the applicable low sulfur 
standards for a brief time period. An approved waiver of this type 
could, for example, allow a refiner that has reached its maximum 
allowable production volume of 500 ppm sulfur fuel under the temporary 
compliance option to temporarily and modestly exceed that volume, so 
long as the other conditions described below were met. Such a request 
will be based on the refiner's inability to produce complying highway 
diesel fuel because of extreme and unusual circumstances outside the 
refiner's control that could not have been avoided through the exercise 
of due diligence. The request will also need to show that other avenues 
for mitigating the problem, such as purchase of credits toward 
compliance under the temporary compliance option, had been pursued and 
yet were insufficient.
    As with other types of relief established in this rule, this type 
of temporary waiver will have to be designed to prevent fuel exceeding 
the 15 ppm standard from being used in 2007 and later vehicles. As with 
the small refiner hardship provisions described above, any such waiver 
must show that other sources of 15 ppm fuel exist in the refiner's 
market area to help reduce the risk that owners of 2007 and later 
diesel vehicles will have difficulty finding the 15 ppm fuel they need 
during the period of the waiver.
    The conditions for obtaining a low sulfur diesel waiver are similar 
to those in the RFG and low sulfur gasoline regulations. These 
conditions are necessary and appropriate to ensure that any waivers 
that are granted are limited in scope, and that refiners do not gain 
economic benefits from a waiver. Therefore, refiners seeking a waiver 
must show that the waiver is in the public interest, that the refiner 
was not able to avoid the nonconformity, that it will make up the air 
quality detriment associated with the waiver, that it will make up any 
economic benefit from the waiver, and that it will meet the applicable 
diesel sulfur standards as expeditiously as possible.
b. Temporary Waivers Based on Extreme Hardship Circumstances
    In addition to the provision for short-term relief in extreme 
unforseen circumstances, we are adopting a provision for relief based 
on extreme hardship circumstances. In developing our diesel sulfur 
program, we considered whether any refiners would face particular 
difficulty in complying with the standards in the lead time provided. 
As described earlier in this section, we concluded that refineries 
owned by small businesses will experience more difficulty in complying 
with the standards on time because they have less ability to raise the 
capital necessary for refinery investments, face proportionately higher 
costs because of poorer economies of scale, and are less able to 
successfully compete for limited engineering and construction 
resources. However, it is possible that other refiners that are not 
small refiners will also face particular difficulty in complying with 
the sulfur standards on time. Therefore, we are including in this final 
rule a provision which allows us, at our discretion, to grant temporary 
waivers from the diesel sulfur standards based on a showing of extreme 
hardship circumstances.
    The extreme hardship provision allows any domestic or foreign 
refiner to request a waiver from the sulfur standards based on a 
showing of unusual circumstances that result in extreme hardship and 
significantly affect a refiner's ability to comply with the low sulfur 
diesel standards by June 1, 2006. An approved extreme hardship waiver 
may provide refiners with provisions similar to those for small 
refiners, or as with the waiver for extreme unforseen circumstances, 
may provide a greater allowance for producing 500 ppm (for sale only 
for use in pre-2007 vehicles) during the period the temporary 
compliance option is in effect. As with other relief provisions 
established in this rule, any waiver under this provision must be 
designed to prevent fuel exceeding the 15 ppm standard from being used 
in 2007 and later vehicles.
    By providing short-term relief to those refiners that need 
additional time because they face hardship circumstances, we can adopt 
an overall program that reduces diesel fuel sulfur beginning in 2006 
for the majority of the industry. However, we do not intend for this 
waiver provision to encourage refiners to delay planning and 
investments they would otherwise make. We do not expect to grant 
temporary waivers that apply to more than approximately one percent of 
the national highway diesel fuel pool in any given year.
    The regulatory language for today's action includes a complete list 
of the information that must be included in a refiner's application for 
an extreme hardship waiver. If a refiner fails to provide all the 
information, as specified in the regulations, as part of its hardship 
application, we can deem the application void. The following are some 
examples of the types of information that must be contained in an 
application:

    --The crude oil refining capacity and diesel fuel sulfur level at 
each of the refiner's refineries.
    --Details on how the refiner plans to modify its current operation 
to achieve future diesel fuel sulfur levels.
    --The anticipated timing for the overall project the refiner is 
proposing and key milestones to ultimately produce 100 percent of 
highway diesel fuel at the 15 ppm sulfur standard.
    --The refiner's capital requirements for the proposed project
    --Plans for financing the project and financial statements
    --List of the areas where the refiner's diesel fuel will be sold.

    We will consider several factors in our evaluation of the hardship 
waiver applications. Such factors will include whether a refinery's 
configuration is unique or atypical; the proportion of diesel fuel 
production relative to other refinery products; whether the refiner, 
its parent company, and its subsidiaries are faced with severe economic 
limitations (for example, a demonstrated inability to raise necessary 
capital or an unfavorable bond rating); steps the refiner has taken to 
attempt to comply with the standards, including efforts to obtain 
credits towards compliance. In addition, we will consider the total 
crude oil capacity of the refinery and its parent or subsidiary 
corporations, if any, in assessing the degree of hardship and the 
refiner's role in the diesel market. Finally, we will consider where 
the diesel fuel will be sold in evaluating the environmental impacts of 
granting a waiver.
    This extreme hardship provision is intended to address unusual 
circumstances that should be apparent now or will emerge in the near 
future. Thus, refiners seeking additional time under this provision 
must apply for relief by June 1, 2002. Applicants for a hardship waiver 
must also submit a plan demonstrating how they will achieve the 
standards as quickly as possible. In submitting the plan, applicants 
must include a timetable for obtaining the necessary capital, 
contracting for engineering and construction resources, obtaining any 
necessary permits, and beginning and completing construction.
    We will review and act on applications and, if a waiver is granted, 
will specify a time period, not to extend beyond May 31, 2010, for the 
waiver.

D. Technological Feasibility of the Low Sulfur Diesel Fuel Program

    This section summarizes our assessment of the feasibility of 
refining

[[Page 5081]]

and distributing diesel fuel with a sulfur content of no more than 15 
ppm. Based on this evaluation, we believe it is technologically 
feasible for refiners to meet the 15 ppm sulfur standard in the lead 
time provided. We are summarizing our analysis here and we refer the 
reader to the RIA for more details.
1. What Technology Will Refiners Use?
    Conventional diesel desulfurization technologies have been 
available and in use for many years. Conventional hydrotreating 
technology involves combining hydrogen with the distillate (material 
falling into the boiling range of diesel fuel) at moderate pressures 
and temperatures and flowing the mixture through a fixed bed of 
catalyst.
    We project that all refiners will be technically capable of meeting 
the 15 ppm sulfur cap with extensions of the same conventional 
hydrotreating which they are using to meet the current highway diesel 
fuel standard of 500 ppm sulfur. This extension will likely mean adding 
a second stage of conventional hydrotreating. Converting an existing 
one-stage hydrotreater into a two-stage hydrotreater will involve 
adding an additional reactor as well as other, more minor units to 
support the new desulfurization unit. These units could include 
hydrogen plants, sulfur recovery plants, amine plants and sour water 
scrubbing facilities. All of these units are already operating in 
refineries, but may have to be expanded or enlarged. We also project 
that all refiners will utilize recently developed, high activity 
catalysts, which increase the amount of sulfur that can be removed 
relative to the catalysts which were available when the current 
desulfurization units were designed and built.
    While still utilizing this conventional hydrotreating technology, 
we expect that some refiners (roughly 20 percent of current production 
volume) will decide to invest in a completely new two-stage 
hydrotreater rather than revamp their current unit. This could occur 
because the current hydrotreater is too old or designed to operate at 
too low a pressure, or because the refiner desires to expand production 
of highway diesel fuel.
    The sufficiency of conventional hydrotreating to meet a 15 ppm 
sulfur cap with current diesel fuel blendstocks is based primarily on 
information provided by several refining technology 
vendors.174 The vendors all projected that two-stage 
hydrotreating would be sufficient to meet a 15 ppm sulfur cap. However, 
their projections of hydrogen consumption and requisite reactor volume 
varied widely. Our projections for hydrogen consumption and reactor 
volume are near the lower end of the range and are essentially the same 
projections as were made in support of the proposed rule.
---------------------------------------------------------------------------

    \174\ Technology vendors were invited to submit projections of 
technology and cost to two studies of the cost of diesel fuel 
desulfurization by Mathpro, Inc. One study was performed for EMA, 
and the other for the National Petroleum Council.
---------------------------------------------------------------------------

    Many refiners commented that we had underestimated the cost of 
meeting the 15 ppm sulfur cap. They argued that higher pressure, thick 
walled reactors of greater volume would be needed and that hydrogen 
consumption would be much higher than we projected. With one exception, 
neither the refiners, nor the technology vendors provided any 
underlying catalyst performance data with which we could use to 
arbitrate between the varying projections. One vendor did submit 
catalyst performance data from a commercial unit processing a diesel 
fuel like that produced in the U.S. Such commercial data is very 
limited, as refiners are generally not currently producing diesel fuel 
at sulfur levels below 10 ppm with this technology from diesel fuel 
feedstocks typical of U.S. refiners. Some refiners are currently 
producing diesel fuel at sulfur levels below either 10 or 50 ppm. 
However, their diesel fuel blendstocks differ substantially in quality 
from those available in the U.S., so their experience cannot be 
extrapolated easily to producing sub-15 ppm sulfur diesel fuel in the 
U.S.
    Based on our review of the limited catalyst performance data in the 
published literature and the one set of confidential data submitted, we 
believe that the projections of the more optimistic vendors are the 
most accurate for the 2006 timeframe. For example, the confidential 
commercial data indicated that five ppm sulfur levels could be achieved 
with two-stage hydrotreating a moderate hydrogen pressures despite the 
presence of a significant amount of light cycle oil (LCO). The key 
factor was the inclusion of a hydrogenation catalyst in the second 
stage, which saturated many of the poly-nuclear, aromatic rings in the 
diesel fuel, allowing the removal of sulfur from the most sterically 
hindered compounds. In addition, refiners that are able to defer 
production of 15 ppm diesel fuel through the purchase of credits will 
have the added benefit of being able to observe the operation of those 
hydrotreating units starting up in 2006. This should allow these 
refiners to be able to select from the best technologies which are 
employed in the first phase of the program.
    In addition, alternative technologies are presently being developed 
which could produce additional savings for refiners that are able to 
delay production of 15 ppm fuel until 2010. Phillips 66 Company, for 
example, just announced that they are developing a version of their S-
Zorb technology for diesel fuel desulfurization. This technology has 
been selected by at least one major refiner (Marathon-Ashland) to meet 
the Tier 2/low sulfur gasoline requirements. In conjunction with a DOE 
research program, Phillips is designing and constructing a commercially 
sized S-Zorb diesel fuel unit at their Borger refinery. This unit is 
currently scheduled for start-up in 2004. We believe that this 
technology could reduce the cost of meeting the 15 ppm cap by roughly 
25 percent.
2. Have These Technologies Been Commercially Demonstrated?
    As mentioned above, conventional diesel desulfurization 
technologies have been available and in use for many years. U.S. 
refiners have roughly seven years of experience with this technology in 
producing highway diesel fuel with less than 500 ppm sulfur. Refiners 
in California also have the same length of experience with meeting the 
California 500 ppm cap on sulfur and an additional aromatics 
standard.175 To meet both sulfur and aromatics standards, 
refineries in California are producing highway and nonroad diesel fuel 
with an average sulfur level of 150 ppm.
---------------------------------------------------------------------------

    \175\ California allows refiners to use an engine test to 
certify an alternative fuel mixture which meets or exceeds the 
NOX reducing performance of a 10 volume percent maximum 
aromatics and a 500 ppm maximum sulfur diesel fuel.
---------------------------------------------------------------------------

    Some refiners in Europe are producing a very low-sulfur, low 
aromatics diesel fuel for use in the cities in Sweden (Class I Swedish 
Diesel) using two-stage hydrotreating. This ``Swedish city diesel'' is 
averaging under 10 ppm sulfur and under 10 volume percent aromatics. 
While clearly demonstrating the feasibility of consistently producing 
diesel fuel with less than 10 ppm sulfur from selected feedstocks, 
there are a few differences between the Swedish fuel and typical U.S. 
diesel fuel. First, the tight aromatics specification applicable to 
Swedish City diesel fuel usually requires the use of ring-opening or 
dearomatization catalysts in the second stage of the two-stage 
hydrotreating unit. Second, Swedish Class I diesel fuel also must meet 
a tight density specification. Third, it is not clear

[[Page 5082]]

whether any refiner is producing a large fraction of their distillate 
production to this specification. Thus, the European experience 
demonstrates the efficacy of the two-stage process and its ability to 
produce very low sulfur diesel fuel. However, doing so without 
saturating most of the aromatics present and with heavier feedstock has 
only been demonstrated in pilot plants and not commercially. Even this 
pilot plant data has not been available for us to evaluate directly, 
due to vendors' competitiveness concerns.
    Europe has adopted a 50 ppm cap sulfur standard for all diesel fuel 
which takes effect in 2005. Some countries, including England, have 
implemented tax incentives for refiners to produce this fuel sooner. 
The majority of diesel fuel in England already meets the 50 ppm 
specification. Refiners have reported no troubles with this technology. 
This diesel fuel is being produced in one-stage hydrotreaters. However, 
as mentioned above, European diesel fuel contains less heavier 
compounds than diesel fuel in the U.S., so the use of one-stage 
conventional hydrotreating to meet very low sulfur levels is 
applicable, but not sufficient to demonstrate feasibility in the U.S. 
Germany has also established a tax incentive, but for diesel fuel 
containing 10 ppm or less sulfur. One European technology vendor 
indicated that they have already licensed two desulfurization units to 
German refiners planning to produce diesel fuel to obtain this tax 
credit. Europe also is considering a 10 ppm sulfur cap to take effect 
later in the decade. However, no refiner is currently producing number 
two diesel fuel to this specification.
    Phillips Petroleum is currently in the process of designing and 
constructing a commercial sized S-Zorb unit to produce sub-15 ppm 
diesel fuel at their Borger, Texas refinery. This plant is scheduled to 
begin commercial operation in 2004. This may not be in time to give 
refiners sufficient confidence in this novel process to rely on it to 
meet the 2006 deadline. However, this process, with its attendant 
hydrogen, cost, and global emission savings should be available for 
those refiners that are able to defer investment under the temporary 
compliance option and hardship provisions of today's rule. While we are 
confident that this and other technology will be available to meet the 
requirements of today's rule, EPA will work with the Department of 
Energy, refiners and technology providers to continue to monitor and 
analyze the progress in further developing and implementing this new 
diesel desulfurization technology. This will allow us to improve our 
understanding of how this new technology can be employed to enhance the 
implementation of this program.
3. Feasibility of Distributing Low Sulfur Highway Diesel Fuel
    We believe that with relatively minor changes and associated costs, 
the existing distribution system will be capable of adequately managing 
sulfur contamination during the transportation of 15 ppm highway diesel 
fuel from the refinery through to the end-user. Further, we believe 
that the existing system is capable of handling two grades of highway 
diesel fuel (500 ppm and 15 ppm sulfur cap) in a limited fashion during 
the transition period of the sulfur program at acceptable cost with the 
addition of storage tanks at a fraction of distributor facilities.
    The following minor changes in distribution practices will be 
needed as a result of today's rule during the transition years of the 
fuel program when various hardship and optional compliance provisions 
are in effect and thereafter:
    --To adequately separate shipments of highway diesel fuel from 
shipments of higher sulfur products, pipeline operators will need to 
increase the amount of highway diesel fuel that they downgrade to a 
lower value product.
    --Instead of cutting the mixture of jet fuel and highway diesel 
fuel that results during pipeline shipments of these products into the 
highway diesel pool, pipeline operators will need to segregate this 
mixture and sell it into the nonroad diesel pool. This change will 
necessitate the addition at some terminals of small tanks to handle the 
mixture of jet fuel and highway diesel fuel.
    --Terminal operators will need to perform additional quality 
control testing to ensure compliance with the 15 ppm sulfur cap.
    We also recognize that tank truck operators will need to more 
carefully and consistently observe current industry practices to limit 
contamination during the transport of 15 ppm sulfur highway diesel 
fuel. However, because these practices already exist and need only to 
be better enforced by distributors, we continue to believe that this 
can be accomplished at insignificant cost. We believe that there will 
not be a significant increase in the volume of highway diesel fuel 
discovered to exceed the sulfur standard downstream of the refinery as 
a result of today's rule. Distributors will quickly optimize the 
distribution system using the means described above to avoid creating 
additional volumes of out of specification product.
    To accommodate two grades of highway diesel fuel during the 
transition period, additional storage tanks will need to be added at 
some refineries, terminals, bulk plants, and truck stops. There are 
significant costs associated with the addition of tanks which are fully 
accounted for during the transition period (see Section V). Commenters 
on the NPRM stated that in addition to the substantial economic burden 
that adding additional storage tanks would represent for some 
distributors, limitations in available space and permitting 
restrictions could preclude some distributors from installing 
additional tanks. This transition is also an added concern for those 
users of specialty fuels (i.e., military fuels, etc.) who currently 
compete for the limited storage tanks because these fuels must be 
segregated. We believe that the burden of adding new storage tanks to 
the system is made manageable by the fact that not all distributors 
will need to handle 500 ppm as well as 15 ppm sulfur highway diesel 
fuel during this time period. Marketplace forces will determine which 
facilities assume the additional burden of handling both grades of 
highway diesel fuel. Those facilities for which the addition of a 
storage tank would represent an unacceptable burden would opt not to 
serve the 500 ppm sulfur highway diesel market during the transition 
years.
    We received several comments on the proposed rule that substantial 
uncertainties exist regarding the ability of the distribution system to 
adapt to the added hardship of limiting sulfur contamination of highway 
diesel fuel meeting a 15 ppm sulfur cap. These commenters noted that 
under today's rule other products in the distribution system would have 
a sulfur content of over 300 times the 15 ppm highway diesel fuel 
sulfur cap, and that unavoidable mixing of small quantities of these 
high sulfur products into highway diesel fuel could easily cause the 15 
ppm sulfur cap to be exceeded. To illustrate the magnitude of the 
challenge, these commenters noted that currently the maximum sulfur 
content of any product that shares the distribution system with highway 
diesel fuel is no more than 10 times the current 500 ppm sulfur cap for 
highway diesel fuel.176 Some commenters stated that the only 
way to adequately limit sulfur contamination in the distribution

[[Page 5083]]

of diesel fuel with a 15 ppm sulfur cap may be to create a completely 
segregated system (at an unacceptably high cost). These commenters 
stated that unavoidable contamination could cause many batches of 
highway diesel fuel to be noncompliant with the 15 ppm cap resulting in 
shortages and high costs. Some commenters stated that additional 
evaluation is needed to determine the capability of the distribution 
system to limit contamination to the very low levels necessitated by 
today's rule.
---------------------------------------------------------------------------

    \176\ Nonroad diesel fuel has a sulfur cap of 5,000 ppm versus a 
500 ppm for current highway diesel fuel.
---------------------------------------------------------------------------

    While we acknowledge that today's rule will pose a substantial new 
challenge to the distribution system, we believe that the additional 
measures outlined in this section will substantially address issues 
associated with adequately limiting sulfur contamination during the 
distribution of 15 ppm sulfur highway diesel fuel.177 Its 
true that not all of the potential minute sources of sulfur 
contamination in the distribution sources have been identified and that 
the cumulative magnitude from these sources is uncertain. However, we 
believe that the contamination from such sources, while made more 
significant by the implementation of the 15 ppm sulfur cap, is not of a 
sufficient magnitude to jeopardize the feasibility of distributing low 
sulfur highway diesel fuel. We will work with the Department of Energy, 
refiners and others involved in diesel fuel distribution to analyze, 
compile data, and conduct additional research, where appropriate, to 
not only more fully understand all sources of contamination and 
deliverability in the distribution of diesel fuel below the 15ppm cap, 
but also their impact on the deliverability of other fuels, including 
specialty military fuels. This information will be used, in conjunction 
with information being developed on the operation of emission control 
devices (which are affected by exposure to sulfur), to monitor progress 
on the successful implementation of this final rule which depends on an 
integrated vehicle/fuel systems approach. Please refer to Section V.D. 
on the costs of today's rule to the distribution system, and to the 
Regulatory Impact Analysis and Response to Comments documents for 
additional discussion regarding the feasibility of distributing highway 
diesel fuel with a 15 ppm sulfur cap.
---------------------------------------------------------------------------

    \177\ See the Response to Comments document for this rule.
---------------------------------------------------------------------------

E. What Are the Potential Impacts of the Low Sulfur Diesel Program on 
Lubricity and Other Fuel Properties?

1. What Is Lubricity and Why Might It Be a Concern?
    Engine manufacturers depend on diesel fuel lubricity properties to 
lubricate and protect moving parts within fuel pumps and injection 
systems for reliable performance. Unit injector systems and in-line 
pumps, commonly used in heavy-duty engines, are actuated by cams 
lubricated with crankcase oil, and have minimal sensitivity to fuel 
lubricity. However, rotary and distributor type pumps, commonly used in 
light and medium-duty diesel engines, are completely fuel lubricated, 
resulting in high sensitivity to fuel lubricity.
    In the United States, there is no government or industry standard 
for diesel fuel lubricity. Thus, specifications for lubricity are 
determined by the market. Since the beginning of the 500 ppm sulfur 
highway diesel program in 1993, fuel system producers, engine and 
vehicle manufacturers, and the military have been working with the 
American Society for Testing and Materials (ASTM) to develop protocols 
and standards for diesel fuel lubricity in its D-975 specifications for 
diesel fuel. Although the ASTM has not yet adopted specific protocols 
and standards, we understand that refiners have been treating diesel 
fuel with lubricity additives on a batch to batch basis, when poor 
lubricity fuel is expected. In addition, the military has found that 
traditional corrosion inhibitor additives that it uses in its fuels 
have been highly effective in reducing fuel system component wear. Some 
commenters expressed concern about the impacts of a 15 ppm standard on 
fuel lubricity.
    Experience has shown that it is very rare for a naturally high-
sulfur fuel to have poor lubricity, although, most studies show 
relatively poor overall correlation between sulfur content and 
lubricity. Considerable research remains to be performed for a better 
understanding of the fuel components most responsible for lubricity. 
Consequently, we are uncertain about the potential impacts of the 15 
ppm sulfur standard on fuel lubricity. There is evidence that the 
typical process used to remove sulfur from diesel fuel--hydrotreating--
can impact lubricity depending on the severity of the treatment process 
and characteristics of the crude. Because refiners will likely rely on 
hydrotreating to achieve the proposed sulfur limit, there may be 
reductions in the concentration of those components of diesel fuel 
which contribute to adequate lubricity. As a result, the lubricity of 
some batches of fuel may be reduced compared to today's levels, 
resulting in an increased need for the use of lubricity additives in 
highway diesel fuel. In response to the proposal, all comments 
submitted regarding lubricity either stated or implied that the 
proposed sulfur standard of 15 ppm would likely cause the refined fuel 
to have lubricity characteristics that would be inadequate to protect 
fuel injection equipment, and that mitigation measures such as 
lubricity additives would be necessary. However, the commenters 
suggested varied approaches for addressing lubricity. For example, some 
suggested that we need to establish a lubricity requirement by 
regulation, but others suggested that the current voluntary (market) 
system would be adequate. The Department of Defense recommended that we 
encourage the industry (ASTM) to adopt lubricity protocols and 
standards before the implementation date of the low sulfur fuel 
established by today's action. Other suggested approaches included 
incorporation of biodiesel as a solution to the lubricity issue, and 
the need to further examine the issues.
    Blending small amounts of lubricity-enhancing additives increases 
the lubricity of poor-lubricity fuels to acceptable levels. These 
additives are available in today's market, are effective, and are in 
widespread use around the world. For example, in the U.S., we 
understand that refiners are treating diesel fuel with lubricity 
additives on a batch to batch basis, when poor lubricity fuel is 
expected. Other examples include Sweden, Canada, and the U.S. military. 
Since 1991, the use of lubricity additives in Sweden's 10 ppm sulfur 
Class I fuel and 50 ppm sulfur Class II fuel has resulted in acceptable 
equipment durability.178 Since 1997, Canada has required 
that its 500 ppm sulfur diesel fuel not meeting a minimum lubricity be 
treated with lubricity additives. The U.S. military has found that the 
traditional corrosion inhibitor additives that it uses in its fuels 
have been highly effective in reducing fuel system component wear.
---------------------------------------------------------------------------

    \178\ See letter from MTC to Michael P. Walsh, dated October 16, 
2000. In public docket, document IV-G-42.
---------------------------------------------------------------------------

2. Today's Action on Lubricity: A Voluntary Approach
    We have decided to not establish a lubricity standard in today's 
action, but have included a 0.2 cents per gallon cost in our 
calculations for the economic

[[Page 5084]]

impact to account for the potential increased use of lubricity 
additives (see section V.D.2). We believe the best approach is to allow 
the industry and the market to address the lubricity issue in the most 
economical manner, while avoiding an additional regulatory scheme. A 
voluntary approach should provide adequate customer protection from 
engine failures due to low lubricity, while providing the maximum 
flexibility for the industry. This approach will be a continuation of 
current industry practices for diesel fuel produced to meet the current 
federal and California 500 ppm sulfur diesel fuel specifications, and 
benefits from the considerable experience gained since 1993. It will 
also include any new specifications and test procedures that we expect 
will be adopted by the American Society for Testing and Materials 
(ASTM) regarding lubricity of highway diesel fuel quality.
    We do not believe that an EPA regulation for lubricity is 
appropriate for several reasons. First, the expertise and mechanism for 
a lubricity standard already exist in the industry. According to the 
comments, the industry has been working on a lubricity specification 
for ASTM D-975, and low cost remedies for poor lubricity have already 
been proven and are already being used around the world. Although some 
commenters expressed concerns that the ASTM process might move too 
slowly to establish a lubricity specification by 2006, we fully expect 
the refining industry, engine manufacturers and end users to work 
together to resolve any issues as part of their normal process in 
dealing with customer and supplier fuel quality issues. Today's action 
will increase the urgency of those working to establish an ASTM D-975 
lubricity specification, and we believe they will do so in time for the 
production and distribution of the low sulfur highway diesel fuel. We 
will do our part to encourage the ASTM process be brought to a 
successful conclusion.
    Second, we have no firm basis to justify a lubricity specification 
in today's action. One such basis might be adequate demonstration that 
a lubricity level below or above a certain specification would either 
cause emissions to increase, or hinder the operation of emission 
control equipment. However, we have no evidence that lubricity impacts 
emissions, or emission control equipment. This issue is primarily a 
concern about equipment performance. Equipment performance is more 
appropriately addressed by the industry rather than government 
regulation by this Agency.
    Third, even if we had a statutory basis to justify a lubricity 
standard, we are concerned that establishing an EPA lubricity 
regulation would provoke the same disagreements that the industry is 
now engaged in its efforts to establish an ASTM D-975 specification. We 
are in no better position to judge those issues than the industry 
experts who are already involved. Further, once a specification is put 
into the regulations and the industry subsequently determines that the 
specification should be changed, based on new information or 
circumstances, the burden would be on us to amend the mandated 
specification by rulemaking. This is a significant burden to put on the 
Agency for an engine performance issue that can and should be resolved 
by the industry without government intervention.
    Subsequent to the close of the comment period another issue related 
to lubricity concerns was raised to the Agency. These concerns related 
to potential incompatibilities in old vehicles of the new engine oils 
the industry hopes to develop for use in the new 2007 and later model 
year vehicles. Much of the ash in today's motor oil results from the 
need to control acidification of the engine oil (maintain total base 
number, or TBN control), which is in large part a function of the 
sulfur content of the fuel and the sulfuric acid that it forms. Without 
the ability to control acidification of the engine oil, engine wear 
increases significantly. The ash in the oil, however, will tend to 
shorten the maintenance intervals for particulate filters to remove 
built up ash on new 2007 and later model year vehicles. At the same 
time, engines operated on low sulfur fuel have much less need for TBN 
control and the high ash levels that result. Consequently, 
manufacturers are investigating with the lubricant industry the 
potential of lower ash oils for use in engines operated on low sulfur 
diesel fuel and equipped with particulate traps. If the new oil 
developed is not ``backwards compatible'' to sufficiently control 
acidification and wear in the pre-existing fleet of vehicles on the 
road that may still be operated on high sulfur diesel fuel for the 
first few years of the program, then two grades of motor oil would have 
to be on the market simultaneously. This has caused some stakeholders 
to raise vehicle performance and durability concerns that might result 
from using the new oil in the old vehicles--namely ``mis-oiling.''
    Since the engine and lubricant industries still have a number of 
years to develop these new oil formulations, it is still premature to 
determine whether or not the new oils will be backwards compatible and 
whether mis-oiling would raise any serious concerns. While this would 
not appear to be an air quality concern and as such something the 
Agency generally leaves up to the industry to resolve, we will 
nevertheless offer to work with the industry and industry associations 
on this issue over the coming years.'' EPA anticipates that engine 
manufacturers would likely provide engine labels to distinguish low ash 
oil from high ash oil because misoiling could result in engine damage.
3. What Are Today's Actions on Fuel Properties Other Than Sulfur?
    We are not taking action today on any fuel properties other than 
sulfur. We have examined the impact of fuel properties other than 
sulfur, such as aromatics, on the materials used in engines and fuel 
supply systems. We do not believe there will be impacts on materials 
from such other fuel properties.
    While there were some problems with leaks from fuel pump O-ring 
seals made of a certain material (Nitrile) after the introduction of 
500 ppm sulfur diesel fuel in the United States in 1993, these issues 
have since been addressed by equipment manufacturers who switched to 
materials that are compatible with low aromatic fuels. The leakage from 
the Nitrile seals was determined to be due to low aromatics levels in 
some 500 ppm sulfur fuel, not the low sulfur levels. In the process of 
lowering the sulfur content of some fuel, some of the aromatics had 
also been removed. Normally, the aromatics in the fuel penetrate the 
Nitrile material and cause it to swell, thereby providing a seal with 
the throttle shaft. When low-aromatics fuel is used after conventional 
fuel has been used, the aromatics already in the swelled O-ring will 
leach out into the low-aromatics fuel. Subsequently, the Nitrile O-ring 
will shrink and pull away, thus causing leaks, or the stress on the O-
ring during the leaching process will cause it to crack and leak. Not 
all 500 ppm sulfur fuels caused this problem, because the amount and 
type of aromatics varied. Fuel pumps using a different material (Viton) 
for the seals did not experience leakage. We believe that no additional 
problems will occur with a change of fuel from 500 to 15 ppm sulfur.

F. How Are State Programs Affected by the Low Sulfur Diesel Program?

1. State Preemption
    Section 211(c)(4)(A) of the CAA prohibits states (and political

[[Page 5085]]

subdivisions of states) from prescribing or attempting to enforce 
controls or prohibitions respecting any fuel characteristic or 
component if EPA has prescribed a control or prohibition applicable to 
such fuel characteristic or component under section 211(c)(1). This 
preemption applies to all states except California, as explained in 
section 211(c)(4)(B). For states other than California, the Act 
provides two mechanisms for avoiding preemption. First, section 
211(c)(4)(A)(ii) creates an exception to preemption for state 
prohibitions or controls that are identical 179 to the 
prohibition or control adopted by EPA. Second, states may seek EPA 
approval of SIP revisions containing fuel control measures, as 
described in section 211(c)(4)(C). We may approve such SIP revisions, 
and thereby ``waive'' preemption, only if it finds the state control or 
prohibition ``is necessary to achieve the national primary or secondary 
ambient air quality standard which the plan implements.''
---------------------------------------------------------------------------

    \179\ In evaluating whether a state fuel prohibition or control 
is ``identical'' to a prohibition or control adopted by us, we might 
consider but is not limited to the following factors in comparing 
the measures: (1) The level of an emission reduction or pollution 
control standard for any particular batch of diesel fuel; (2) the 
use of ``per gallon'' or ``averaged'' amounts in setting that level; 
(3) the lead time allowed to the affected industry for compliance; 
(4) the test method(s) and sampling requirements used in determining 
compliance; and (5) reporting and recordkeeping requirements.
---------------------------------------------------------------------------

    When we adopted the current highway diesel fuel sulfur standard of 
500 ppm pursuant to our authority under section 211(c)(1) of the CAA in 
1990, States were preempted from also doing so under the provisions of 
section 211(c)(4)(A). The 15 ppm highway diesel fuel sulfur standard 
promulgated today modifies the existing standard and, as a result, do 
not initiate any new preemption of state authority. Today's action 
continues the explicit preemption under section 211(c)(4)(A) of state 
actions to prescribe or enforce highway diesel fuel sulfur controls. 
States other than California with highway diesel fuel sulfur control 
programs not already approved into their SIPs are preempted under 
Section 211(c)(4)(A) and will therefore need to obtain a waiver from us 
under the provisions described in section 211(c)(4)(C) for all state 
fuel sulfur control measures, unless the state control or prohibition 
is identical to ours.
    Aside from the explicit preemption in Section 211(c)(4)(A), a court 
could also consider whether a state sulfur control is implicitly 
preempted under the Supremacy Clause of the U.S. Constitution. Courts 
have determined that a state law is preempted by federal law where the 
state requirement actually conflicts with federal law by preventing 
compliance with both federal and state requirements, or by standing as 
an obstacle to accomplishment of Congressional objectives. A court 
could thus consider whether a given state sulfur control is preempted, 
notwithstanding waiver of preemption under 211(c)(4)(C), if it places 
such significant cost and investment burdens on refiners that refiners 
cannot meet both state and federal requirements in time, or if the 
state control would otherwise meet the criteria for conflict 
preemption.
2. What Provisions Apply in Alaska?
    There are important nationwide environmental and public health 
benefits that will be achieved with cleaner diesel engines and fuel, 
particularly from reduced particulate emissions, nitrogen oxides, and 
air toxics (as further discussed in section II). Therefore, it is also 
important to implement this program in Alaska. Any 2007 and later model 
year diesel vehicles in Alaska, or driven to Alaska, must be fueled 
with low sulfur highway diesel, or risk potential damage to the 
aftertreatment technologies or even the engines themselves. Although 
the engine standards established today are not based upon different 
technology and cost implications for Alaska as compared to the rest of 
the country, the low sulfur fuel program has different implications.
    Unlike the rest of the nation, Alaska is currently exempt from the 
500 ppm sulfur standard for highway diesel fuel and dye requirements. 
Since the beginning of the 500 ppm highway diesel fuel program, we have 
granted Alaska exemptions from meeting the sulfur standard and dye 
requirements, because of its unique geographical, meteorological, air 
quality, and economic factors. (These unique factors are discussed 
generally in this section, and in more detail in the RIA.) Because of 
these unique factors, we are establishing in today's action an 
alternative option for implementing the low sulfur fuel program in 
Alaska.
    We are providing the State of Alaska an opportunity to develop an 
alternative low sulfur transition plan. We intend to facilitate the 
development of this plan by working in close cooperation with the state 
and key stakeholders. This plan must ensure that sufficient supplies of 
low sulfur diesel fuel are available in Alaska to meet the demand of 
any new 2007 and later model year diesel vehicles. Given that Alaska's 
demand for highway diesel fuel is very low and only a small number of 
new diesel vehicles are introduced in Alaska each year, it may be 
possible to develop an alternative implementation plan for Alaska in 
the early years of the program that provides low sulfur diesel only in 
sufficient quantities to meet the demand from the small number of new 
diesel vehicles. This would give Alaska refiners more flexibility 
during the transition period because they would not have to desulfurize 
the entire highway diesel volume. Our goal in offering this additional 
flexibility is to transition Alaska into the low sulfur fuel program in 
a manner that minimizes costs, while still ensuring that the new 
vehicles receive the low sulfur fuel they need. We expect that the 
transition plan will begin to be implemented at the same time as the 
national program, but the state will have an opportunity to determine 
what volumes of low sulfur fuel must be supplied, and in what 
timeframes, in different areas of the state.
    At a minimum, this transition plan must: (1) Ensure an adequate 
supply (either through production or imports) of 15 ppm fuel to meet 
the demand of any 2007 or later model year vehicles, (2) ensure 
sufficient retail availability of low sulfur fuel for new vehicles in 
Alaska, (3) address the growth of supply and availability over time as 
more new vehicles enter the fleet, (4) include measures to ensure 
segregation of the 15 ppm fuel and avoid contamination and misfueling, 
and (5) ensure enforceability. We anticipate that, to develop a 
workable transition plan, the state will likely work in close 
cooperation with refiners and other key stakeholders, including 
retailers, distributors, truckers, engine manufacturers, environmental 
groups, and other interested groups. For example, the state will likely 
rely on input from the trucking industry in determining the expected 
low sulfur fuel volume needed in Alaska, based on the anticipated 
number of new vehicles, and how this volume is expected to grow during 
the first few years of the program. Similarly, the state will likely 
rely on the Alaska refiners' input regarding plans for supplying 
(either through production or imports) low sulfur fuel to meet the 
expected demand. Further, the state will likely rely on input and 
cooperation from retailers and distributors to determine at which 
locations the low sulfur fuel should be made available. Retailers 
offering low sulfur fuel will have to take measures to prevent 
misfueling, such as pump labeling, which must include

[[Page 5086]]

provisions that are at least as stringent as those required of 
retailers nationally by the regulations and as described in section 
VII. Similarly, all parties in the distribution system must ensure the 
low sulfur fuel remains segregated and must take measures to prevent 
sulfur contamination, in a manner that is at least as stringent as that 
required nationally by the regulations and as described in section VII.
    If the state anticipates that the primary demand for low sulfur 
fuel will be along the highway system (e.g., to address truck traffic 
from the lower-48 states) in the early years of the program, then the 
initial stages of the transition plan could be focused in these areas. 
We believe it would be appropriate for the state to consider an 
extended transition schedule for implementing the low sulfur program in 
rural Alaska, as part of the state's overall plan, based on when they 
anticipate the introduction of a significant number of 2007 and later 
model year vehicles in the remote areas.
    Under this approach, the state will be given the opportunity to 
develop such a transition plan, as an alternative to the national 
program, and submit it to us for approval. We intend to help facilitate 
the development of the plan, by working closely with the state and the 
relevant stakeholders so they will have an opportunity to address our 
concerns in their submittal. It is our intent that any flexibility that 
is available to small refiners nationwide (as described in Section IV) 
will also be available to small refiners in Alaska under an approved 
alternative transition plan. To ensure that refineries and other 
affected parties will have certainty regarding their regulatory 
requirements with adequate lead time, Alaska must submit this plan by 
April 1, 2002 (approximately one year after the effective date of 
today's rule). If Alaska submits such a plan to us within one year, and 
if it provides a reasonable alternative as described above, we will 
conduct a rulemaking with notice for public comment and then publish a 
final rule promulgating the new regulatory scheme for Alaska. Our 
intent is to issue such a final rule within one year of Alaska's 
submittal of the plan. However, if the state chooses not to submit an 
alternative plan, or if the plan it submits does not provide a 
reasonable alternative for Alaska as described above, then refiners and 
other regulated parties in Alaska will be subject to the national 
program, including the implementation schedule established in today's 
action, without further regulatory action.
a. Today's Action Regarding the 500 ppm Standard in Alaska
    We are extending the existing temporary exemption from the current 
diesel fuel sulfur standard of 500 ppm for the areas of Alaska served 
by the Federal Aid Highway System (FAHS) to the effective date for the 
new standard (i.e., June 1, 2006 at the refinery level; July 15, 2006 
at the terminal level; and September 1, 2006 at all downstream 
locations). While Alaska submitted a petition for a permanent exemption 
from the 500 ppm standard for these areas, we are not taking further 
action on that petition. Our goal is to take action on that petition in 
a way that minimizes costs through Alaska's transition to the new low 
sulfur program. The cost of compliance could be reduced if Alaska 
refiners were given the flexibility to meet the low sulfur standard in 
one step, rather than two steps (i.e., once for the current 500 ppm 
sulfur standard in 2004 when the temporary exemption expires, and again 
for the new 15 ppm standard in 2006).
    As already discussed, we are allowing Alaska to develop an 
alternative transition plan for implementing the low sulfur diesel fuel 
program. During such a transition period, it is possible that both low 
sulfur diesel fuel (for 2007 and later model year vehicles) and higher 
sulfur (for older vehicles) highway fuels might be available in Alaska. 
To avoid the two-step sulfur program described above during an 
alternative transition period, we will consider additional extensions 
to the temporary exemption of the 500 ppm standard beyond 2006 (e.g., 
for that portion of the highway diesel pool that is available for the 
pre-2007 vehicles) during Alaska's transition period. We will make a 
decision on any additional temporary extensions, if appropriate, in the 
context of the separate rulemaking taking action on the alternative 
transition plan submitted by Alaska.
    As in previous actions to grant Alaska sulfur exemptions, we will 
not base any vehicle or engine recall on emissions exceedences caused 
by the use of high-sulfur (>500 ppm) fuel in Alaska during the period 
of the temporary sulfur exemption. Our in-use testing goals are to 
establish whether representative engines, when properly maintained and 
used, will meet emission standards for their useful lives. These goals 
are consistent with the requirements for recall outlined in Section 
207(c)(1) of the CAA. Further, manufacturers may have a reasonable 
basis for denying emission related warranties where damage or failures 
are caused by the use of high sulfur fuel in Alaska.
    The Engine Manufacturers Association commented that the level of 
protection provided to engine manufacturers under the current exemption 
for Alaska and the proposal, as described above, falls short of what is 
reasonable and necessary. It asserted that the use of high sulfur 
diesel fuel by an engine should raise a ``rebuttable presumption'' that 
the fuel has caused the engine failure, and that EPA should have the 
burden of rebutting that presumption. It also asserted that the 
emissions warranty is a regulatory requirement under Section 207, that 
only EPA has the authority to exclude claims based on the use of high 
sulfur diesel fuel. We understand and concur with the manufacturers' 
concerns about in-use testing of engines operated in an area exempt 
from fuel sulfur requirements. Consequently, we affirm that, for recall 
purposes, we will not seek to conduct or cause the in-use testing of 
engines we know have been exposed to high sulfur fuels. We will likely 
screen any engines used in our testing program to see if they have been 
operated in the exempt area. We believe we can readily obtain 
sufficient samples of engines without testing engines from exempt 
areas. Also, in any recall that we order, manufacturers have the option 
of requesting a public hearing. The use of engines that have seen high 
sulfur fuel will increase the likelihood of a recall hearing. We expect 
manufacturers to scrutinize any test engines for sulfur usage that were 
used to justify an ordered recall. In reviewing the warranty concerns 
of the Engine Manufacturers Association, we have determined that our 
position regarding warranties, as previously stated and described 
above, is consistent with section 207(a) and (b) of the CAA and does 
not require any new or amended regulatory language to implement.
    Today's action also grants Alaska's request for a permanent 
exemption from the dye requirement of 40 CFR 80.29 and 40 CFR 80.446 
for the entire state. The costs of complying with the low sulfur (both 
the current 500 ppm sulfur and new 15 ppm sulfur) diesel fuel 
requirements could be reduced significantly if Alaska were not required 
to dye the non-highway fuel. Dye contamination of other fuels, 
particularly jet fuel, is a serious potential problem. This is a 
serious issue in Alaska since the same transport and storage tanks used 
for jet fuel (which is more than half of Alaska's distillate market) 
are generally also used for other diesel products, including off-
highway diesel products which are required to be dyed under the current

[[Page 5087]]

national program. This issue is discussed further in the RIA (Chapter 
VIII).
b. Why Are We Treating Alaska Uniquely?
    Section 211(i)(4) of the Clean Air Act (CAA) provides that the 
states of Alaska and Hawaii may seek an exemption from the diesel fuel 
sulfur standard (500 ppm as specified in section 211(i)) in the same 
manner as provided in section 325 of the CAA. The requested exemption 
could be granted if EPA determines that compliance with such 
requirement is not feasible or is unreasonable due to unique 
geographical, meteorological, or economic factors of the territory, or 
other local factors as EPA considers significant.
    On February 12, 1993, Alaska submitted a petition under section 325 
of the CAA to exempt highway vehicle diesel fuel in Alaska from 
paragraphs (1) and (2) of section 211(i) of the CAA, except for the 
minimum cetane index requirement.180 The petition requested 
that we temporarily exempt highway vehicle diesel fuel in communities 
served by the FAHS from meeting the sulfur content (500 ppm) specified 
in section 211(i) of the CAA and the dye requirement for non-highway 
diesel fuel of 40 CFR 80.29, until October 1, 1996. The petition also 
requested a permanent exemption from those requirements for areas of 
Alaska not reachable by the FAHS'the remote areas. On March 22, 1994, 
(59 FR 13610), we granted the petition based on geographical, 
meteorological, air quality, and economic factors unique to Alaska.
---------------------------------------------------------------------------

    \180\ Copies of information regarding Alaska's petition for 
exemption, subsequent requests by Alaska, public comments received, 
and actions by EPA area available in public docket A-96-26.
---------------------------------------------------------------------------

    On December 12, 1995, Alaska submitted a petition for a permanent 
exemption for all areas of the state served by the FAHS, that is, those 
areas covered only by the temporary exemption. On August 19, 1996, we 
extended the temporary exemption until October 1, 1998 (61 FR 42812), 
to give us time to consider comments to that petition that were 
subsequently submitted by stakeholders. On April 28, 1998 (63 FR 23241) 
we proposed to grant the petition for permanent exemption. Substantial 
public comments and substantive new information were submitted in 
response to the proposal. To give us time to consider those comments 
and new information, we extended the temporary exemption for another 
nine months until July 1, 1999 (September 16, 1998, 63 FR 49459). 
During this time period, we started work on a nationwide rule to 
consider more stringent diesel fuel requirements, particularly for the 
sulfur content (today's action). To coordinate the decision on Alaska's 
request for a permanent exemption with the new nationwide rule on 
diesel fuel quality, we extended the temporary exemption until January 
1, 2004 (June 25, 1999, 64 FR 34126).
    As discussed in the previous section, in today's action we are 
extending the temporary exemption from the 500 ppm diesel fuel sulfur 
standard to the effective date for the new nationwide 15 ppm diesel 
fuel sulfur standard in 2006. While it is important to implement in 
Alaska the cleaner diesel engines and fuel of today's action, our goal 
is to take action on the petition in a way that minimizes costs through 
Alaska's transition to the new low sulfur program. The cost of 
compliance could be reduced if Alaska refiners were given the 
flexibility to meet the low sulfur standard in one step (i.e., going 
straight from uncontrolled levels to the 15 ppm sulfur standard), 
rather than in two steps. We considered the prior public comments we 
received as a result of our previous notices and actions regarding 
exemptions from the 500 ppm sulfur standard for highway diesel fuel in 
Alaska (see RIA).
    Unlike in the rest of the country, diesel fuel consumption for 
highway use in Alaska represents only five percent of the State's total 
distillate fuel consumption. Aviation and marine applications, power 
generation and heating consume most of the distillate, while Alaska's 
highway diesel vehicle fleet is relatively small, particularly outside 
the FAHS. The state estimates that there are less than 9000 diesel 
vehicles in the entire state, with less than 600 of these vehicles in 
all of rural Alaska. The state also indicates that new model vehicles 
are introduced into the Alaska market at a slower rate than elsewhere, 
thus Alaska does not need to transition its highway fuel to low sulfur 
as quickly as the rest of the nation.
    Most of the fuel consumed in Alaska is produced by refineries 
located in Alaska. This is primarily because of the more severe cloud 
point specification needed for the extremely low temperatures 
experienced in much of Alaska during the winter and the high cost to 
import fuel that is produced elsewhere. There are four commercial 
refineries in Alaska. Only one of these refineries currently has any 
desulfurization capacity, which is relatively small. Consequently, 
because these refineries will have to reduce sulfur from uncontrolled 
levels to meet the new 15 ppm standard established by today's action, 
these refineries could incur substantially higher costs than those in 
the rest of the nation. Given the very small highway diesel demand, 
however, it is doubtful that more than one or two Alaska refineries 
will choose to produce low sulfur highway fuel, and these refiners 
could even decide to import it from refineries outside of Alaska.
    Further, Alaska's fuel distribution system faces many unique 
challenges. Unlike the rest of the country, because of its current 
exemption from the 500 ppm sulfur standard and dye requirements, Alaska 
does not currently segregate highway diesel fuel from that used for 
off-road, marine, heating oil, and other distillate uses. Therefore, 
the distribution system costs for segregating a low sulfur grade of 
diesel for highway uses will be significant. The existing fuel storage 
facilities limit the number of fuel types that can be stored. In 
addition to significant obstacles to expanding tankage in Alaska, the 
cost of constructing separate storage facilities, and providing 
separate tanks for transporting low sulfur diesel fuel (e.g., by barge 
or truck), could be significant. Most of Alaska's communities rely on 
barge deliveries, and ice formation on the navigable waters during the 
winter months restricts fuel delivery to these areas. Construction 
costs are 30 percent higher in Alaska than in the lower-48 states, due 
to higher costs for freight deliveries, materials, electrical, 
mechanical, and labor. There is also a shorter period of time during 
which construction can occur, because of seasonal extremes in 
temperature and the amount of daily sunlight.
    The severe impacts to Alaska's fuel distribution system of 
implementing a low sulfur requirement for highway diesel fuel would 
likely occur whether we require the current 500 ppm standard or the new 
15 ppm standard. The impacts to Alaska's refineries and fuel importers 
are greater at 15 ppm than at 500 ppm. It is likely that the refiners 
and fuel importers would have a significant incremental impact if we 
required Alaska to implement the 500 ppm diesel fuel sulfur standard in 
2004 when the current exemption expires, and the 15 ppm diesel fuel 
sulfur standard in 2006 when the new national requirement becomes 
effective, rather than only once for the 15 ppm diesel fuel sulfur 
standard in 2006.

[[Page 5088]]

3. What Provisions Apply in American Samoa, Guam, and the Commonwealth 
of Northern Mariana Islands?
a. Today's Action Regarding the Highway Diesel Fuel Standard in the 
Territories
    As we proposed, today's action excludes American Samoa, Guam and 
the Commonwealth of Northern Mariana Islands from the new diesel fuel 
sulfur requirement of 15 ppm and the 2007 heavy-duty diesel vehicle and 
engine emissions standards, and other requirements associated with 
those emission standards. The territories will continue to have access 
to 2006 heavy-duty diesel vehicle and engine technologies, at least as 
long as manufacturers choose to market those technologies. We will not, 
however, allow the emissions control technology in the territories to 
backslide from those available in 2006. If, in the future, 
manufacturers choose to market only heavy-duty diesel vehicles and 
engines with 2007 and later emission control technologies, we believe 
the market will determine when and if the territories will make the 
investment needed to obtain and distribute the low sulfur diesel fuel 
necessary to support these technologies.
    This exclusion from emission standards does not apply to the new 
heavy-duty gasoline engine and vehicle emission standards, because low 
sulfur gasoline that complies with our regulations will be available, 
and so concerns about damage to engines and emissions control systems 
will not exist. This exclusion from emission standards also does not 
apply to light-duty diesel vehicles and trucks because gasoline 
vehicles and trucks meeting the emission standards and capable of 
fulfilling the same functions will be available. We believe that the 
market will determine when and if having access to new light-duty 
diesel technologies in the territories, in place of or in addition to 
gasoline technologies, is important enough to obtain and distribute the 
low sulfur diesel fuel needed to support those technologies.
    As we also proposed, we are requiring all heavy-duty diesel motor 
vehicles and engines for these territories to be certified and labeled 
to the applicable requirements (either to the 2006 model year standards 
and associated requirements under the exclusion, or to the standards 
and associated requirements applicable for the model year of production 
under the nationwide requirements) and warranted, as otherwise required 
under the Clean Air Act and EPA regulations. Special recall and 
warranty considerations due to the use of excluded high sulfur fuel are 
the same as those for Alaska during its exemption and transition 
periods (see the discussion in previous section). To protect against 
this exclusion being used to circumvent the emission requirements 
applicable to the rest of the United States (i.e., continental United 
States, Alaska, Hawaii, Puerto Rico and the U.S. Virgin Islands) after 
2006 by routing exempted (pre-2007 technology) vehicles and engines 
through one of these territories, we are restricting the importation of 
vehicles and engines from these territories into the rest of the United 
States. After the 2006 model year, diesel vehicles and engines 
certified under this exclusion to meet the 2006 model year emission 
standards for sale in American Samoa, Guam and the Commonwealth of the 
Northern Mariana Islands will not be permitted entry into the rest of 
the United States.
b. Why Are We Treating These Territories Uniquely?
    Unlike the rest of the nation (except Alaska), these territories 
are currently exempt from the 500 ppm sulfur standard for highway 
diesel fuel. Section 325 of the CAA provides that upon request of Guam, 
American Samoa, the Virgin Islands, or the Commonwealth of the Northern 
Mariana Islands, we may exempt any person or source, or class of 
persons or sources, in that territory from any requirement of the CAA, 
with some specific exceptions. The requested exemption could be granted 
if we determine that compliance with such requirement is not feasible 
or is unreasonable due to unique geographical, meteorological, or 
economic factors of the territory, or other local factors as we 
consider significant.
    Prior to the effective date of the current highway diesel sulfur 
standard of 500 ppm, the territories of American Samoa, Guam and the 
Commonwealth of Northern Mariana Islands petitioned us for an exemption 
under section 325 of the CAA from the sulfur requirement under section 
211(i) of the CAA and associated regulations at 40 CFR 80.29. The 
petitions were based on geographical, meteorological, air quality, and 
economic factors unique to those territories. We subsequently granted 
the petitions.181
---------------------------------------------------------------------------

    \181\ See 57 FR 32010, July 20, 1992 for American Samoa; 57 FR 
32010, July 30, 1992 for Guam; and 59 FR 26129, May 19, 1994 for 
CNMI.
---------------------------------------------------------------------------

    These U.S. territories are islands with limited transportation 
networks. Combined, these three territories have only approximately 
1300 registered diesel vehicles. Diesel fuel consumption in these 
vehicles represents just a tiny fraction of the total diesel fuel 
volume consumed on these islands; the bulk of diesel fuel is burned in 
marine, nonroad, and stationary applications. Consequently highway 
diesel vehicles are believed to have a negligible impact on the air 
quality in these territories, which, with minor exceptions, is very 
good.
    All three of these territories lack internal petroleum supplies and 
refining capabilities and rely on long distance imports. Given their 
remote location from Hawaii and the U.S. mainland, most petroleum 
products are imported from East rim nations, particularly Singapore. 
Although Australia, the Philippines, and certain other Asian countries 
have or will soon require low sulfur diesel fuel, their sulfur limit is 
500 ppm, not the new 15 ppm sulfur limit established by today's action 
for the United States. Compliance with low sulfur (15 ppm) requirements 
for highway fuel would require construction of separate storage and 
handling facilities for small quantities of a unique grade of diesel 
fuel for highway purposes, or use of low sulfur (15 ppm) diesel fuel 
for all purposes to avoid segregation. Either of these alternatives 
would require importation of the low sulfur fuel from Hawaii or the 
U.S. mainland, and would significantly add to the already high cost of 
diesel fuel in these territories, which rely heavily on United States 
support for their economies.

G. Refinery Air Permitting

    Prior to making diesel desulfurization changes, some refineries may 
be required to obtain a preconstruction permit, under the New Source 
Review (NSR) program, from the applicable state/local air pollution 
control agency.182 We believe that today's program provides 
sufficient lead time for refiners to obtain any necessary NSR permits 
well in advance of the compliance date. Further, refiners will be able 
to stagger their construction of desulfurization projects, since many

[[Page 5089]]

refineries could take advantage of the temporary compliance option for 
low sulfur diesel fuel from 2006-2009, as described in Section IV.A. 
Although some refiners commented that obtaining air permits would be a 
factor in their ability to comply in the 2006 time frame, state/local 
agencies commented that they will make the issuance of permits a top 
priority, because they strongly support achieving the environmental 
objectives of the low sulfur highway diesel program. State/local 
agencies further commented that they are committed to working with all 
affected parties to expedite the processing and issuance of any 
necessary permits.
---------------------------------------------------------------------------

    \182\ Hydrotreating diesel fuel involves the use of process 
heaters, which have the potential to emit pollutants associated with 
combustion, such as NOX, PM, CO and SO2. In 
addition, reconfiguring refinery processes to add desulfurization 
equipment could increase fugitive VOC emissions. The emissions 
increases associated with diesel desulfurization will vary widely 
from refinery to refinery, depending on many source-specific 
factors, such as crude oil supply, refinery configuration, type of 
desulfurization technology, amount of diesel fuel produced, and type 
of fuel used to fire the process heaters.
---------------------------------------------------------------------------

    For the Tier 2/gasoline sulfur control program promulgated in 
December 1999, refiners had expressed concerns that permit delays might 
impede their ability to meet compliance dates. Although we believed 
that the Tier 2 program provided sufficient lead time for refiners to 
obtain permits, we committed to undertake several actions to minimize 
the possibility of any delays for refineries obtaining major NSR 
permits for gasoline desulfurization projects. These actions include 
providing federal guidance on emission control 
technologies183 and the appropriate use of motor vehicle 
emission reductions (resulting from the use of low sulfur gasoline), 
where available, as emission offsets, as well as forming EPA permit 
teams to assist states in quickly resolving issues, where needed. These 
three items are discussed in more detail in the Tier 2 final rule (see 
65 FR 6773, Feb. 10, 2000).
---------------------------------------------------------------------------

    \183\ Best Available Control Technology (BACT) and Lowest 
Achievable Emission Rate (LAER) technology.
---------------------------------------------------------------------------

    Given that today's diesel sulfur program provides more than five 
years of lead time, as well as an additional transitional period, we 
believe refiners will have ample time to obtain any necessary 
preconstruction permits. Nevertheless, we believe it is reasonable to 
continue our efforts under the Tier 2 program, as described above, to 
help states in facilitating the issuance of permits under the highway 
diesel sulfur program. For example, the guidance on BACT and LAER 
control technology that is currently under development for the gasoline 
sulfur program should have application for diesel desulfurization 
projects as well. We will plan to reevaluate this guidance to the 
extent that it may need to be revised or updated for application to 
highway diesel desulfurization projects. Similarly, we believe the 
concept of EPA permit teams for gasoline sulfur projects could readily 
be extended to permits related to diesel projects as well. These teams 
will track the overall progress of permit issuance and will be 
available to assist state/local permitting authorities, refineries and 
the public upon request to resolve site-specific permitting questions. 
Further, in Tier 2, we announced our plan to issue guidance to help 
states determine whether and to what extent they may wish to use 
vehicle emissions reductions as offsets for refineries implementing 
gasoline desulfurization projects. We are currently in the process of 
evaluating public comments received on the draft guidance relating to 
the use of Tier 2 reductions as refinery offsets. Whatever resolution 
we determine is appropriate for this guidance in the Tier 2 context, we 
plan to apply a similar approach for diesel desulfurization projects as 
well. Finally, to facilitate the processing of permits, we encourage 
refineries to begin discussions with permitting agencies and to submit 
permit applications as early as possible.

V. Economic Impact

    This Section discusses the projected economic impact and cost 
effectiveness of the emission standards and low-sulfur fuel 
requirement. Full details of our cost and cost effectiveness analyses 
can be found in the RIA.

A. Cost for Diesel Vehicles to Meet Emissions Standards

1. Summary of New System and Operating Costs
    The technologies described in Section III represent significant 
technological advancements for controlling emissions, but also make 
clear that much effort remains to develop and optimize these new 
technologies for maximum emission-control effectiveness with minimum 
negative impacts on engine performance, durability, and fuel 
consumption. On the other hand, it has become clear that manufacturers 
have a great potential to advance beyond the current state of 
understanding by identifying aspects of the key technologies that 
contribute most to hardware or operational costs or other drawbacks and 
pursuing improvements, simplifications, or alternatives to limit those 
burdens. To reflect this investment in long-term cost savings 
potential, the cost analysis includes an estimated $385 million in R&D 
outlays for heavy-duty engine designs and $220 million in R&D for 
catalysts systems giving a total R&D outlay for improved emission 
control of more than $600 million. The cost and technical feasibility 
analyses accordingly reflect substantial improvements on the current 
state of technology due to these future developments.
    Estimated costs are broken into additional hardware costs and life-
cycle operating costs. The incremental hardware costs for new engines 
are comprised of variable costs (for hardware and assembly time) and 
fixed costs (for R&D, retooling, and certification). Total operating 
costs include the estimated incremental cost for low-sulfur diesel 
fuel, any expected increases in maintenance cost or fuel consumption 
costs along with any decreases in operating cost expected due to low-
sulfur fuel. Cost estimates based on these projected technology 
packages represent an expected incremental cost of engines in the 2007 
model year. Costs in subsequent years will be reduced by several 
factors, as described below. Separate projected costs were derived for 
engines used in three service classes of heavy-duty diesel engines. All 
costs are presented in 1999 dollars.
    The costs of these new technologies for meeting the 2007 model year 
standards are itemized in the RIA and summarized in Table V.A-1. For 
light heavy-duty vehicles, the cost of an engine is estimated to 
increase by $1,990 in the early years of the program reducing to $1,170 
in later years and operating costs over a full life-cycle to increase 
by approximately $500 in the near term. For medium heavy-duty vehicles 
the cost of a new engine is estimated to increase by $2,560 initially 
decreasing to $1,410 in later years with life-cycle operating costs 
increasing by approximately $900 in the near term. Similarly, for heavy 
heavy-duty engines, the vehicle cost in the first year is expected to 
increase by $3,230 decreasing to $1,870 in later years. Estimated 
additional life-cycle operating costs for heavy heavy-duty engines in 
the near term are approximately $3,800. The higher incremental increase 
in operating costs for the heavy heavy-duty vehicles is due to the 
larger number of miles driven over their lifetime (714,000 miles on 
average) and their correspondingly high lifetime fuel usage. Emission 
reductions are also proportional to VMT and so are significantly higher 
for heavy heavy-duty vehicles.
    We also believe there are factors that will cause cost impacts to 
decrease over time, making it appropriate to distinguish between near-
term and long term costs. Research in the costs of manufacturing has 
consistently shown that as manufacturers gain experience in production, 
they are able to apply innovations to simplify machining and

[[Page 5090]]

assembly operations, use lower cost materials, and reduce the number or 
complexity of component parts.184 Our analysis, as described 
in more detail in the RIA, incorporates the effects of this learning 
curve by projecting that the variable costs of producing the low-
emitting engines decreases by 20 percent starting with the third year 
of production (2009 model year) and by reducing variable costs again by 
20 percent starting with the fifth year of production. Additionally, 
since fixed costs are assumed to be recovered over a five-year period, 
these costs are not included in the analysis after the first five model 
years. Finally, manufacturers are expected to apply ongoing research to 
make emission controls more effective and to have lower operating cost 
over time. However, because of the uncertainty involved in forecasting 
the results of this research, we have conservatively not accounted for 
it in this analysis. Table V.A-1 lists the projected costs for each 
category of vehicle in the near-and long-term. For the purposes of this 
analysis, ``near-term'' costs are those calculated for the 2007 model 
year and ``long term'' costs are those calculated for 2012 and later 
model years.
---------------------------------------------------------------------------

    \184\ See Chapter V of the final Tier 2 Regulatory Impact 
Analysis, contained in Air Docket A-97-10.

  Table V.A-1.--Projected Incremental System Cost and Life Cycle Operating Cost for Heavy-Duty Diesel Vehicles
                             [net present values in the year of sale, 1999 dollars]
----------------------------------------------------------------------------------------------------------------
                                                                                                      Life-cycle
             Vehicle class                                Model year                      Hardware    operating
                                                                                            cost       cost a b
----------------------------------------------------------------------------------------------------------------
Light.................................                                      near term         1,990          509
Heavy-duty............................                                      long term         1,170          537
Medium................................                                      near term         2,560          943
Heavy-duty............................                                      long term         1,410          996
Heavy.................................                                      near term         3,230        3,785
Heavy-duty............................                                      long term         1,870       3,979
----------------------------------------------------------------------------------------------------------------
a Incremental life-cycle operating costs include the incremental costs to refine and distribute low sulfur
  diesel fuel, the service cost of closed crankcase filtration systems, the maintenance cost for PM filters and
  the lower maintenance costs realized through the use of low sulfur diesel fuel (see discussion in Section
  V.C).
b These costs are for new vehicles only and do not reflect any costs or savings for the existing fleet.

2. New System Costs for NOX and PM Emission Control
    Several new technologies are projected for complying with the 2007 
model year emission standards. We are projecting that NOX 
adsorbers and catalyzed diesel particulate filters will be the most 
likely technologies applied by the industry in order to meet the 
emissions standards. The fact that manufacturers will have several 
years before implementation of the new standards ensures that the 
technologies used to comply with the standards will develop 
significantly before reaching production. This ongoing development 
could lead to reduced costs in three ways. First, we expect research 
will lead to enhanced effectiveness for individual technologies, 
allowing manufacturers to use simpler packages of emission control 
technologies than we would predict given the current state of 
development. Similarly, we anticipate that the continuing effort to 
improve the emission control technologies will include innovations that 
allow lower-cost production. Finally, we believe that manufacturers 
will focus research efforts on any drawbacks, such as fuel economy 
impacts or maintenance costs, in an effort to minimize or overcome any 
potential negative effects.
    We anticipate that in order to meet the standards, industry will 
introduce a combination of primary technology upgrades for the 2007 
model year. Achieving very low NOX emissions will require 
continued development of NOX emission control technologies 
and improvements in engine management to take advantage of the exhaust 
emission control system capabilities. The manufacturers are expected to 
take a systems approach to the problem of optimizing the engine and 
exhaust emission control system to realize the best overall performance 
possible. Since most research to date with exhaust emission control 
technologies has focused on retrofit programs, there remains room for 
significant improvements by taking such a systems approach. The 
NOX adsorber technology in particular is expected to benefit 
from re-optimization of the engine management system to better match 
the NOX adsorbers performance characteristics. The majority 
of the $600 million dollars we have estimated for research is expected 
to be spent on developing this synergy between the engine and 
NOX exhaust emission control systems. PM control 
technologies are expected to be less sensitive to engine operating 
conditions as they have already shown good robustness in retrofit 
applications with low-sulfur diesel fuel.
    The NOX adsorber system that we are anticipating will be 
applied in 2007 consists of a catalyst which combines traditional 
gasoline three-way conversion technology with a newly developed 
NOX storage function, a reductant metering system and a 
means to control exhaust air fuel (A/F) ratio. The NOX 
adsorber catalyst itself is a relatively new device, but is benefitting 
in its development from over 20 years of gasoline three-way catalyst 
development. In order for it to function properly, a systems approach 
that includes a reductant metering system and control of exhaust A/F 
ratio is also necessary. Many of the new air handling and electronic 
system technologies developed in order to meet the 2004 heavy-duty 
engine standards can be applied to accomplish the NOX 
adsorber control functions as well. Some additional hardware for 
exhaust NOX or O2 sensing, for exhaust 
partitioning and for fuel metering will likely be required. The RIA 
also calculates an increase in warranty costs for this additional 
hardware. In total the new NOX control technologies required 
in order to meet the 2007 emission standards are estimated to increase 
light heavy-duty engine costs by $1,000, medium heavy-duty engine costs 
by $1,310 and heavy heavy-duty engine costs by $1,650 in the year 2007. 
In the year 2012 and

[[Page 5091]]

beyond the incremental costs are expected to decrease to $590 for a 
light heavy-duty engine, $690 for a medium heavy-duty engine and to 
$930 for a heavy heavy-duty engine.
    Catalyzed diesel particulate filters are experiencing widespread 
retrofit use in much of Europe as low-sulfur diesel fuel becomes 
readily available. These technologies are proving to be robust in their 
non-optimized retrofit applications requiring no modification to engine 
or vehicle control functions. We therefore anticipate that catalyzed 
diesel particulate filters can be integrated with new diesel engines 
with only a minimal amount of engine development. We do not anticipate 
that additional hardware beyond the diesel particulate filter itself 
and an exhaust pressure sensor for OBD will be required in order to 
meet the PM standard. However, in order to ensure trap durability under 
all possible operating conditions, some engine manufacturers may choose 
to provide backup regeneration technologies for their PM filter based 
systems. As detailed further in the RIA and the RTC documents, we do 
not anticipate that these redundant systems will add to variable costs. 
We estimate in 2007 that diesel particulate filter systems will add 
$730 to the cost of a light heavy-duty vehicle, $950 to the cost of a 
medium heavy-duty vehicle and $1,190 to the cost of a heavy heavy-duty 
vehicle. By 2012 these costs are expected to decrease to $425, $530, 
and $690 respectively. These cost estimates are comparable to estimates 
made by the Manufacturers of Emission Controls Association for these 
technologies.185
---------------------------------------------------------------------------

    \185\ Letter from Bruce Bertelsen, Manufacturers of Emission 
Controls Association (MECA) to William Charmley, US EPA, December 
17, 1998. The letter documents a MECA member survey of expected 
diesel particulate filter costs. Air Docket A-98-32 Item II-D-09.
---------------------------------------------------------------------------

    The hydrocarbon (HC) exhaust standards set in this rulemaking will 
be challenging for both diesel and gasoline engine technologies. For 
diesel engines utilizing the NOX adsorber based technology 
solution to control NOX emissions, HC control due to 
imprecise NOX regeneration control may be difficult. One way 
to ensure HC compliance will be to apply a separate diesel oxidation 
catalyst which can control HC emissions to the limits set here. These 
diesel oxidation catalysts are expected to add an additional cost to 
the system of $206 for light heavy-duty vehicles, $261 for medium 
heavy-duty vehicles, and $338 for heavy heavy-duty vehicles.
    We have eliminated the exemption that allowed turbo-charged heavy-
duty diesel engines to vent crankcase gases directly to the 
environment, so called open crankcase systems, and have projected that 
manufacturers will rely on engineered closed crankcase ventilation 
systems which filter oil from the blow-by gases. We estimate that the 
initial cost of these systems in 2007 will be $37, $42, and $49 for 
light, medium and heavy heavy-duty diesel engines respectively. 
Additionally we expect a portion of the oil filtration system to be a 
service replacement oil filter which will be replaced on a 30,000 mile 
service interval with a service cost of $10, $12, and $15 for light, 
medium, and heavy heavy-duty diesel engines respectively. These cost 
are summarized with the other cost for emission controls in Table V.A-1 
and are included in the aggregate cost reported in Section V.D.
3. Operating Costs Associated With NOX and PM Control
    The RIA assumes that a variety of new technologies will be 
introduced to enable heavy-duty vehicles to meet the new emissions 
standards. Primary among these are advanced emission control 
technologies and low-sulfur diesel fuel. The many benefits of low-
sulfur diesel fuel are described in Section III, and the incremental 
cost for low-sulfur fuel is described in Section V.C. The new emission 
control technologies are themselves not expected to introduce 
additional operating costs in the form of increased fuel consumption. 
Operating costs are estimated in the RIA over the life of the vehicle 
and are expressed as a net present value (NPV) in 1999 dollars for 
comparison purposes.
    Total operating cost estimates include both the expected increases 
in maintenance and fuel costs (both the incremental cost for low-sulfur 
fuel and any fuel consumption penalty) due to the emission control 
systems application and the predicted decreases in maintenance cost due 
to the use of low-sulfur fuel. Our analysis projects some increase in 
operating costs due to the incremental cost of low-sulfur diesel fuel 
but no net increase in fuel consumption with the application of the new 
emission control technologies (see discussion in Section III.G). The 
net increase in operating costs are summarized in Table V.A-1. While we 
are using these incremental operating cost estimates for our cost 
effectiveness calculations, it is almost certain that the manufacturers 
will improve existing technologies or introduce new technologies in 
order to offset at least some of the increased operating costs.
    We estimate that the low-sulfur diesel fuel required in order to 
enable these technologies will have an incremental cost of 
approximately $0.045/gallon in the near term increasing to $0.050/
gallon in the long term as discussed in Section V.C. The low-sulfur 
diesel fuel may also provide additional benefits by reducing the engine 
maintenance costs associated with corrosion due to sulfur in the 
current diesel fuel. These benefits, which are discussed further in 
Section V.C.5 and in the RIA, include extended oil change intervals due 
to the slower acidification rate of the engine oil with low-sulfur 
diesel fuel. Service intervals for the EGR system are also expected to 
increase due to lower-sulfur induced corrosion than will occur with 
today's higher-sulfur fuel. This lengthening of service intervals 
provides a significant savings to the end user. As described in more 
detail in the RIA we anticipate that low-sulfur diesel fuel will 
provide additional cost savings to the consumer of $153 for light 
heavy-duty vehicles, $249 for medium heavy-duty vehicles and $610 
dollars for heavy heavy-duty vehicles.
    The operating costs for replacement filters in the closed crankcase 
filtration systems expressed as a net present value in the year of sale 
are estimated to be $31 for light heavy-duty vehicles, $59 for medium 
heavy-duty vehicles and $218 for heavy heavy-duty vehicles for vehicles 
sold in 2007.
    PM filter based technologies capture all forms of particulate in 
the exhaust including inorganic solid particles which can come from the 
engine oil or wear products of the engine. These inorganic particles 
(often call ash) must be periodically cleaned from the particulate 
filter. We have estimated the additional maintenance cost to clean the 
PM filter expressed as a net present value in the year of sale of $55 
for light heavy-duty vehicles, $56 for medium heavy-duty vehicles and 
$208 dollars for heavy heavy-duty vehicles, as detailed in the RIA.
    Factoring the cost savings due to low sulfur diesel fuel into the 
additional cost for low-sulfur diesel fuel and the service cost of the 
closed crankcase ventilation system and the PM filter system yields an 
increase in vehicle operating costs expressed as a net present value in 
the year of sale of $509 for a light heavy-duty vehicle, $943 for a 
medium heavy-duty vehicle and $3,785 for a heavy heavy-duty vehicle. 
These life cycle operating costs are also summarized in Table V.A-1. 
The net increase in operating cost can also be expressed as an average 
annual operating cost for each class of heavy-duty vehicle by dividing 
the total undiscounted operating costs by the average vehicle life 
assumed to be 9 years for light heavy-duty vehicles, and

[[Page 5092]]

11 years for medium and heavy heavy-duty engines. Expressed as an 
approximate annual per vehicle cost, the additional operating cost is 
estimated as $80 for a light heavy-duty vehicle, $130 for a medium 
heavy-duty vehicle, and $510 for a heavy heavy-duty vehicle.

B. Cost for Gasoline Vehicles to Meet the New Emissions Standards

1. Summary of New System Costs
    To perform a cost analysis for the final gasoline standards, we 
first determined a package of likely technologies that manufacturers 
could use to meet the standards and then determined the costs of those 
technologies. In making our estimates, we have relied on our own 
technology assessment which included publicly available information 
such as that developed by California, confidential information supplied 
by individual manufacturers, and the results of our own in-house 
testing.
    In general, we expect that heavy-duty gasoline vehicles would (like 
Tier 2 light duty vehicles) be able to meet these standards through 
refinements of current emissions control components and systems rather 
than through the widespread use of new technology. More specifically, 
we anticipate a combination of technology upgrades such as the 
following:
     Improvements to the catalyst system design, structure, and 
formulation, plus an increase in average catalyst size and loading.
     Air and fuel system modifications including changes such 
as improved oxygen sensors, and calibration changes including improved 
precision fuel control and individual cylinder fuel control.
     Exhaust system modifications, possibly including air 
gapped components, insulation, leak free exhaust systems, and thin wall 
exhaust pipes.
     Increased use of fully electronic exhaust gas 
recirculation (EGR).
     Increased use of secondary air injection.
     Use of ignition spark retard on engine start-up to improve 
upon cold start emission control.
     Use of low permeability materials and minor improvements 
to designs, such as the use of low-loss connectors, in evaporative 
emission control systems.
    We expect that the technologies needed to meet the heavy-duty 
gasoline standards will be very similar to those required to meet the 
Tier 2 standards for vehicles over 8,500 pounds GVWR. Few heavy-duty 
gasoline vehicles currently rely on technologies such as close coupled 
catalysts and secondary air injection, but we expect they would to meet 
the new standards.
    For each group we developed estimates of both variable costs (for 
hardware and assembly time) and fixed costs (for R&D, retooling, and 
certification). Cost estimates based on the current projected costs for 
our estimated technology packages represent an expected incremental 
cost of vehicles in the near-term. For the longer term, we have 
identified factors that would cause cost impacts to decrease over time. 
First, since fixed costs are assumed to be recovered over a five-year 
period, these costs disappear from the analysis after the fifth model 
year of production. Second, the analysis incorporates the expectation 
that manufacturers and suppliers would apply ongoing research and 
manufacturing innovation to making emission controls more effective and 
less costly over time. Research in the costs of manufacturing has 
consistently shown that as manufacturers gain experience in production 
and use, they are able to apply innovations to simplify machining and 
assembly operations, use lower cost materials, and reduce the number or 
complexity of component parts.186 These reductions in 
production costs are typically associated with every doubling of 
production volume. Our analysis incorporates the effects of this 
``learning curve'' by projecting that a portion of the variable costs 
of producing the new vehicles decreases by 20 percent starting with the 
third year of production. We applied the learning curve reduction only 
once since, with existing technologies, there would be less opportunity 
for lowering production costs than would be the case with the adoption 
of new technology. We did not apply the learning curve reduction to 
precious metal costs, nor did we apply it for the evaporative 
standards.
---------------------------------------------------------------------------

    \186\ See Chapter V of the final Tier 2 Regulatory Impact 
Analysis, contained in Air Docket A-97-10.
---------------------------------------------------------------------------

    We have prepared our cost estimates for meeting the new heavy-duty 
gasoline standards using a baseline of current technologies for heavy-
duty gasoline vehicles and engines. Finally, we have incorporated what 
we believe to be a conservatively high level of R&D spending at 
$2,500,000 per engine family where no California counterpart exists. We 
have included this large R&D effort because calibration and system 
optimization is likely to be a critical part of the effort to meet the 
standards. However, we believe that the R&D costs may be generous 
because the projection probably underestimates the carryover of 
knowledge from the development required to meet the light-duty Tier 2 
and CARB LEV-II standards.
    Table V.B-1 provides our estimates of the per vehicle cost for 
heavy-duty gasoline vehicles and engines. The near-term cost estimates 
in Table V.B-1 are for the first years that vehicles meeting the 
standards are sold, prior to cost reductions due to lower productions 
costs and the retirement of fixed costs. The long-term projections take 
these cost reductions into account.

Table V.B-1.--Projected Incremental System Cost and Life Cycle Operating
                  Cost for Heavy-Duty Gasoline Vehicles
         [Net Present Values in the year of sale, 1999 dollars]
------------------------------------------------------------------------
                                                              Life-cycle
        Vehicle class             Model year    Incremental   operating
                                                system cost      cost
------------------------------------------------------------------------
Heavy-Duty...................  near term......         $198           $0
Gasoline.....................  long term......          167            0
------------------------------------------------------------------------


[[Page 5093]]

2. Operating Costs Associated With Meeting the Heavy-Duty Gasoline 
Standard
    Low sulfur gasoline is a fundamental enabling technology which will 
allow heavy-duty gasoline vehicles to meet the very low emission 
standards being finalized today. The low sulfur gasoline required under 
the Tier 2 proposal will enable advanced exhaust emission control for 
heavy-duty vehicles as well. Today's final rule puts no additional 
requirements on gasoline sulfur levels and as such should not increase 
gasoline fuel costs. Additionally, the new technologies being employed 
in order to meet the new standards are not expected to increase fuel 
consumption for heavy-duty gasoline vehicles. In fact, there may be 
some small improvement in fuel economy from the application of improved 
fuel and air control systems on these engines. Therefore, in the 
absence of changes to gasoline specifications and with no decrease in 
fuel economy, we do not expect any increase in vehicle operating costs.

C. Cost of Fuel Change

    We estimate that the overall net cost associated with producing and 
distributing 15 ppm diesel fuel, when those costs are allocated to all 
gallons of highway diesel fuel, will be approximately 5.0 cents per 
gallon in the long term, or an annual cost of roughly $2.2 billion per 
year once the program is fully effective starting June 1, 2010. During 
the initial years under temporary compliance option, the overall net 
cost is projected to be 4.5 cents per gallon, or an annual cost of 
roughly $1.7 billion per year.
    This cost consists of a number of components associated with 
refining and distributing the new fuel. The majority of the cost is 
related to refining. From 2006-2010, refining costs are estimated to be 
approximately 3.3 cents per gallon of highway diesel fuel (4.1 cents 
per gallon for that portion produced to the 15 ppm standard), 
increasing to 4.3 cents per gallon once the program is fully in place. 
In annual terms, the 2006-2010 refining costs are expected to be about 
$1.4 billion per year, increasing to about $1.8 billion in 2011. These 
figures include the cost of producing slightly more volume of diesel 
fuel because: (1) Desulfurization decreases the energy density of the 
fuel and (2) slightly more highway diesel fuel is expected to be 
downgraded to nonroad diesel fuel in the distribution system.
    A small cost of 0.2 cents per gallon is associated with an 
anticipated increase in the use of additives to maintain fuel 
lubricity. Also, distribution costs are projected to increase by 1.0 
cents per gallon during the initial years under the temporary 
compliance option, including the cost of distributing slightly greater 
volumes of fuel. Together, these two cost components only amount to 
about $0.5 billion per year beginning in 2006. These costs drop to only 
about $0.3 billion in 2011.
    As discussed in Sections V.A. and V.C.5, operation with 15 ppm 
sulfur diesel fuel is expected to reduce average vehicle maintenance 
costs by approximately 1 cent on a per gallon basis. Beginning in 2011, 
this reduction in maintenance costs will total roughly $400 million per 
year. All of these cost estimates are discussed in more detail below 
and in the RIA.
 1. Refinery Costs
    As explained in Section IV, EPA believes that refiners will meet 
the 15 ppm sulfur standard through an extension of the same 
hydrotreating technology which is used today to meet the current 500 
ppm sulfur standard. Meeting the new standard will generally require 
refiners to install additional hydrotreating equipment. Most refiners 
are expected to add another hydrotreating reactor and other related 
equipment to their existing desulfurization unit. However, we project 
that some refiners, roughly 20 percent, will conclude that it is not 
economical to add onto their existing unit and will instead build an 
entirely new hydrotreater.
    Consistent with our analysis for the NPRM, we estimate that a 
refinery's diesel fuel will have to average 7 ppm in order to 
consistently meet the 15 ppm standard. For the NPRM, we estimated the 
cost of producing highway diesel fuel with a 7 ppm average sulfur level 
for the average U.S. refinery. We received a number of comments on the 
NPRM which indicated that the cost for various refiners would differ 
dramatically, as would the cost of treating the various blendstocks 
which comprise highway diesel fuel. In response, we extended our 
refining cost model to be specific to each refinery in the U.S., based 
on a refinery's production volume and estimated composition of its 
highway diesel fuel. Using this model, we estimated each refinery's 
cost of producing 7 ppm sulfur highway diesel fuel and then aggregated 
these results to estimate a national average cost.
    This analysis considers the fact that some diesel fuel blendstocks 
are more difficult to desulfurize than others. As indicated in some 
comments on the NPRM, this could lead refiners to shift their 
blendstocks between highway diesel fuel and other distillate products 
in order to minimize costs. For example, our analysis found that the 
incremental cost of desulfurizing current highway diesel fuel can be 
more expensive for some refiners than the cost to other refiners of 
desulfurizing nonroad diesel fuel to meet the 15 ppm standard, despite 
the fact that the current sulfur level of nonroad diesel fuel is 
roughly 2500-3000 ppm.
    We evaluated costs under two scenarios: (1) all current producers 
of highway diesel fuel continued to do so, and (2) some refiners 
increase production of highway diesel fuel and some refiners facing 
higher desulfurization costs leave the highway diesel fuel market. Our 
cost projections presented below are based on the first scenario. This 
is conservative, because in this scenario, some refineries currently 
produce relatively low volumes of highway diesel fuel and would face 
relatively high costs per gallon to desulfurize this same volume of 
fuel.
    We project that the average refining cost to meet the 15 ppm cap 
standard will be 4.3 cents per gallon, including capital costs 
amortized at 7 percent per year before taxes, once the standard is 
fully in place in June, 2010. Refining costs will be lower, 4.1 cents 
per gallon of 15 ppm fuel (or 3.3 cents per gallon of all highway 
diesel fuel), during optional compliance provisions (2006-2010), 
because we expect that those refiners facing the lowest cost of meeting 
the standard in each PADD will invest to produce the new fuel. We 
project that refiners will invest $3.8 billion in new equipment in 
order for about 80 percent of highway diesel fuel to meet the 15 ppm 
standard in 2006. An additional $1.4 billion will be invested for the 
rest of the highway diesel fuel market to meet the new standard in 
2010, for a total capital cost of $5.2 billion. The average refinery is 
projected to spend about $43 million in capital costs, and $7 million 
per year in operating costs.
    Table V.C-1 shows the range of average costs per refinery by PADD. 
Despite the varying size of refineries and differences in their 
available distillate blendstocks, the variations in the average cost 
between PADDs in either 2006 or 2010 are small, with the exception of 
PADD 4. PADD 4 average costs are 30-40 percent higher than the costs in 
the other PADDs.

[[Page 5094]]



Table V.C-1.--Average Refining Costs by PADD (cents per gallon of 15 ppm
                                  fuel)
------------------------------------------------------------------------
                                                    2006         2010
------------------------------------------------------------------------
PADD 1........................................          4.4          4.7
PADD 2........................................          4.3          4.5
PADD 3........................................          3.8          3.9
PADD 4........................................          5.1          5.3
PADD 5........................................          4.2          4.5
U.S. Average..................................          4.1          4.3
------------------------------------------------------------------------

    A number of other estimates of the cost of the 15 ppm sulfur 
standard were submitted as part of the comments. Mathpro used a 
notional refinery model to estimate the national average costs of the 
proposed standard for EMA. Charles River Associates (CRA), along with 
Baker and O'Brien, used the Prism refinery model to estimate the cost 
for each refinery in the U.S. for API. Finally, EnSys used the Oak 
Ridge National Laboratory PADD 3 refinery model to estimate costs for 
DOE. Table V.C-2 summarizes these estimates after adjusting the 
projected costs to represent a 7 percent rate of return on investment 
before taxes (except for the CRA cost, which could not be adjusted).

  Table V.C-2.--Comparison of National Average Refining Cost Estimates
          [7 percent rate of return on investment before taxes]
------------------------------------------------------------------------
                                           Average cost
                                            (cents per     Capital cost
                                           gallon of 15     ($ billion)
                                             ppm fuel)
------------------------------------------------------------------------
EPA (Full program)......................             4.4             5.3
Methpro for EMA*........................         4.2-6.1         3.4-6.1
CRA for API (10% after tax rate of                   6.2              --
 return)................................
EnSys for DOE (conservative technology)*         5.1-6.0         3.9-6.5
 ...............................
EnSys for DOE (optimistic technology)*           4.2-4.4        2.7-4.5
 ...............................
------------------------------------------------------------------------
* Lower end of range assumes 100 percent revamped equipment; upper end
  assumes all new equipment.
 Costs are only for the Gulf Coast refining region, which have
  slightly lower per-gallon costs than the entire U.S., and about half
  the capital costs.

    The costs estimated by Mathpro are the most similar to those 
estimated by EPA. This is primarily because the desulfurization 
technology projected to be used were similar in the two studies.
    CRA projected the use of similar technology, but estimated that 40 
percent of refiners would build new desulfurization units, versus our 
estimate of 20 percent. CRA also assumed that technology vendors are 
inherently optimistic in their projections and increased their 
projected costs by roughly 20 percent. CRA also projected that nonroad 
diesel fuel sulfur levels would be capped at 500 ppm. How this affected 
the projected cost of producing 15 ppm fuel is not clear. CRA assumed 
that this 500 ppm fuel would be produced by blending 8 ppm sulfur 
highway diesel fuel and 3000 ppm heating oil. Much of this production 
was assumed to occur due to mixing in the distribution system. An 
unknown amount of 500 ppm fuel was produced at refineries. 
Desulfurization costs are not linear, as shown by CRA's own study. 
Thus, any blending of 15 ppm sulfur highway diesel fuel with non-
desulfurized heating oil at refineries was much more costly than simply 
hydrotreating nonroad diesel fuel to 500 ppm. It also required refiners 
to hydrotreat the most difficult blendstocks at a much higher cost. 
Because of these significant differences in both methodology and 
assumptions, it is not surprising that CRA's costs would be higher than 
those estimated by Mathpro or ourselves.
    EnSys's cost estimates require some explanation due to the number 
of scenarios they analyzed. EnSys did not estimate how many refiners 
would build new desulfurization units and how many would modify their 
current hydrotreaters, but simply presented costs if refiners took one 
approach or the other. Thus, the lower limits of the ranges shown in 
Table V.C-2 assume refiners modify their current hydrotreaters, while 
the upper limits assume that refiners would build new units. EnSys also 
projected costs for two separate sets of technologies. One set was 
considered conservative and relied on technologies that are already in 
commercial use. The other was considered to be optimistic and was 
similar to that projected to be used by EPA, Mathpro and CRA. EnSys' 
costs using the conservative technology are higher than our estimates. 
This is due to the fact that this technology involves greater capital 
investment and greater consumption of hydrogen. These greater costs are 
due to the fact that this technology is not just designed to reduce 
sulfur, but to reduce aromatic content, increase cetane levels and 
perform some cracking. EnSys' costs using the optimistic technology are 
much more similar to those of EPA and Mathpro, considering that EnSys' 
range of costs reflects both revamped and new desulfurization units and 
that EPA's costs are dominated (80 percent) by revamped units.
    Some of the variation in the costs projected by the various studies 
involves uncertainty in exactly what degree of hydrotreating will be 
necessary to meet the 15 ppm sulfur standard day in and day out with a 
variety of distillate feedstocks. As discussed in Section IV above, 
there is currently no commercial experience in the U.S. and only a 
limited amount of information in the public literature on the costs 
associated with reducing the sulfur level in diesel fuel to very low 
levels on an ongoing operational basis. Thus, any cost projections 
involve a significant amount of uncertainty.
2. Highway Diesel Fuel Supply
    While API and many refiners did not question the feasibility of the 
15 ppm standard, they did indicate that the cost would be higher than 
that projected by EPA. API believes that those refiners facing higher 
than average costs may decide to leave the highway diesel fuel market. 
They argue this is especially a possibility if they are faced with a 
sulfur standard below a 30 ppm average (or 50 ppm cap), which they 
believe will require very large investments for high pressure 
hydrotreating to maintain current highway diesel production volumes. 
API also believes that many refiners may reduce their production of 
highway diesel fuel, by switching the feedstocks (i.e., LCO) which are 
most difficult to desulfurize to other markets,

[[Page 5095]]

thus avoiding the higher investments associated with high pressure 
hydrotreating. If some refiners reduce highway diesel fuel production, 
that could present an opportunity for other refiners, who choose to 
make the investment, of higher prices for the new 15 ppm sulfur 
product.
    This view is embodied by a study by Charles River Associates (CRA) 
and Baker and O'Brien which was commissioned by API. CRA polled 
refiners concerning their plans under a 15 ppm sulfur cap. Using the 
results of this survey, as well as other information, CRA projected 
refiners' costs of meeting the 15 ppm standard, as well as their likely 
production volumes. CRA concluded that U.S. refiners would likely 
reduce their highway diesel fuel production by an average of 12 
percent, creating significant shortages and price spikes.
    CRA's conclusions appear to have been strongly affected by their 
assumptions, as well as the refiner survey they conducted. For example, 
CRA assumed that the new sulfur standard would cause 10 percent more 
highway diesel fuel to be ``lost'' in the distribution system compared 
to today (i.e., downgraded to off-highway diesel fuel). We believe 
based on the analysis outlined in the RIA that 2.2 percent is a more 
accurate estimate, resulting in 9 percent more 15 ppm fuel being 
available than CRA estimated. This difference alone accounts for 75 
percent of the potential national supply shortfall projected by CRA.
    CRA also concluded, with little explanation, that 20 refineries 
producing highway diesel fuel today would not produce highway diesel 
fuel under the 15 ppm standard and that many more would reduce 
production. Given the lack of information provided in the study, it was 
not possible to evaluate CRA's criteria in selecting these 20 
refineries, nor was it possible to determine how much of the shortfall 
was attributable to this conclusion. While CRA evaluated whether 
refiners currently producing highway diesel fuel would be likely to 
leave the market, they did not assess whether any refineries currently 
not producing highway diesel fuel might enter the market. EPA did 
conduct such an assessment. We found 2 refineries that produce 
essentially no highway diesel fuel today which could meet the new 
standard for less than 5 cents per gallon. Production from these 
refineries would increase highway diesel fuel production by 9 percent. 
We also found based on our assessment that 4 other refineries could 
produce highway diesel fuel from their off-highway diesel fuel 
blendstocks for less than 5 cents per gallon. Production from these 6 
refineries would increase highway diesel fuel production by 7 percent. 
Together with a more reasonable estimate of downgrades in the 
distribution system, this would more than compensate for any potential 
lost production, even as estimated by CRA.
    CRA also implicitly assumed that the material it projected could be 
removed from the highway diesel market could be sold at a reasonable 
price. However, CRA did not analyze the impact of this additional 
supply on the prices which could be obtained in these markets, or even 
if these alternative markets could physically absorb all of this 
material. Much of this material is not diesel fuel, but poor quality 
blendstock. It is not clear that such material could be blended into 
non-highway diesel fuel and CRA did not analyze this likely problem. 
Our analyses, supported by a study by Muse, Stancil and Co., indicate 
that any substantial quantities of highway diesel fuel diverted to 
other markets will depress prices in those markets 
substantially.187 Hydrotreating diesel fuel to meet the 15 
ppm standard avoids these depressed prices, reducing the net cost of 
meeting the new standard. Since CRA only considered the cost to 
desulfurize highway diesel fuel, and ignored the added cost of dumping 
this fuel into markets with depressed prices, CRA's conclusions must be 
considered to be seriously flawed in this regard.
---------------------------------------------------------------------------

    \187\ ``Alternate Markets for Highway Diesel Fuel Components,'' 
Muse, Stancil & Co., for Southwest Research Institute, for U.S. EPA, 
September, 2000.
---------------------------------------------------------------------------

    Furthermore, CRA ignored the fact that roughly 15 percent of 
today's highway diesel fuel is consumed in engines and furnaces not 
requiring this fuel. Any shortage of highway diesel fuel would lead 
many of these non-essential users to switch to nonroad diesel fuel or 
heating oil. Only limitations in the fuel distribution system would 
cause these users to continue to burn highway diesel fuel.
    These problems with CRA's analysis, plus the lack of detail 
available concerning the specifics of the study, lead us to reject the 
study's conclusions that there will be significant supply shortfalls 
under a 15 ppm sulfur standard.
    Finally, if any potential for highway diesel fuel shortfalls exists 
by requiring all fuel to meet 15 ppm sulfur in 2006, as CRA's analysis 
suggests, we believe that allowing some continued supply of 500 ppm, as 
we are doing under the temporary compliance option and hardship 
provisions contained in today's action, addresses this concern. Since 
the final rule allows some transition period before the entire highway 
diesel pool is required to meet the 15 ppm sulfur standard, some 
refiners will not need to change their current operations and will be 
able to continue producing 500 ppm fuel during these years. Those 
refiners that delay production of low sulfur diesel fuel until the 
later years of the program will tend to be the refiners with the 
highest cost to comply and, thus, refiners that would otherwise have 
the greatest tendency not to invest and thereby impact supply. Refiners 
that begin producing low sulfur diesel fuel in the later years of the 
program will also be able to take advantage of ongoing improvements in 
desulfurization technology. Together, these factors will help avoid or 
reduce any potential losses in highway diesel fuel production when the 
program requires full compliance with low sulfur diesel fuel.
    As mentioned above, EPA agrees that some refiners will face higher 
desulfurization costs than others. This is generally the case with any 
fuel quality regulation, since the crude oils processed by, as well as 
the configurations and product slates of individual refineries vary 
dramatically. As mentioned above and summarized in the RIA, we used our 
refining cost model to assess the likelihood that refiners would leave 
the highway diesel fuel market or reduce their production of highway 
diesel fuel. We also assessed the likelihood of other refiners entering 
this market. We found that a number of refiners appear to be in a 
position to expand their highway diesel fuel production capacity very 
economically relative to other refiners facing higher desulfurization 
costs. We also found that up to 2 refineries not now producing highway 
diesel fuel could easily enter the highway diesel fuel market at very 
competitive costs.
    Some refiners may have an alternative market for their diesel fuel. 
In the extreme, a refiner would likely prefer to only shift his light 
cycle oil to other distillate products, like nonroad diesel fuel and 
No. 2 heating oil, retaining his other blendstocks in the higher value 
highway diesel fuel market. However, in many cases, a refiner cannot 
shift light cycle oil directly to a distillate product, because the 
resulting non-highway fuel would no longer meet applicable 
specifications, such as sulfur or cetane. In most cases, we expect that 
the refiner must shift highway diesel fuel to alternative markets in 
order to be able to obtain a reasonable price.
    As mentioned above, Muse, Stancil, & Co. analyzed the ability of 
refiners to

[[Page 5096]]

divert highway diesel fuel or its blendstocks to other distillate 
markets. Muse, Stancil found that this ability varied significantly by 
PADD. In PADDs II and IV, it would be difficult for refiners to move 
any appreciable quantity of highway diesel fuel to other markets. For 
example, compared to the value of highway diesel fuel today, the 
achievable value for the diverted material would decrease by 14 to 20 
cents per gallon if refiners tried to move more than 5 percent of their 
highway diesel fuel to other markets. The loss in value was highest in 
these two PADDs, because growth in nonroad diesel fuel consumption is 
small or negative, the ability to reduce the consumption of highway 
diesel fuel by users other than highway vehicles was limited, and 
exports are only available through the Gulf or West Coasts with a large 
transportation cost of getting the material there.
    In PADDs III and V, the loss of value was lower, at 4.5-5 cents per 
gallon and was the lowest in PADD I, 2 cents per gallon. This was 
primarily because of the ability to export high sulfur diesel fuel 
overseas. Generally, these losses in value apply if diesel fuel was 
being diverted to other distillate markets. If light cycle oil was 
being diverted, the value would drop an additional 3-3.5 cents per 
gallon.
    At lower levels of diversion (e.g., 5 percent or less), the loss in 
value was much less, ranging from 1.6-5 cents per gallon across the 
five PADDs. However, the primary reason for this was the reduced use of 
highway diesel fuel by users other than highway vehicles, who do not 
require this fuel. Muse believed that such conversions were limited, 
but real and could represent roughly a third of the current use of 
highway diesel fuel in other than highway vehicles. If this occurs, 
then demand for highway diesel fuel drops at the same time. Thus, in 
this case, the total refining costs associated with the new sulfur 
standard will decline because the total amount of fuel; needing to be 
desulfurized will decrease.
    The only area where refiners could easily divert substantial 
amounts of highway diesel fuel is PADD I. PADD I refiners currently 
produce a relatively low amount of highway diesel fuel and substantial 
amounts of high sulfur diesel fuel/heating oil are imported. Thus, 
refiners in PADD I facing relatively high costs of meeting the 15 ppm 
standard could shift some or all of their highway diesel fuel to other 
markets, reducing imports and not substantially affecting prices in 
this market.
    In the end, refiners will make their decisions regarding investment 
based on their projections of demand of 15 and 500 ppm diesel fuel, the 
prices of these fuels and the prices available in alternative markets. 
At this time, we do not project that the specifics involved in this 
case (technology, cost, alternative markets) are significantly 
different from those which have existed in the past. The last time EPA 
regulated diesel fuel, the refining industry actually overbuilt 
desulfurization capacity for the current 500 ppm standard, as evidenced 
by the significant use in the nonroad market of diesel fuel produced to 
the current highway diesel sulfur standard of 500 ppm and the 
relatively low price of highway diesel fuel relative to nonroad diesel 
fuel. Some of this overproduction may have been due to limitations in 
the distribution system to distribute both highway and nonroad grades 
of diesel fuel. However, the refinery system as a whole was able to 
supply both highway diesel vehicles, plus the use of highway diesel 
fuel by other users. This was accomplished despite the fact that a 
number of small refiners did decide to switch from the highway diesel 
fuel market to the nonroad diesel fuel market, presumably for economic 
reasons.
3. Cost of Lubricity Additives
    As discussed in Section IV, the refinery processes needed to 
achieve the sulfur standard have some potential to degrade the natural 
lubricity characteristics of the fuel. Consequently, an increase in the 
use of lubricity additives for diesel fuel may be anticipated over the 
amounts used today. As described in more detail in the Regulatory 
Impact Analysis in the Public Docket, we include in our fuel cost 
estimate an average cost of 0.2 cents per gallon for lubricity 
additives over the entire pool of low sulfur highway diesel fuel (the 
same cost estimate as used in the proposal). This estimate is 
comparable to an estimate made by Mathpro in a study sponsored by the 
Engine Manufacturers Association, and is consistent with the cost 
estimate submitted by Cummins in its comments.
    Prior to the proposal, we contacted various producers of lubricity 
additives to get their estimates of what costs might be incurred for 
this increase in the use of lubricity additives. The cost estimates 
varied from 0.1 to 0.5 cents per gallon. The cost is likely to be a 
strong function of not only the additive type, but also the assumed 
treatment rate and the volume of fuel that needs to be treated, both of 
which will be, to some extent, a function of the sulfur cap. We 
requested comment on our cost estimate, including whether there may be 
unique costs for the military to maintain the lubricity of their 
distillate fuels. We requested that comments addressing this issue 
include a detailed discussion of the volumes of fuel affected, current 
lubricity additive use, and the additional measures that might be 
needed (and associated costs) to maintain the appropriate level of fuel 
lubricity. In response to the proposal, we received few comments on the 
cost of lubricity additives, and none on the volumes of fuel affected, 
current lubricity additive use, or additional measures that might be 
needed to maintain the appropriate level of lubricity. In considering 
the comments, we have found no basis in today's action to use a 
different average cost estimate to treat low sulfur diesel for 
lubricity than that which was used in the proposal (0.2 cents per 
gallon). See more discussion in the Response to Comments Document in 
the Public Docket.
4. Distribution Costs
    We estimate that as a result of today's rule, distribution costs 
will increase by 0.5 cents per gallon of highway diesel fuel supplied 
when the sulfur requirements are fully implemented beginning in the 
year 2010. During the initial years (2006 through May 31, 2010) we 
estimate that the increase in distribution costs will be 0.4 cents per 
gallon of highway diesel fuel supplied, with an additional 0.7 cents 
per gallon equivalent related to capital costs for additional storage 
tanks to handle two grades of highway diesel fuel.188
---------------------------------------------------------------------------

    \188\ This cost is expressed in terms of the total volume of 
highway diesel fuel supplied, including the fuel which meets the 15 
ppm sulfur cap and that which meets the 500 ppm sulfur cap.
---------------------------------------------------------------------------

    In the proposal, we estimated that distribution costs would 
increase by 0.2 cents per gallon if the proposed requirement that the 
entire highway diesel fuel pool meet a 15 ppm sulfur cap beginning in 
2006 be adopted. This cost was comprised of roughly 0.1 cents per 
gallon due to an increase in pipeline interface and testing costs, and 
0.1 cents per gallon for distributing the additional volume of highway 
diesel fuel needed due to an anticipated decrease in fuel energy 
density as a side effect of reducing the sulfur content to the proposed 
15 ppm cap. The case evaluated in the NPRM is most similar to that for 
the fully implemented sulfur program in this final rule.
    We took advantage of additional information contained in the 
comments to the NPRM in formulating a more comprehensive estimate of 
the

[[Page 5097]]

distribution costs under today's rule. In some cases this involved 
adjusting an estimate for a parameter that factored into our 
calculation of costs in the NPRM. One important example is that we 
increased our estimate of the additional volume of highway diesel 
shipped by pipeline that would need to be downgraded to a lower-value 
product. This product downgrade is necessitated by mixing that takes 
place between products that abut each other while in the pipeline. The 
mixture is referred to as interface when it can be blended into another 
product and transmix when it must be returned to the refinery for 
reprocessing. In other cases, our reevaluation of distribution costs 
included the consideration of parameters that did not factor into the 
estimation of distribution costs in the proposed rule. For example, 
commenters to the NPRM brought to our attention that there would be 
additional costs associated with needed changes in the handling 
practices for interface volumes which result from shipments of jet fuel 
and highway diesel fuel that abut each other in the pipeline.
    There are a number of common factors in the estimation of 
distribution costs during the initial period and after the sulfur 
requirements are fully implemented, such as the increase in interface 
volumes for pipeline shipments of highway diesel fuel. However, there 
are other factors that are unique to the estimation of costs during the 
initial years as well. For example, with two grades of highway diesel 
fuel in the distribution system at the same time there are costs 
associated with the need for additional storage tanks at some petroleum 
terminals and refineries. Our estimation of distribution costs under 
these two periods is discussed separately in the following sections. 
Where there is a commonality, the issue is discussed under the section 
on distribution costs for the fully implemented program.
a. Distribution Costs Under the Fully Implemented Program
    Based on the considerations discussed below, we estimate that the 
increase in distribution costs under the fully implemented sulfur 
program will be 0.5 cents per gallon of highway diesel fuel supplied.
    The cost of distributing the additional volume of highway diesel 
fuel needed to compensate for the lower energy density of highway 
diesel fuel that meets a 15 ppm sulfur cap is estimated at 0.17 cents 
per gallon of highway diesel fuel supplied. As in the NPRM, the cost of 
producing this additional volume was included in the calculation of 
refinery costs (see Section V.C.1.). In the NPRM, we estimated that the 
cost of distributing highway diesel fuel was equal to the difference in 
price at the refinery rack and the retail price. For today's final 
rule, we based our estimate of distribution cost on a PADD by PADD 
evaluation of the difference in the price of highway diesel fuel at the 
refiner rack versus the retail price. The price differential for each 
PADD was weighted by the additional volume of fuel we anticipate will 
need to be produced in each PADD to arrive at an estimate of 
distributing the additional volume needed for the nation as a whole. We 
believe this approach provides a more accurate estimate of costs.
    Based on additional information provided in the comments on the 
changes in pipeline interface practices that would result from today's 
rule, we adjusted our estimate of the increased volume of highway 
diesel fuel that would be downgraded to a lower-value product from 1.5 
percent to 2.2 percent of highway diesel fuel supplied (see the RIA to 
this rule). As in the NPRM, the cost of producing this additional 
volume was included in the calculation of refinery costs (see Section 
V.C.1.). The cost of downgrading the increased volume of highway diesel 
fuel to a lower-value product is based on the difference in the cost of 
15 ppm sulfur diesel fuel and the product to which the interface is 
downgraded. Under the fully imlemented program, this downgrade would be 
made into the nonroad diesel pool. The cost of this increased volume of 
downgrade is estimated at approximately 0.14 cents per gallon of 
highway diesel supplied.
    We identified that there would also be an increase in the economic 
impact for the existing volume of interface currently associated with 
pipeline shipments of highway diesel fuel. This is because the cost of 
downgrading the existing interface volume would be determined by the 
difference between the cost of 15 ppm sulfur fuel and nonroad diesel 
fuel rather than the difference in cost between current 500 ppm diesel 
fuel and nonroad diesel fuel as it is today. We estimate that the 
increase in the cost of downgrading the existing highway diesel 
interface would be 0.09 cents per gallon of highway diesel fuel 
supplied.
    We anticipate that there may be minor costs in addition to those 
discussed above associated with optimizing the distribution system to 
adequately limit sulfur contamination. These costs could result from 
various minor changes to distribution practices and or hardware 
discovered to be needed by industry while preparing to comply with 
today's rule. While it is not possible to specifically identify the 
nature of these changes, they could include the occasional replacement 
of a leaking valve or improvements in communication practices to 
facilitate batch changes in the pipeline system. There may also be some 
cost associated with the process that we anticipate the distribution 
industry will undertake to evaluate its readiness to comply with the 
requirements in today's rule. Such costs might result from testing to 
determine the level of contamination introduced through the use of 
various distribution hardware or practices. It is not possible to 
specifically identify the costs that might be associated with this 
optimization process. However, given the limited nature of the changes 
that might be needed and that the need for such changes would not be 
widespread, we believe that the associated costs would not pose a 
substantial burden. We estimate that the miscellaneous costs associated 
with optimizing the distribution system to limit sulfur contamination 
would be 0.025 cents per gallon of highway diesel fuel supplied (on 
average) during the period from when the sulfur program is fully 
implemented (2010) through the year 2020. These costs were amortized at 
a rate of 7% over the period of 2006 through 2020. The per gallon cost 
is somewhat higher during the initial years.
    Commenters to the proposed rule stated that it is current practice 
for all of the interface generated when highway diesel fuel abuts jet 
fuel in the pipeline to be cut into highway diesel fuel. They pointed 
out that this practice would no longer be possible when all highway 
diesel fuel is required to meet a 15 ppm sulfur cap because of the 
relatively high sulfur content of jet fuel (as high as 3000 
ppm).189 They stated that the mixture of highway diesel fuel 
meeting a 15 ppm sulfur cap and jet fuel would need to be returned from 
the terminal to the refinery for reprocessing, at high cost (i.e. would 
need to be treated as transmix). While we agree that handling 
procedures for this mixture will need to change, we believe that it 
will not be necessary to treat it as transmix. We believe that there 
will be opportunity for the mixture to be sold from the terminal into 
the nonroad diesel pool. This will increase the cost associated with 
downgrading this mixture.

[[Page 5098]]

Expressed in terms of the volume of highway diesel fuel supplied, we 
estimate this cost at 0.07 cents per gallon. Additional storage tanks 
will be needed to handle the mixture at those terminals that currently 
do not handle nonroad diesel fuel. The cost of these tanks has been 
fully accounted for in the calculation of costs during the initial 
years of the program.
---------------------------------------------------------------------------

    \189\ During the initial years of the sulfur program, the 
current practice used to handle the interface between shipments of 
jet fuel and highway diesel fuel can be used for that portion of the 
highway diesel fuel that continues to meet a 500 ppm sulfur cap.
---------------------------------------------------------------------------

    The additional quality control testing at the terminal level needed 
to ensure compliance with the 15 ppm sulfur cap would be the same 
during the initial years as after the requirements are fully 
implemented. We estimate that the cost of this additional testing would 
be as we projected in the proposal, 0.002 cent per gallon of highway 
diesel supplied (see the RIA to this rule).
    We believe that there will not be a significant increase in the 
volume of highway diesel fuel discovered to exceed the sulfur standard 
downstream of the refinery as a result of today's rule. We believe this 
will be the case both during the initial years and after the sulfur 
requirements are fully implemented. We anticipate that distributors 
will quickly optimize their practices to avoid sulfur contamination. We 
also anticipate that distributors will gain some experience in reducing 
sulfur contamination in the distribution system through complying with 
the recently finalized Tier 2 low sulfur gasoline requirements (65 FR 
6698, February 10, 2000). While outside the scope of this final rule, 
it is worth pointing out that potential difficulties in distributing 15 
ppm diesel fuel would be lessened if the sulfur content of nonroad 
diesel fuel is reduced by a future rulemaking (as discussed in Section 
8). We anticipate that the batches of highway diesel fuel that are 
discovered to exceed the 15 ppm sulfur cap will be coped with as 
follows:
--When possible, by blending highway diesel fuel that is below the 15 
ppm cap with the out-of-specification batch to bring the resulting 
mixture into compliance. This practice will be more difficult than it 
is currently because the amount of fuel needed to blend the out-of-
specification batch into compliance may increase. However, we expect it 
to continue to be the method of choice for handling out-of-
specification highway diesel whenever possible.
--By downgrading the batch either to nonroad diesel fuel or to 500 ppm 
highway diesel during the initial years.
--By reprocessing the batch to meet the 15 ppm cap, but only in those 
infrequent instances where the previous options do not exist.
    We do not believe that the cost of handling out-of specification 
highway diesel batches will increase significantly as a result of 
today's action.
    Tank truck, tank wagon, and barge operators may need to more 
carefully and consistently observe current industry practices to limit 
contamination in some situations. However, these situations are more 
the exception than the rule and are of a limited nature. Consequently, 
we believe that this can be accomplished at an insignificant cost. 
Additional considerations exist for distributors during the initial 
years as discussed in the following section.
    Please refer to the Response to Comments Document for an evaluation 
of the comments received on the increase in fuel distribution costs 
associated with today's rule, and to the RIA for a detailed discussion 
of the way in which we derived the our cost estimates.
b. Distribution Costs During the Initial Years
    The factors that cause distribution costs to differ during the 
initial years include:

--Having a lesser volume of 15 ppm diesel fuel in the system reduces 
the costs associated with distributing 15 ppm fuel.
--Having an additional grade of highway diesel fuel in the system (500 
ppm) creates additional pipeline interface volumes, and additional 
product downgrade costs.
--The need for additional equipment to handle an additional grade leads 
to additional costs that must be accounted for during the initial 
years.
--Having 500 ppm highway diesel fuel in the system allows some 
opportunity for the pipeline interface volumes associated with the 
shipment of 15 ppm fuel and jet fuel to be downgraded to 500 ppm diesel 
fuel rather than nonroad diesel fuel. This will reduce the cost 
associated with downgrading the subject interface volumes.

    In calculating the distribution costs for the initial years of the 
program, we estimated that 60 percent of the 15 ppm highway diesel fuel 
shipped by pipeline will be carried in pipelines that choose not to 
carry 500 ppm diesel fuel. We estimated that the remaining 40 percent 
of 15 ppm highway diesel fuel shipped by pipeline would be carried in 
pipelines that carry 500 ppm as well as nonroad diesel fuel. For the 
sake of simplicity and to allow a comparison with distribution costs 
when the program is fully implemented, the distribution costs during 
the initial years as discussed below are expressed in terms of the 
total volume of highway diesel fuel supplied. This includes 500 ppm as 
well as 15 ppm highway diesel fuel.
    For the reasons outlined above, the following costs, which are also 
present under the fully implemented sulfur program, were adjusted to 
reflect the unique conditions during the initial years. During the 
initial years, the cost of distributing the additional volume of 
highway diesel fuel needed to compensate for lower energy density of 15 
ppm sulfur fuel is estimated at 0.14 cents per gallon of highway diesel 
fuel supplied. The cost of the increased volume of highway diesel fuel 
that must be downgraded to a lower-value product is estimated at 0.1 
cents per gallon of highway diesel supplied. We estimate that during 
the initial years of the program the increase in the cost of 
downgrading the existing highway diesel interface would be 0.08 cents 
per gallon of highway diesel fuel supplied. During the initial years, 
the cost of downgrading the interface between pipeline shipments of jet 
fuel and highway diesel fuel is estimated to increase by 0.03 cents per 
gallon of highway diesel fuel supplied. The cost of the additional 
tanks required at terminals to handle this interface is estimated at 
0.009 cents per gallon of highway diesel fuel supplied. This tank cost 
was amortized over the period of the four-year transition period. We 
estimate that the miscellaneous costs associated with optimizing the 
distribution system to limit sulfur contamination would be 0.027 cents 
per gallon of highway diesel fuel supplied (on average) during the 
initial period (2006--2010).
    As noted in the previous section, the additional quality control 
testing at the terminal level needed to ensure compliance with the 15 
ppm sulfur cap would be the same during the initial years and after the 
requirements are fully implemented. We estimate that the cost of this 
additional testing would be as we projected in the proposal, 0.002 cent 
per gallon of highway diesel supplied.
    The cost during the initial years of downgrading the additional 
interface volumes associated with having two grades of highway diesel 
fuel in part of the pipeline system is estimated at 0.004 cents per 
gallon of highway diesel full supplied
    The most substantial costs associated with the provisions during 
the initial years of the program are due to the need to handle an 
additional grade of highway diesel fuel in the distribution

[[Page 5099]]

system. Under the final program, the production of 500 ppm sulfur fuel 
will be much less than that of 15 ppm fuel. At the same time, most of 
the diesel vehicle fleet can burn 500 ppm fuel during the initial 
period. Because of its greater volume and the need to distribute it 
everywhere in the country, we expect that essentially all pipelines and 
terminals will handle 15 ppm fuel. In contrast, distribution of 500 ppm 
fuel will concentrate on those areas nearest the refineries producing 
that fuel, plus a few major pipelines serving major refining areas.
    Regarding distribution to the final user, we expect that nearly all 
truck stops in areas where 500 ppm fuel is available will invest in 
piping and tankage to handle a second fuel. Because of the significant 
expense involved in adding a second tank, in these areas, we expect 
service stations will only carry one fuel or the other, as market 
demands dictate. Likewise, we expect that centrally fueled fleets and 
card locks will only handle 15 ppm fuel. Under this scenario, sales of 
500 ppm fuel are limited to only those vehicles which refuel at truck 
stops and service stations. This is somewhat conservative since some 
centrally fueled fleets may have the flexibility to inexpensively 
handle two fuels. Likewise, some card locks in a given area may be able 
to carry 15 ppm fuel and others 500 ppm fuel and still serve their 
clients at little extra cost. Still, given the above assumptions, we 
project that the 500 ppm fuel will have to be distributed to areas 
representing about 50 percent of the national diesel fuel demand. Also, 
as the fleet turns over to 2007 and later vehicles during the initial 
years, the amount of 500 ppm fuel produced will gradually decrease from 
just over 20 percent in 2007 to about 16 percent in 2010.
    The tankage cost at refineries, terminals, pipelines and bulk 
plants handling both fuels is estimated to be $0.81 billion. The cost 
for truck stops to handle two fuels is roughly $0.24 billion, for a 
total cost of $1.05 billion. Amortized over all of the highway diesel 
fuel supplied during the initial four-years (15 ppm and 500 ppm) at 7 
percent per annum, the cost per gallon is 0.7 cents.
5. Benefits of Low-Sulfur Diesel Fuel for the Existing Diesel Fleet
    We estimate that the low-sulfur diesel fuel will provide additional 
benefits to the existing heavy-duty vehicle fleet as soon as the fuel 
is introduced. We believe these benefits will offer significant cost 
savings to the vehicle owner without the need for purchasing any new 
technologies. The RIA has catalogued a variety of benefits from the 
low-sulfur diesel fuel. These benefits are summarized in Table V.C-3.

 Table V.C-3.--Components Potentially Affected by Lower Sulfur Levels in
                               Diesel Fuel
------------------------------------------------------------------------
                                 Effect of lower     Potential impact on
     Affected components             sulfur             engine system
------------------------------------------------------------------------
Piston Rings................  Reduce corrosion      Extended engine life
                               wear.                 and less frequent
                                                     rebuilds.
Cylinder Liners.............  Reduce corrosion      Extended engine life
                               wear.                 and less frequent
                                                     rebuilds.
Oil Quality.................  Reduce deposits and   Reduce wear on
                               less need for         piston ring and
                               alkaline additives.   cylinder liner and
                                                     less frequent oil
                                                     changes.
Exhaust System (tailpipe)...  Reduces corrosion     Less frequent part
                               wear.                 replacement.
EGR.........................  Reduces corrosion     Less frequent part
                               wear.                 replacement.
------------------------------------------------------------------------

    The actual value of these benefits over the life of the vehicle 
will depend upon the length of time that the vehicle operates on low-
sulfur diesel fuel and the degree to which vehicle operators change 
engine maintenance patterns to take advantage of these benefits. For a 
vehicle near the end of its life in 2007 the benefits will be quite 
small. However for vehicles produced in the years immediately preceding 
the introduction of low-sulfur fuel the savings will be substantial. 
The RIA estimates that a heavy heavy-duty vehicle introduced into the 
fleet in 2006 will realize savings of $610 over its life. This savings 
could alternatively be expressed in terms of fuel costs as 
approximately 1 cent per gallon as discussed in the RIA. These savings 
will occur without additional new cost to the vehicle owner beyond the 
incremental cost of the low-sulfur diesel fuel, although these savings 
will require changes to existing maintenance schedules. Such changes 
seem likely given the magnitude of the savings and the nature of the 
regulated industry.

D. Aggregate Costs

    Using current data for the size and characteristics of the heavy-
duty vehicle fleet and making projections for the future, the diesel 
per-engine, gasoline per-vehicle, and per-gallon fuel costs described 
above can be used to estimate the total cost to the nation for the 
emission standards in any year. Figure V.D-1 portrays the results of 
these projections.190 All capital costs have been amortized.
---------------------------------------------------------------------------

    \190\ Figure V.E-1 is based on the amortized engine, vehicle and 
fuel costs as described in the RIA. Actual capital investments, 
particularly important for fuels, would occur prior to and during 
the initial years of the program.
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BILLING CODE 6560-50-P

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[GRAPHIC] [TIFF OMITTED] TR18JA01.006

BILLING CODE 6560-50-C

[[Page 5101]]

    As can be seen from the figure, the annual costs start out at less 
than 1.0 billion dollars in year 2006 and increase during the initial 
years to about $3.6 billion in 2010. Thereafter, total annualized costs 
are projected to continue increasing due to the effects of projected 
growth in engine sales and fuel consumption. The RIA provides further 
detail regarding these cost projections.
    Future consumption of 15 ppm diesel fuel may be influenced by a 
potential influx of diesel-powered cars and light trucks into the 
light-duty fleet. At the present time, virtually all cars and light 
trucks being sold are gasoline fueled. However, the possibility exists 
that diesels will become more prevalent in the car and light-duty truck 
fleet, since automotive companies have announced their desire to 
increase their sales of diesel cars and light trucks. For the Tier 2 
rulemaking, the Agency performed a sensitivity analysis using 
A.D.Little's ``most likely'' increased growth scenario of diesel 
penetration into the light-duty vehicle fleet which culminated in a 9 
percent and 24 percent penetration of diesel vehicles in the LDV and 
LDT markets, respectively, in 2015 (see Tier 2 RIA, Table III.A.-13). 
Were this scenario to play out, the increased number of diesel-powered 
cars and light-duty trucks would increase the societal costs (those 
costs, in total, paid by consumers) for the higher priced diesel fuel 
because more diesel fuel would be consumed. However, were more diesel 
vehicles to penetrate the light-duty fleet, less gasoline would be 
consumed than was estimated in our Tier 2 cost analysis. Also, diesel 
vehicles tend to get higher fuel economy. As a result, the effect of 
increased dieselization of the light-duty fleet will likely have little 
or no impact on the aggregate costs estimated for the standards being 
finalized in today's action.

E. Cost Effectiveness

    One tool that can be used to assess the value of new standards for 
heavy-duty vehicles and engines is cost effectiveness, in which the 
costs incurred to reach the standards are compared to the mass of 
emission reductions. This analysis results in the calculation of a $/
ton value, the purpose of which is to show that the reductions from the 
engine and fuel controls being finalized today are cost effective, in 
comparison to alternative means of control. This analysis involves a 
comparison of our program not only to past measures, but also to other 
potential future measures that could be implemented. Both EPA and 
States have already adopted numerous control measures, and remaining 
measures tend to be more expensive than those previously employed. As 
we and States tend to employ the most cost effective available measures 
first, more expensive ones must be adopted to achieve further emission 
reductions.
    Comments we received in response to our Notice of Proposed 
Rulemaking on the subject of our cost effectiveness analysis are 
addressed in the Response to Comments Document.
1. What Is the Cost Effectiveness of This Program?
    We have calculated the cost-effectiveness of our diesel engine/
gasoline vehicle/diesel sulfur standards based on two different 
approaches. The first considers the net present value of all costs 
incurred and emission reductions generated over the life of a single 
vehicle meeting our standards. This per-vehicle approach focuses on the 
cost-effectiveness of the program from the point of view of the 
vehicles and engines which will be used to meet the new requirements. 
However, the per-vehicle approach does not capture all of the costs or 
emission reductions from our diesel engine/gasoline vehicle/diesel 
sulfur program since it does not account for the use of 15 ppm diesel 
fuel in current diesel engines. Therefore, we have also calculated a 
30-year net present value cost-effectiveness using the net present 
value of costs and emission reductions for all in-use vehicles over a 
30-year time frame. The baseline or point of comparison for this 
evaluation is the previous set of engine, vehicle, and diesel sulfur 
standards (in other words, the applicable 2006 model year standards).
    As described earlier in the discussion of the cost of this program, 
the cost of complying with the new standards will decline over time as 
manufacturing costs are reduced and amortized capital investments are 
recovered. To show the effect of declining cost in the per-vehicle 
cost-effectiveness analysis, we have developed both near term and long 
term cost-effectiveness values. More specifically, these correspond to 
vehicles sold in years one and six of the vehicle and fuel programs. 
Chapter VI of the RIA contains a full description of this analysis, and 
you should look in that document for more details of the results 
summarized here.
    The 30-year net present value approach to calculating the cost-
effectiveness of our program involves the net present value of all 
nationwide emission reductions and costs for a 30 year period beginning 
with the start of the diesel fuel sulfur program and introduction of 
model year 2007 vehicles and engines in year 2006. This 30-year 
timeframe captures both the early period of the program when very few 
vehicles that meet our standards will be in the fleet, and the later 
period when essentially all vehicles in the fleet will meet the new 
standards. We have calculated the 30-year net present value cost-
effectiveness using the net present value of the nationwide emission 
reductions and costs for each calender year. These emission reductions 
and costs are given for every calendar year in the RIA, in addition to 
details of the methodology we used to calculated the 30-year net 
present value cost-effectiveness.
    Our per-vehicle and 30-year net present value cost-effectiveness 
values are given in Tables V.E-1 and V.E-2. Table V.E-1 summarizes the 
per-vehicle, net present value cost-effectiveness results for our 
diesel engine/gasoline vehicle/diesel sulfur standards using sales 
weighted averages of the costs (both near term and long term) and 
emission reductions of the various vehicle and engine classes affected. 
Table V.E-2 provides the same information from the program 30-year net 
present value perspective. It is based on the net present value of the 
30 year stream of vehicle and fuel costs and NMHC+ NOX and 
PM emission reductions, resulting in the 30-year net present value 
cost-effectiveness. Diesel fuel costs applicable to diesel engines have 
been divided equally between the adsorber and trap, since 15 ppm diesel 
fuel is intended to enable all technologies to meet our standards. In 
addition, since the trap produces reductions in PM and also operates as 
an enabling device for the NOX adsorber, we have divided the 
total trap costs equally between compliance with the PM standard and 
compliance with the NOX and NMHC standards.
    Tables V.E-1 and V.E-2 also display cost-effectiveness values based 
on two approaches to account for the reductions in SO2 
emissions associated with the reduction in diesel fuel sulfur. While 
these reductions are not central to the program and are therefore not 
displayed with their own cost-effectiveness, they do represent real 
emission reductions due to our program. The first set of cost-
effectiveness numbers in the tables simply ignores these reductions and 
bases the cost-effectiveness on only the NOX, NMHC, and PM 
emission reductions from our program. The second set accounts for these 
ancillary reductions by crediting some of the cost of the program to 
SO2. The amount of cost allocated to SO2 is based 
on the cost-effectiveness of SO2

[[Page 5102]]

emission reductions that could be obtained from alternative, potential 
future EPA programs. The SO2 credit was applied only to the 
PM calculation, since SO2 reductions are primarily a means 
to reduce ambient PM concentrations.

 Table V.E-1.--Per-Engine a Cost Effectiveness of the Standards for 2007
                          and Later MY Vehicles
------------------------------------------------------------------------
                                                             Discounted
                                              Discounted   lifetime cost
                Pollutants                  lifetime cost  effectiveness
                                            effectiveness   per ton with
                                               per ton      SO2 credit b
------------------------------------------------------------------------
Near-term costs:
  NOX+NMHC................................        $2,125         $2,125
  PM......................................        14,237          7,599
Long-term costs:
  NOX+NMHC................................         1,621          1,621
  PM......................................        11,340         4,701
------------------------------------------------------------------------
a As described above, per-engine cost effectiveness does not include any
  costs or benefits from the existing, pre-control, fleet of vehicles
  that would use the 15 ppm diesel fuel.
b $446 credited to SO2 (at $4800/ton) for PM cost effectiveness.


   Table V.E-2.--30-Year Net Present Value a Cost Effectiveness of the
                                Standards
------------------------------------------------------------------------
                                                              30-year
                                               30-year      n.p.v. cost
                                             n.p.v. cost   effectiveness
                                            effectiveness   per ton with
                                               per ton      SO2 credit b
------------------------------------------------------------------------
NOX+NMHC..................................        $2,149         $2,149
PM........................................        13,607         4,195
------------------------------------------------------------------------
a This cost effectiveness methodology reflects the total fuel costs
  incurred in the early years of the program when the fleet is
  transitioning from pre-control to post-control diesel vehicles. In
  2007 10% of highway diesel fuel is anticipated to be consumed by 2007
  MY vehicles. By 2012 this increases to >50% for 2007 and later MY
  vehicles.
b $7.1 billion credited to SO2 (at $4800/ton).

2. Comparison With Other Means of Reducing Emissions
    In comparison with other mobile source control programs, we believe 
that our program represents a cost effective strategy for generating 
substantial NOX, NMHC, and PM reductions. This can be seen 
by comparing the cost effectiveness of today's program with a number of 
mobile source standards that EPA has adopted in the past. Table V.E-3 
summarizes the cost effectiveness of several past EPA actions for 
NOX+ NMHC. Table V.E-4 summarizes the cost effectiveness of 
several past EPA actions for PM.

 Table V.E-3.--Cost Effectiveness of Previous Mobile Source Programs for
                                NOX+NMHC
------------------------------------------------------------------------
                        Program                               $/ton
------------------------------------------------------------------------
Tier 2 vehicle/gasoline sulfur.........................      1,340-2,260
2004 Highway HD diesel.................................          212-414
Off-highway diesel engine..............................          425-675
Tier 1 vehicle.........................................      2,054-2,792
NLEV...................................................            1,930
Marine SI engines......................................      1,171-1,846
On-board diagnostics...................................            2,313
Marine CI engines......................................          24-176
------------------------------------------------------------------------
Note: Costs adjusted to 1999 dollars.


 Table V.E-4.--Cost Effectiveness of Previous Mobile Source Programs for
                                   PM
------------------------------------------------------------------------
                       Program                               $/ton
------------------------------------------------------------------------
Marine CI engines....................................          5222-3881
1996 urban bus.......................................      12,264-19,622
Urban bus retrofit/rebuild...........................             30,251
1994 highway HD diesel...............................     20,900-24,467
------------------------------------------------------------------------
Note: Costs adjusted to 1999 dollars.

    We can see from these tables that the cost effectiveness of our 
diesel engine/gasoline vehicle/diesel sulfur standards falls within the 
range of these other programs for both NOX+NMHC and PM. Our 
program overlaps the range of the recently promulgated standards for 
Tier 2 light-duty vehicles and gasoline sulfur shown in Table V.E-3. 
Our program also overlaps the cost-effectiveness of past programs for 
PM. It is true that some previous programs have been more cost 
efficient than the program we are finalizing today. However, it should 
be expected that the next generation of standards will be more 
expensive than the last, since the least costly means for reducing 
emissions is generally pursued first.
    In evaluating the cost effectiveness of our diesel engine/gasoline 
vehicle/diesel sulfur program, we also considered whether the new 
standards are cost effective in comparison with possible stationary 
source controls. In the context of the Agency's rulemaking which would 
have revised the ozone and PM NAAQS,191 the Agency compiled 
a list of additional known technologies that could be considered in 
devising new emission reductions strategies.192 Through this 
broad review, over 50 technologies were identified that could reduce 
NOX, VOC, or PM. The cost effectiveness of these 
technologies averaged approximately $5,000/ton for VOC, $13,000/ton for 
NOX, and $40,000/ton for PM. Although a $10,000/ton limit 
was actually used in the air quality analysis presented in the NAAQS 
revisions rule, these values clearly indicate that, not only are future 
emission control strategies likely to be more expensive (less cost 
effective) than past strategies, but the cost effectiveness of our 
program falls well below the average of those choices, and is near the 
lower end of the range of potential future strategies.
---------------------------------------------------------------------------

    \191\ This rulemaking was remanded to EPA by the D.C. Circuit 
Court on May 14, 1999. However, the analyses completed in support of 
that rulemaking are still relevant, since they were designed to 
investigate the cost effectiveness of a wide variety of potential 
future emission control strategies. An appeal is currently pending 
before the U.S. Supreme Court.
    \192\ Regulatory Impact Analyses for the Particulate Matter and 
Ozone National Ambient Air Quality Standards and Proposed Regional 
Haze Rule,'' Appendix B, ``Summary of control measures in the PM, 
regional haze, and ozone partial attainment analyses,'' Innovative 
Strategies and Economics Group, Office of Air Quality Planning and 
Standards, U.S. Environmental Protection Agency, Research Triangle 
Park, NC, July 17, 1997.
---------------------------------------------------------------------------

    In summary, we believe that the weight of the evidence from 
alternative means of providing substantial NOX + NMHC and PM 
emission reductions indicates that our diesel engine/gasoline vehicle/
diesel sulfur program is cost effective relative to other means of 
achieving air quality improvements. We believe this is true from the 
perspective of other mobile source control programs and from the 
perspective of other stationary source technologies that might be 
considered.

F. Does the Value of the Benefits Outweigh the Cost of the Standards?

    While EPA uses relative cost-effectiveness as the principal 
economic policy criterion for these standards, further insight 
regarding the merits of the standards can be provided by benefit-cost 
analysis. The purpose of this section is to summarize the methods we 
used and results we obtained in conducting an analysis of the economic 
benefits of the HD Engine/Diesel Fuel program, and to compare these 
economic benefits with the estimated costs of the rule. In summary, the 
results of our analysis indicate that the economic benefits of the HD 
Engine/Diesel Fuel standards will exceed the costs of meeting the 
standards. The annual estimated benefits we were able to quantify were 
$70.4 billion (1999$).
1. What Was Our Overall Approach to the Benefit-Cost Analysis?
    The basic question we sought to answer in the benefit-cost analysis 
was, ``What are the net yearly economic benefits to society of the 
reduction in mobile source emissions likely to be

[[Page 5103]]

achieved by the final HD Engine/Diesel Fuel program?'' In designing an 
analysis to address this question, we selected a future year for 
analysis (2030) that is representative of full-implementation of the 
program (i.e., when the US heavy-duty truck fleet is composed of 
virtually only compliant heavy-duty vehicles). We also adopted an 
analytical structure and sequence similar to that used in the ``section 
812 studies'' to estimate the total benefits and costs of the full 
Clean Air Act.193 Moreover, we used many of the same models 
and assumptions used in the section 812 studies as well as other 
Regulatory Impact Analyses (RIAs) prepared by the Office of Air and 
Radiation. One difference from previous RIAs, however, is that for 
particulate matter air quality modeling we used the Regulatory Modeling 
System for Aerosols and Deposition (REMSAD) model. This model was used 
in the most recent section 812 study to model air quality in the West. 
By adopting the major design elements, models, and assumptions 
developed for the section 812 studies and other RIAs, we have largely 
relied on methods which have already received extensive review by the 
independent Science Advisory Board (SAB), by the public, and by other 
federal agencies.
---------------------------------------------------------------------------

    \193\ The section 812 studies include: (1) US EPA, Report to 
Congress: The Benefits and Costs of the Clean Air Act, 1970 to 1990, 
October 1997 (also known as the ``Section 812 Retrospective 
Report''); and (2) the first in the ongoing series of prospective 
studies estimating the total costs and benefits of the Clean Air Act 
(see EPA report number: EPA-410-R-99-001, November 1999).
---------------------------------------------------------------------------

2. What Are the Significant Limitations of the Benefit-Cost Analysis?
    Every benefit-cost analysis examining the potential effects of a 
change in environmental protection requirements is limited to some 
extent by data gaps, limitations in model capabilities (such as 
geographic coverage), and uncertainties in the underlying scientific 
and economic studies used to configure the benefit and cost models. 
Deficiencies in the scientific literature often result in the inability 
to estimate changes in health and environmental effects, such as 
potential increases in premature mortality associated with increased 
exposure to carbon monoxide. Deficiencies in the economics literature 
often result in the inability to assign economic values even to those 
health and environmental outcomes which can be quantified. While these 
general uncertainties in the underlying scientific and economics 
literatures are discussed in detail in the RIA and its supporting 
documents and references, the key uncertainties which have a bearing on 
the results of the benefit-cost analysis of today's action are the 
following:
     The exclusion of potentially significant benefit 
categories (e.g., health and ecological benefits of reduction in 
hazardous air pollutants emissions);
     Errors in measurement and projection for variables such as 
population growth;
     Uncertainties in the estimation of future year emissions 
inventories and air quality;
     Uncertainties associated with the extrapolation of air 
quality monitoring data to some unmonitored areas required to better 
capture the effects of the standards on the affected population;
     Variability in the estimated relationships of health and 
welfare effects to changes in pollutant concentrations; and
     Uncertainties associated with the effect of potential 
future actions to limit emissions.
    Despite these uncertainties, we believe the benefit-cost analysis 
provides a reasonable indication of the expected economic benefits of 
the HD Engine/Diesel Fuel program in 2030 under a set of assumptions. 
For the final HD Engine/Diesel Fuel benefit analysis, we adopt an 
approach similar to the Tier 2/Gasoline Sulfur RIA and the section 812 
study. We first present an estimate for a primary set of benefit 
endpoints followed by a presentation of alternative calculations of key 
health and welfare endpoints to characterize uncertainty in this 
primary set.
    One key area of uncertainty is the value of a statistical life 
(VSL) for risk reductions in mortality. The adoption of a value for the 
projected reduction in the risk of premature mortality is the subject 
of continuing discussion within the economic and public policy analysis 
community. There is general agreement that the value to an individual 
of a reduction in mortality risk tends to vary based on several 
factors, including the age of the individual, the type of risk, the 
level of control the individual has over the risk, the individual's 
attitude toward risk, and the health status of the individual. Age in 
particular may be an important difference between populations affected 
by air pollution mortality risks and populations affected by workplace 
risks. Premature mortality risks from air pollution tend to affect the 
very old more than the working age population. As such, any adjustments 
to VSL for age differences may have a large impact on total benefits. 
However, EPA prefers not to draw distinctions in the monetary value 
assigned to the lives saved even if they differ in age, health status, 
socioeconomic status, gender or other characteristic of the adult 
population.
    In the recent Tier 2/Gasoline Sulfur benefits analysis, we employed 
a value of statistical life years (VSLY) approach developed for the 
Section 812 studies in exploring the impact of age on VSL. However, 
since these earlier analyses were completed, the SAB Environmental 
Economics Advisory Committee (EEAC) issued a new advisory report which 
identifies significant additional limitations in this method. 
Specifically, the SAB EEAC notes that ``inferring the value of a 
statistical life year, however, requires assumptions about the discount 
rate and about the time path of expected utility of consumption'' (EPA-
SAB-EEAC-00-013). They also note that ``the theoretically appropriate 
method is to calculate [willingness to pay (WTP)] for individuals whose 
ages correspond to those of the affected population, and that it is 
preferable to base these calculations on empirical estimates of WTP by 
age.''
    SAB advised that the EPA ``continue to use a wage-risk-based VSL as 
its primary estimate, including appropriate sensitivity analyses to 
reflect the uncertainty of these estimates,'' and that ``the only risk 
characteristic for which adjustments to the VSL can be made is the 
timing of the risk'' (EPA-SAB-EEAC-00-013). In developing our primary 
estimate of the benefits of premature mortality reductions, we have 
appropriately discounted over the lag period between exposure and 
premature mortality. However, an empirical basis that meets the SAB's 
standards of reliability for adjusting the current $6 million VSL for 
many of these factors does not yet exist. A discussion of these factors 
is contained in the RIA and supporting documents. EPA recognizes the 
need for additional research by the scientific community to develop 
additional empirical support for adjustments to VSL for the factors 
mentioned above.
    In accordance with the SAB advice, we use the VSL in our primary 
estimate and present alternative calculations of adjustment for age and 
other factors. Specifically, several studies conducted by Jones-Lee, et 
al. (1985, 1989, 1993) found a significant effect of age on the value 
of mortality risk reductions expressed by citizens in the United 
Kingdom. The results are supported by a recent analysis which asked 
samples of Canadian residents their values for reductions in mortality 
risk (Krupnick et al., 2000). As alternative calculations, we apply the 
ratios based on the Jones-

[[Page 5104]]

Lee, et al. (1989, 1993) studies to the estimated premature mortalities 
within the appropriate age groups to provide alternative age-adjusted 
estimates of the value of avoided premature mortalities.
    In the same way, the presentation of the other alternative 
calculations for certain endpoints seeks to demonstrate how much the 
overall benefit estimate might vary based on the value EPA has given to 
a parameter (which has uncertainty associated with it) underlying the 
estimates for human health and environmental effect incidence and the 
economic valuation of those effects. These alternative calculations 
represent conditions that might occur; however, EPA has selected the 
best values supported by current scientific literature for use in the 
primary estimate. The alternate calculations include the following:
     Estimating PM-related premature mortality benefits based 
on different concentration-response (C-R) function estimates;
     Value of avoided premature mortality incidences based on 
VSLY;
     Consideration of reversals in chronic bronchitis treated 
as lowest severity cases;
     Estimate of ozone-related chronic asthma;194
---------------------------------------------------------------------------

    \194\ McDonnell, W.F., D.E. Abbey, N.Nishino, M.D. Lebowitz. 
Long-term Ambient Ozone Concentration and the Incidence of Asthma in 
Nonsmoking Adults: The Ahsmog Study. Environmental Research. A:80, 
110-121. 1999.
---------------------------------------------------------------------------

     Value of visibility changes in all Federal Class I areas;
     Value of visibility changes in US residential areas;
     Value of reduced household soiling damage;
     Alternative sensitivities of crops to ozone exposure from 
National Crop Loss Assessment Network estimates; and
     Avoided costs of reducing nitrogen loadings in three case 
study eastern estuaries and nine other eastern estuaries.
    Unfortunately, it is not possible to combine all of the assumptions 
used in the alternate calculations to arrive at different total benefit 
estimates because, it is highly unlikely that the selected combination 
of alternative values would all occur simultaneously. Therefore, it is 
better to consider each alternative calculation individually to assess 
the sensitivity of total benefits to individual assumptions. For 
instance, estimating PM-related premature mortality benefits based on 
different concentration-response functions may be an important 
uncertainty. Specifically, the Harvard Six Cities study by Dockery et 
al. (1993) of the relationship between PM concentration and premature 
mortality is a plausible alternative to the American Cancer Society 
(ACS)/Krewski et al. (2000) study used for the primary estimate of 
benefits. The SAB has noted that ``the study had better monitoring with 
less measurement error than did most other studies'' (EPA-SAB-COUNCIL-
ADV-99-012, 1999). However, the Dockery et al. study had a more limited 
geographic scope (and a smaller study population) than the ACS/Krewski 
et al. study and the ACS/Krewski et al. study appears more likely to 
mitigate a key source of potential confounding. The Dockery et al. 
study did cover a broader age category (25 and older compared to 30 and 
older in the ACS study) and followed the cohort for a longer period (15 
years compared to 8 years in the ACS study). For these reasons, the 
Dockery et al. study is considered to be a plausible alternative 
estimate of the avoided premature mortality incidences associated with 
this final rule. The alternative estimate for mortality can be 
substituted for the valuation component in our primary estimate of 
mortality benefits to observe how the net benefits of the program may 
be influenced by this assumption.
    In addition to the estimate for the primary set of endpoints and 
alternative calculations of benefits, our RIA also presents an appendix 
with supplemental benefit estimates and sensitivity analyses of other 
key parameters in the benefits analysis that have greater uncertainty 
surrounding them due to limitations in the scientific literature. The 
following sensitivity analyses include alternative income elasticities 
of willingness to pay;195 alternative discount 
rates;196 alternative PM exposure lags preceding mortality; 
threshold analysis for PM mortality;197 and other analyses.
---------------------------------------------------------------------------

    \195\ Income elasticity of WTP characterizes the relationship 
between changes in real income and changes in the WTP for a 
particular commodity. Income elasticity of WTP is measured as the 
percentage change in WTP for a one percent change in real income. 
For example, an income elasticity of 0.5 implies that a 10 percent 
increase in real income would lead to a 5 percent increase in WTP.
    \196\ The choice of a discount rate, and its associated 
conceptual basis, is a topic of ongoing discussion within the 
federal government. EPA adopted a 3 percent discount rate for its 
primary analysis in this case to reflect reliance on a ``social rate 
of time preference'' discounting concept. We have also calculated 
benefits and costs using a 7 percent rate consistent with an 
``opportunity cost of capital'' concept to reflect the time value of 
resources directed to meet regulatory requirements. In this case, 
the benefit and cost estimates were not significantly affected by 
the choice of discount rate. Further discussion of this topic 
appears in EPA's Guidelines for Preparing Economic Analyses (in 
press).
    \197\ The SAB has advised EPA that there is no current 
scientific basis for selecting a threshold for PM-related health 
effects considered in this analysis (EPA-SAB-Council-ADV-99-012, 
1999).
---------------------------------------------------------------------------

    Even with our efforts to fully disclose the uncertainty in our 
estimate, this uncertainty presentation method does not provide a 
definitive or complete picture of the true range of monetized benefits 
estimates. The set of alternative calculations is only representative 
of those benefits that we were able to quantify and monetize.
3. How Has the Benefit-Cost Analysis Changed From Proposal?
    No quantitative benefits analysis was conducted for the proposal, 
although we outlined the methodology to be used for the final rule 
analysis. We summarized and responded to public comment regarding the 
methods in the Summary and Analysis of Comment document. Moreover, we 
have improved the methods that were presented at proposal. For the 
benefits assessment for the final rule, EPA updated the C-R functions 
for health endpoints (e.g., Krewski et al., 2000), updated the 
emissions inventory, and presented air quality information regarding 
urban and residential visibility. For the air quality inputs to the 
benefits analysis, we used the REMSAD model which offers improved 
chemistry, resolution, and other capabilities over the Source-Receptor 
Matrix discussed in the proposal. The model's performance, including 
uncertainties, are discussed elsewhere in the RIA and technical support 
documents. In addition, we also updated our presentations of monetary 
benefits of the reduced premature mortality based on advice from the 
SAB.198 All of the changes made since the proposal serve to 
improve the analysis.
---------------------------------------------------------------------------

    \198\ Full documentation of the SAB advice can be found at their 
website (www.epa.gov/sab) or in the docket under the following 
reference: EPA-SAB-EEAC-00-013, July 27, 2000. An SAB Report on 
EPA's White Paper Valuing the Benefits of Fatal Cancer Risk 
Reduction.
---------------------------------------------------------------------------

4. What Are the Benefits in the Years Leading up to 2030?
    The HD Engine/Diesel Fuel program has various cost and emission 
related components, as described earlier in this section. These 
components would begin at various times and in some cases would phase 
in over time. This means that during the early years of the program 
there would not be a consistent match between cost and benefits. This 
is especially true for the vehicle control portions of the program, 
where the full vehicle cost would be incurred at the time of vehicle 
purchase, while the fuel cost along with the emission reductions and 
benefits resulting from all these costs would occur throughout the 
lifetime of the vehicle. Because of this

[[Page 5105]]

inconsistency and our desire to more appropriately match the costs and 
emission reductions of our program, our analysis uses a future year 
when the fleet is nearly fully turned over (2030).
    In the years before 2030, the benefits from the HD Engine/Diesel 
Fuel program will be less than those estimated here, because the 
compliant heavy-duty fleet will not be fully phased in. Annualized 
costs, on the other hand, reach nearly their full value within a few 
years of program initiation (once all phase-ins are completed). This 
can be seen by comparing the anticipated emission reductions described 
earlier in section II.D with the aggregate costs of section V.E. Thus, 
a benefit-cost ratio computed for the earlier years of the program 
would be expected to be lower than a ratio based on our 2030 analysis. 
On the other hand, since the estimated benefits are more than ten times 
the costs in 2030, the emission reduction and cost trends suggest that 
it is likely that annual benefits would exceed costs from a time early 
in the life of the program.199
---------------------------------------------------------------------------

    \199\ While emission reduction trends give a general indication 
of the likely trends in the benefits, there are sufficient non-
linearities and interactions among pollutants in the atmospheric 
chemistry used in our modeling that it is not possible to attempt a 
quantitative estimate of the benefits simply from changes in the 
inventories in years that were not fully modeled.
---------------------------------------------------------------------------

    Furthermore, to the extent that a lower ratio of benefits to costs 
early in the program is the result of the mismatch of costs and 
benefits in time, a simple analysis of an individual year would be 
misleading. A more appropriate means of capturing the impacts of timing 
differences in benefits and costs would be to produce a net present 
value comparison of the costs and benefits over some period of years 
(an approach analogous to the aggregate cost effectiveness presented in 
section V.F). Unfortunately, while this is relatively straight-forward 
for the costs, it is currently not feasible to do a multi-year analysis 
of the benefits as this would require a significant amount of air 
quality modeling to capture each year.
5. What Were the Results of the Benefit-Cost Analysis?
    The benefit-cost analysis for the HD Engine/Diesel Fuel program 
reflects a single year ``snapshot'' of the yearly benefits and costs 
expected to be realized once the standards have been fully implemented 
and non-compliant vehicles have all been retired. As discussed in 
section V.F-4, the benefit-cost ratio would be expected to be lower 
than the results calculated here in the early years of the program.
    Table V.F-1 presents EPA's primary estimate of the benefits of the 
rule, both the estimated reductions in incidences and the estimated 
economic value of those incidence reductions. In interpreting the 
results, it is important to keep in mind the limited set of effects we 
are able to monetize. Specifically, the table lists the avoided 
incidences of individual health and environmental effects, the 
pollutant associated with each of these endpoints, and the estimated 
economic value of those avoided incidences. For several environmental 
effects such as visibility, the concept of incidences or cases does not 
apply as it does for health effects; thus, for these categories 
economic values are applied directly to air quality conditions. As the 
table indicates, we estimate that the HD Engine/Diesel Fuel program 
will produce about 5,500 fewer cases of chronic bronchitis, and we also 
see significant improvements in minor restricted activity days (with an 
estimated 9,838,500 fewer cases). Our estimate also incorporates 
significant reductions in impacts on children's health, showing 
reductions of 17,600 cases of acute bronchitis, 192,900 fewer cases of 
lower respiratory symptoms, and 193,400 fewer cases of upper 
respiratory symptoms in asthmatic children each year. In addition, 
today's rule is estimated to reduce 361,400 incidents of asthma attacks 
each year in asthmatics of all ages from reduced exposure to ozone and 
particles. Asthma is the most prevalent chronic disease among children 
and currently affects over seven percent of children under 18 years of 
age.
    Total monetized benefits, however, are driven primarily by the 
estimated 8,300 fewer premature fatalities each year, which account for 
almost 89 percent of total benefits. We assume for this analysis that 
some of the incidences of premature mortality related to PM exposures 
occur in a distributed fashion over the five years following exposure. 
To take this into account in the valuation of reductions in premature 
mortality, we apply an annual three percent discount rate to the value 
of premature mortality occurring in years after our analysis year.

 Table V.F-1.--EPA Primary Estimate of the Annual Quantified and Monetized Benefits Associated With Improved Air
                         Quality Resulting From the HD Engine/Diesel Fuel Rule in 2030 A
----------------------------------------------------------------------------------------------------------------
                                                                           Avoided incidence  Monetary  benefits
                  Endpoint                            Pollutant            A C  (cases/year)    A D  (millions
                                                                                                    1999$)
----------------------------------------------------------------------------------------------------------------
Premature mortality B (adults, ages 30 and   PM B.......................               8,300             $62,580
 over).
Chronic bronchitis.........................  PM.........................               5,500              $2,430
Hospital Admissions from Respiratory Causes  Ozone and PM...............               4,100                 $60
Hospital Admissions from Cardiovascular      Ozone and PM...............               3,000                 $50
 Causes.
Emergency Room Visits for Asthma...........  Ozone and PM...............               2,400                  $5
Acute bronchitis (children, ages 8-12).....  PM.........................              17,600                  $5
Upper respiratory symptoms (asthmatic        PM.........................             193,400                 $10
 children, ages 9-11).
Lower respiratory symptoms (children, ages   PM.........................             192,900                  $5
 7-14).
Asthma attacks (asthmatics, all ages) E....  Ozone and PM...............             361,400                  Ba
Work loss days (adults, ages 18-65)........  PM.........................           1,539,400                $160
Minor restricted activity days (adults,      Ozone and PM...............           9,838,500                $530
 ages 18-65).
(adjusted to exclude asthma attacks).......
Other health effects E.....................  Ozone, PM, CO, NMHC........         U1+U2+U3+U4         B1+B2+B3+B4
Decreased worker productivity..............  Ozone......................  ..................                $140
Recreational visibility (86 Class I Areas).  PM.........................  ..................              $3,260
Residential visibility.....................  PM.........................  ..................                  B5
Household soiling damage...................  PM.........................  ..................                  B6
Materials damage...........................  PM.........................  ..................                  B7
Nitrogen Deposition to Estuaries...........  Nitrogen...................  ..................                  B8
Premature mortality B (adults, ages 30 and   PM B.......................               8,300             $62,580
 over).

[[Page 5106]]

 
Chronic bronchitis.........................  PM.........................               5,500              $2,430
Hospital Admissions from Respiratory Causes  Ozone and PM...............               4,100                 $60
Hospital Admissions from Cardiovascular      Ozone and PM...............               3,000                 $50
 Causes.
Emergency Room Visits for Asthma...........  Ozone and PM...............               2,400                  $5
Acute bronchitis (children, ages 8-12).....  PM.........................              17,600                  $5
Upper respiratory symptoms (asthmatic        PM.........................             193,400                 $10
 children, ages 9-11).
Lower respiratory symptoms (children, ages   PM.........................             192,900                  $5
 7-14).
Asthma attacks (asthmatics, all ages) E....  Ozone and PM...............             361,400                  Ba
Work loss days (adults, ages 18-65)........  PM.........................           1,539,400                $160
Minor restricted activity days (adults,      Ozone and PM...............           9,838,500                $530
 ages 18-65).
(adjusted to exclude asthma attacks).......  ...........................  ..................  ..................
Other health effects E.....................  Ozone and PM...............         U1+U2+U3+U4         B1+B2+B3+B4
                                             CO, NMHC...................  ..................  ..................
Decreased worker productivity..............  Ozone......................  ..................                $140
Agricultural crop damage (6 crops).........  Ozone......................  ..................              $1,120
Commercial forest damage, (6 species in      Ozone......................  ..................                  B9
 Eastern US).
Commercial forest damage, other............  Ozone......................  ..................                 B10
Other welfare effects E....................  Ozone, PM..................  ..................    B11+B12+B 13+B14
                                             CO, NMHC...................  ..................  ..................
                                            --------------------------------------------------------------------
    Monetized Total F......................  ...........................  ..................          $70,360+B
----------------------------------------------------------------------------------------------------------------
Notes:
A Ozone-related benefits are only calculated for the Eastern US due to unavailability of reliable modeled ozone
  concentrations in the Western US, thus underestimating national ozone-related benefits. See RIA and technical
  support documents for details.
B Premature mortality associated with ozone is not separately included in this analysis. It is assumed that the
  ACS/Krewski, et al. (2000) C-R function for premature mortality captures both PM mortality benefits and any
  mortality benefits associated with other air pollutants. Also note that the valuation assumes the 5 year
  distributed lag structure described earlier and a 3 percent discount rate over that lag period.
C Incidences are rounded to the nearest 100.
D Dollar values are rounded to the nearest 10 million. Monetary benefits account for growth in real GDP per
  capita between 1990 and 2030.
E The Ui are the incidences and the Bi are the values for the unquantified category i. For some categories such
  as asthma attacks, we were able to quantify the reduction in incidence, but we present the monetization as an
  alternative calculation. A detailed listing of unquantified PM, ozone, CO, and NMHC related health and welfare
  effects is provided in Table V.F-2. NMHC shown here are also hazardous air pollutants listed in the Clean Air
  Act.
F B is equal to the sum of all unmonetized categories, i.e. Ba+B1+B2+...+Bn.

    This table also indicates with a ``B'' those additional health and 
environmental benefits which could not be expressed in quantitative 
incidence and/or economic value terms. A full listing of the benefit 
categories that could not be quantified or monetized in our estimate 
are provided in Table V.F-2. For instance, visibility is expected to 
improve in all areas of the country, with the largest improvements 
occurring in heavily populated residential areas (e.g., half of the 
urban areas show an improvement of 0.5 deciviews or more). However, due 
to limitations on sources to value these effects, we include a ``B'' in 
the primary estimate table for this category. Likewise, the HD Engine/
Diesel Fuel rule will also provide progress for some estuaries to meet 
their goals for reducing nitrogen deposition (e.g., nitrogen loadings 
for the Albemarle/Pamlico Sound are reduced by 24 percent of their 
reductions goal), however, this endpoint is also displayed with a ``B'' 
in the table. A full appreciation of the overall economic consequences 
of the HD Engine/Diesel Fuel standards requires consideration of all 
benefits and costs expected to result from the new standards, not just 
those benefits and costs which could be expressed here in dollar terms.
    In summary, EPA's primary estimate of the benefits of the HD 
Engine/Diesel Fuel rule is $70.4 billion in 2030. This estimate 
accounts for growth in real gross domestic product (GDP) per capita 
between 1990 and 2030.

             Table V.F-2.--Additional, Non-monetized Benefits of the HD Engine/Diesel Fuel Standards
----------------------------------------------------------------------------------------------------------------
                      Pollutant                                          Unquantified effects
----------------------------------------------------------------------------------------------------------------
Ozone Health........................................  Premature mortality; A Increased airway responsiveness to
                                                       stimuli; Inflammation in the lung; Chronic respiratory
                                                       damage; Premature aging of the lungs; Acute inflammation
                                                       and respiratory cell damage; Increased susceptibility to
                                                       respiratory infection; and Non-asthma respiratory
                                                       emergency room visits.
Ozone Welfare.......................................  Decreased yields for commercial forests; Decreased yields
                                                       for fruits and vegetables; Decreased yields for non-
                                                       commercial crops; Damage to urban ornamental plants;
                                                       Impacts on recreational demand from damaged forest
                                                       aesthetics; and Damage to ecosystem functions.
PM Health...........................................  Infant mortality; Low birth weight; Changes in pulmonary
                                                       function; Chronic respiratory diseases other than chronic
                                                       bronchitis; and Morphological changes.
PM Welfare..........................................  Visibility in non-class I areas; Soiling and materials
                                                       damage; and Damage to ecosystem functions.
Nitrogen and Sulfate Deposition Welfare.............  Impacts of acidic sulfate and nitrate deposition on
                                                       commercial forests; Impacts of acidic deposition to
                                                       commercial freshwater fishing; Impacts of acidic
                                                       deposition to recreation in terrestrial ecosystems;
                                                       Reduced existence values for currently healthy
                                                       ecosystems; Impacts of nitrogen deposition on commercial
                                                       fishing, agriculture, and forests; Impacts of nitrogen
                                                       deposition on recreation in estuarine ecosystems; and
                                                       Damage to ecosystem functions.

[[Page 5107]]

 
CO Health...........................................  Premature mortality; A Behavioral effects; Hospital
                                                       admissions--respiratory, cardiovascular, and other; Other
                                                       cardiovascular effects; Developmental effects; Decreased
                                                       time to onset of angina; and Non-asthma respiratory ER
                                                       visits.
NMHC Health.........................................  Cancer (benzene, 1,3-butadiene, formaldehyde,
                                                       acetaldehyde); B Anemia (benzene); Disruption of
                                                       production of blood components (benzene); Reduction in
                                                       the number of blood platelets (benzene); Excessive bone
                                                       marrow formation (benzene); Depression of lymphocyte
                                                       counts (benzene); Reproductive and developmental effects
                                                       (1,3-butadiene); Irritation of eyes and mucus membranes
                                                       (formaldehyde); Respiratory irritation (formaldehyde);
                                                       Asthma attacks in asthmatics (formaldehyde); Asthma-like
                                                       symptoms in non-asthmatics (formaldehyde); Irritation of
                                                       the eyes, skin, and respiratory tract (acetaldehyde); and
                                                       Upper respiratory tract irritation and congestion
                                                       (acrolein).
NMHC Welfare........................................  Direct toxic effects to animals; Bioaccumlation in the
                                                       food chain; and Damage to ecosystem function.
----------------------------------------------------------------------------------------------------------------
A Premature mortality associated with ozone and carbon monoxide is not separately included in this analysis. In
  this analysis, we assume that the ACS/Krewski, et al. C-R function for premature mortality captures both PM
  mortality benefits and any mortality benefits associated with other air pollutants.
B Non-methane hydrocarbons related to this rule are also hazardous air pollutants listed in the Clean Air Act.

    In addition, in analyzing the present rule, we recognized that the 
benefits estimates were subject to a number of uncertainties with other 
parameters. In Table V.F-3 we present key alternatives to assumptions 
regarding individual elements of the benefits analysis and their effect 
on the primary estimate of benefits. This table also displays some 
assumptions that can be made to value some of the categories that are 
indicated with a ``B'' in the primary estimate. For example, this table 
can be used to answer questions like, ``What would total benefits be if 
we were to use the ACS/Krewski, et al. regionally adjusted 
PM2.5 C-R function to estimate avoided premature 
mortality?'' This table is not meant to be comprehensive but to 
identify the impact of key issues identified by EPA or in public 
comment as affecting the total benefits estimation.

         Table V.F--3. Key Alternative Benefits Calculations for the HD Engine/Diesel Fuel Rule in 2030A
----------------------------------------------------------------------------------------------------------------
                                                                                           Impact on primary
                                                                                           benefits estimate
               Description of alternative                                   Avoided      adjusted for growth in
                                                                           incidences    real income  (million
                                                                                                 1999$)
----------------------------------------------------------------------------------------------------------------
                 Alternative Concentration-Response Functions for PM-related Premature Mortality
----------------------------------------------------------------------------------------------------------------
1. Krewski/ACS Study Regional Adjustment Model B........  ..............        9,400           +$7,370 (+10.5%)
2. Pope/ACS Study C.....................................  ..............        9,900           +12,780 (+18.2%)
3. Krewski/Harvard Six-city Study D.....................  ..............       24,200        +$118,500 (+168.4%)
----------------------------------------------------------------------------------------------------------------
           Alternative Methods for Valuing Reductions in Incidences of PM-related Premature Mortality
----------------------------------------------------------------------------------------------------------------
Value of avoided premature mortality incidences based on      Jones-Lee         8,300          -$28,510 (-40.5%)
 age-specific VSL.......................................       (1989) E
                                                              Jones-Lee         8,300          -$6,820 (-10.0%)
                                                               (1993) F
----------------------------------------------------------------------------------------------------------------
A Section VII-.F of the RIA provides complete information about the estimates in this table.
B This C-R function is included as a reasonable specification to explore the impact of adjustments for broad
  regional correlations, which have been identified as important factors in correctly specifying the PM
  mortality C-R function.
C The Pope et al. C-R function was used to estimate reductions in premature mortality for the Tier 2/Gasoline
  Sulfur benefits analysis. It is included here to provide a comparable estimate for the HD Engine/Diesel Fuel
  rule.
D The Krewski et al. ``Harvard Six-cities Study'' estimate is included because the Harvard Six-cities Study
  featured improved exposure estimates, a slightly broader study population (adults aged 25 and older), and a
  follow-up period nearly twice as long as that of Pope, et al. and as such provides a reasonable alternative to
  the primary estimate.
E Jones-Lee (1989) provides an estimate of age-adjusted VSL based on a finding that older people place a much
  lower value on mortality risk reductions than middle-age or younger people.
F Jones-Lee (1993) provides an estimate of age-adjusted VSL based on a finding that older people value mortality
  risk reductions only somewhat less than middle-aged or younger people.

    The estimated annualized 2030 cost for businesses to implement the 
final HD Engine/Diesel Fuel program from Table V.D-1 of the RIA is $4.3 
billion (1999$). When considered in a broader social cost context of 
the cost to society of the resources used, which is the right metric 
for cost-benefit analysis, the annualized cost is $4.2 billion. The 
monetized benefits are approximately $70.4 billion and EPA believes 
there is considerable value to the public of the benefits it could not 
monetize. The net benefit that can be monetized is $66.2 billion. 
Therefore, implementation of the HD Engine/Diesel Fuel program is 
expected to provide society with a net gain in social welfare based on 
economic efficiency criteria. Tables V.F-4 summarizes the costs, 
benefits, and net benefits.

[[Page 5108]]



  Table V.F-4.--2030 Annual Monetized Costs, Benefits, and Net Benefits
               for the Final HD Engine/Diesel Fuel Rule a
------------------------------------------------------------------------
                                                       Billions of 1999$
------------------------------------------------------------------------
Annual compliance costs.............................               $4.2
    Monetized PM-related benefits b.................        $69.0 + BPM
    Monetized Ozone-related benefitsb, c............     $1.4 + B Ozone
    NMHC-related benefits...........................      not monetized
                                                                  (BNMHC)
    CO-related benefits.............................      not monetized
                                                                     (BCO)
Total annual benefits...............................     $70.4 +BPM + B
                                                           Ozone + BNMHC +
                                                                      BCO
Monetized net benefitsd.............................         $66.2 + B
------------------------------------------------------------------------
\a\ For this section, all costs and benefits are rounded to the nearest
  100 million. Thus, figures presented in this chapter may not exactly
  equal benefit and cost numbers presented in earlier sections of the
  chapter.
\b\ Not all possible benefits or disbenefits are quantified and
  monetized in this analysis. Potential benefit categories that have not
  been quantified and monetized are listed in Table VII-1. Unmonetized
  PM- and ozone-related benefits are indicated by BPM and BOzone,
  respectively.
\c\ Ozone-related benefits are only calculated for the Eastern U.S. due
  to unavailability of reliable modeled ozone concentrations in the
  Western U.S. This results in an underestimate of national ozone-
  related benefits. See US EPA (2000a) for a detailed discussion of the
  UAM-V ozone model and model performance issues.
\d\ B is equal to the sum of all unmonetized benefits, including those
  associated with PM, ozone, CO, and NMHC.

VI. Requirements for Engine and Vehicle Manufacturers

A. Compliance with Standards and Enforcement

    We are making some changes to the compliance-related requirements 
that will apply to vehicles and engines certified to the new standards. 
These changes are described below. Changes related to the supplemental 
emission requirements are discussed in Section III.C, along with the 
discussion of revised standards for those requirements. In general, 
however, existing compliance provisions will continue to apply to the 
vehicles and engines subject to today's standards.
1. Allowable Maintenance
    Our existing regulations contain provisions (40 CFR Sec. 86.004-25) 
that would affect scheduled maintenance of NOX adsorbers, PM 
traps, and other devices that may be used to comply with the new 
standards. These provisions limit the amount of maintenance to 
emission-related components that the manufacturer is allowed to conduct 
during durability testing (or specify in the maintenance instructions 
that it gives to operators). We believe that the continuation of these 
requirements is appropriate because we expect that, with very low fuel 
sulfur levels, these technologies will be very durable in use and will 
last the full useful life with little or no scheduled maintenance other 
than cleaning. However, we are modifying these provisions slightly. The 
existing regulations would have allowed a manufacturer to specify 
something as drastic as replacement of the adsorber catalyst bed or the 
trap filter after as little as 100,000-150,000 miles if there was a 
``reasonable likelihood'' that the maintenance would get done. To 
ensure that no manufacturer underdesigns their adsorbers or traps 
(compared to the level of durability that is achievable), we are 
requiring that these technologies be designed to last for the full 
useful life of the engine. More specifically, the final regulations 
state that scheduled replacement of the PM filter element, 
NOX adsorber, or other catalyst module bed is not allowed 
during the useful life, unless the manufacturer can show that the 
replacement will in fact occur and pays for the replacement. Otherwise, 
only cleaning and adjustment will be allowed as scheduled maintenance. 
It is important to note that this restriction only applies to the 
manufacturer's specified maintenance. Owners and operators are, of 
course, allowed to perform additional maintenance.
2. Emission Data Waivers
    Today's action includes PM standards for all heavy-duty engines. 
However, because gasoline engines have inherently low PM emissions, it 
will be appropriate in some cases to waive the requirement to measure 
PM emissions for certification. Therefore, the final regulations give 
us the flexibility to allow manufacturers to certify gasoline engines 
and vehicles without measuring PM emissions, provided they can 
demonstrate compliance in some other way such as with previous data, 
analyses, or other information. The flexibility is the same as that 
allowed for PM emissions from light-duty gasoline vehicles and for CO 
emissions from heavy-duty diesel engines. We are also allowing the same 
type of analysis to be used with respect to formaldehyde emissions from 
all petroleum-fueled heavy-duty vehicles.
3. Crankcase Emissions
    Section III describes a new requirement for manufacturers to 
control crankcase emissions from turbocharged diesel engines. 
Historically, control of crankcase emissions has meant sealing the 
crankcase and routing the crankcase gases into the air intake system so 
they can be combusted. However, some manufacturers have expressed a 
reasonable concern that this would be unnecessarily restrictive, and 
suggested that we should allow for alternative controls. Therefore, we 
are making some revisions from the proposed regulations. First, we are 
clarifying that this closed crankcase provision does not require that 
crankcase gases be routed into the engine intake. We will also allow 
manufacturers to route crankcase gases into the exhaust system, 
including upstream of the exhaust emission controls. Furthermore, we 
are also changing the regulations to allow manufacturers to instead 
measure crankcase emissions and add them to the measured exhaust 
emissions (or to measure them together). Manufacturers choosing to use 
this allowance rather than to seal the crankcase will need to modify 
their exhaust deterioration factors or to develop separate 
deterioration factors to account for increases in crankcase emissions 
as the engine ages. Manufacturers would also be responsible for 
ensuring that crankcase emissions would be readily measurable in use.

[[Page 5109]]

4. Non-Conformance Penalties
    We are not establishing non-conformance penalties (NCPs) for the 
new standards at this time. NCPs are monetary penalties that 
manufacturers can pay instead of complying with an emission standard. 
In order for us to establish NCPs for a specific standard, we would 
have to find that: (1) Substantial work will be required to meet the 
standard for which the NCP is offered; and (2) there is likely to be a 
``technological laggard'' (i.e., a manufacturer that cannot meet the 
standard because of technological (not economic) difficulties and, 
without NCPs, might be forced from the marketplace). According to the 
CAA (Section 206(g)), such NCPs ``shall remove any competitive 
disadvantage to manufacturers whose engines or vehicles achieve the 
required degree of emission reduction.'' We also must determine 
compliance costs so that appropriate penalties can be established. 
While we have established NCPs in past rulemakings, their use has been 
rare since the implementation of our averaging, banking and trading 
program.
    We requested comment on the need for NCPs in this rulemaking. 
However, after reviewing the comments, we cannot conclude that NCPs 
will be needed. While we believe that substantial work will be required 
to meet the 2007 standards, we currently have no information indicating 
that a technological laggard is likely to exist. Recognizing that it 
may have been difficult for manufacturers to comment on these criteria 
at this early stage of development, when implementation of these 
standards is still more than six years away, it may be appropriate to 
reconsider NCPs in a future action.
5. Idle CO Standards
    We are also eliminating the idle CO emission standards for heavy-
duty vehicles and engines below 14,000 pounds beginning in the 2004 
model year, provided they are certified to the OBD requirements of our 
Phase 1 rule. (See 65 FR 59896, October 6, 2000.) The certified OBD 
systems on those vehicles will likely serve as the basis for future 
inspection and maintenance tests in areas testing vehicles in that 
weight class. Certification data show that heavy-duty engines and 
vehicles are certifying with idle CO levels well below the standard. We 
believe that the existing standard is not the forcing function for 
these low idle CO levels, but instead it is the electronic computer-
controlled engines of today. In effect, we believe that the idle CO 
standard places an unnecessary testing burden on manufacturers whose 
vehicles are certified to the OBD requirements. We also eliminated the 
idle CO standard for light-duty trucks in our Tier 2 rule. (See 65 FR 
6698, February 10, 2000.) Note that we are considering a future rule 
that would implement OBD on engines over 14,000 pounds. We would 
consider eliminating the idle CO requirement for those engines in the 
event that OBD requirements are put into place.

B. Compliance With Phase-in Schedules

    In Section III we described the phase-in options for diesel engine 
manufacturers. These options are based on percentages of a 
manufacturer's production. We recognize, however, that manufacturers 
need to plan for compliance well in advance of the start of production, 
and that actual production volumes for any one model year may differ 
from their projections. This is a bigger concern for the diesel engines 
than for gasoline engines because of the three-year phase-in of the new 
diesel NOX standards. On the other hand, we believe that it 
would be inappropriate to base compliance solely on a manufacturer's 
projections. That could encourage manufacturers to overestimate their 
production of the low-emission engines, and could result in 
significantly lower emission benefits during the phase-in. Given these 
conflicting factors, we are finalizing a compromise approach. We will 
initially only require diesel manufacturers to project compliance with 
the phase-in based on their projected production volumes, provided that 
they made up any deficits (in terms of percent of production) the 
following year. Thus, a manufacturer that projected 50 percent of its 
production in 2007 would be low-NOX (i.e., meet the 0.20 g/
bhp-hr NOX standard), but that was only able to actually 
produce 45 percent of its production as low-NOX, could 
achieve compliance by producing at least 55 percent of its production 
as low-NOX in 2008. However,since production volumes differ 
from year to year, deficits would be calculated and made up based on 
numbers of engines or vehicles, rather than percent of production. This 
is similar to the approach that we used in phasing-in the Tier 2 
emission standards.
    Since we expect that a manufacturer making a good-faith projection 
of sales would not be very far off of the actual production volumes, we 
are limiting the size of the deficit that could be excused. In all 
cases, the manufacturer will be required to produce at least 25 percent 
of its production as low-NOX engines in model years 2007, 
2008, and 2009. Another important restriction is that manufacturers 
will not be allowed to have a deficit in the third year of the phase-in 
(2009). This restriction is being finalized to ensure that 
manufacturers are able to make up the deficit. Since they could not 
produce more than 100 percent low-NOX engines in 2010, it 
would not be possible to make up a deficit from 2009.

C. Averaging, Banking, and Trading

    We are continuing the basic structure of the existing ABT program 
for heavy-duty engines. This program allows manufacturers to certify 
their engine families at various specified emissions levels above or 
below the standard, as long as they comply with the applicable 
standards when averaged across their various engine families. More 
specifically, manufacturers are allowed to certify their engine 
families with various family emission limits (FELs), provided that in 
each model year the average of the FELs does not exceed the standard 
when weighted by the numbers of engines produced in each family for 
that model year. To do this, they generate certification emission 
credits by producing engine families that are certified below the 
applicable standard. These credits can then be used to offset the 
production of engine families that are certified to have emissions in 
excess of the applicable standards. Manufacturers are also allowed to 
bank these credits for later use or trade them to other manufacturers. 
We are adopting some restrictions to ensure that the environmental 
benefits of the program are not jeopardized as described in the 
Response to Comments document. These restrictions are described below 
along with other changes made in response to comments. We are 
continuing this ABT program because we believe that it will provide the 
manufacturers significant compliance flexibility. This compliance 
flexibility could be a significant factor in the manufacturers' ability 
to comply with the standards in 2007 and will help to allow 
implementation of the new, more stringent standards as soon as 
permissible under the CAA.
    We proposed two separate averaging sets during the diesel phase-in 
period. In one set, engines would be certified to the 2.4 g/bhp-hr 
NOX+NMHC standard (which applies for model years 2004-2006), 
and would be subject to the restrictions and allowances established for 
those model years. In the other set, engines would be certified to the 
0.20 g/bhp-hr NOX standard, and would be subject to the 
restrictions and allowances in the proposed program.

[[Page 5110]]

While we proposed to not allow averaging between these two sets, based 
on the comments we received, the final regulations allow manufacturers 
to transfer credits across these averaging sets, with some 
restrictions. Manufacturers could use credits generated during the 
phase-out of engines subject to the 2.4 g/bhp-hr NOX+NMHC 
standard to comply with the 0.20 g/bhp-hr NOX standard, but 
these credits will be subject to a 20 percent discount. (Each gram of 
NOX+NMHC credits from the phase-out engines would be worth 
0.8 grams of NOX credits in the new ABT program.) This 
discount reflects the fact that the change from our proposed ABT 
program provides manufacturers with substantial flexibility in meeting 
the final standards and also accounts for the NMHC component of the 
credit. In the first year of the phase-in, this flexibility will allow 
manufacturers to reduce fleetwide emissions more than would have been 
possible with the proposed program. Manufacturers will be able to 
reduce emissions for a substantial percentage of their production, 
reflecting the use of low-NOX technologies, without being 
required to produce a full 50 percent of their production with 
NOX emissions near or below 0.20 g/bhp-hr in the initial 
year of the phase-in. This generation and use of credits will give 
manufacturers a greater opportunity to gain experience with the low-
NOX technologies before they are required to meet the final 
standards across their full production. As part of the averaging 
program during the phase-in period (model years 2007-2009), we will 
allow diesel engine credits to be averaged across service class using a 
modified form of the ABT program. These credit exchanges would occur in 
the same manner as other credit exchanges, except that the credits 
generated from one service class would need to be calculated using the 
useful life and horsepower values of the engine family using credits. 
This would make the credit exchanges equivalent to the vehicle count 
phase-in provisions. This allowance is restricted to averaging. Banked 
or traded credits cannot be used across service class.
    We are also adopting a restriction on the use of banked 
NOX+NMHC credits generated from diesel engines certified to 
the 2.4 g/bhp-hr NOX+NMHC standard. While we proposed to 
prohibit any such use, the final regulations will allow manufacturers 
to use banked credits to show compliance with the 0.20 g/bhp-hr 
standard, but the credits will be discounted by 20 percent when they 
are used for this purpose.200 This is consistent with the 
cross-averaging set discount described above. In addition, we are 
setting an upper bound on the number of engines for which a 
manufacturer could use such banked credits during any one model year. 
The upper limit is ten percent of the manufacturer's annual U.S.-
directed production of heavy-duty highway diesel engines, and would 
apply only for engines certified to FELs higher than 0.50 g/bhp-hr. We 
believe that this limit is necessary to prevent manufacturers from 
delaying the introduction of the low-NOX technologies by 
using a large number of banked credits. This kind of delay would be 
contrary to the goals of the phase-in, which in large part is intended 
for manufacturers to gain some initial experience with the low-
NOX technologies for a limited portion of their production. 
Although it does not appear likely (based on manufacturer expectations) 
that such credits will exist in large numbers, this limit appears 
prudent to ensure that such a problem does not occur.
---------------------------------------------------------------------------

    \200\ It should be noted that the existing regulations already 
contain provisions that would discount diesel NOX+NMHC 
credits in some cases when they are banked or traded. The reason for 
this discount is an interest in encouraging engine designs that are 
significantly cleaner than the 2.4 g/bhp-hr standard while that 
standard is in effect. There are also similar provisions for 
gasoline engines and vehicles. While the new regulations do not 
change these existing provisions, they do account for the previous 
discount by capping the total discount at 20 percent.
---------------------------------------------------------------------------

    We are making similar changes to the ABT programs for heavy-duty 
gasoline engines and vehicles. We will allow exchange of credits from 
the chassis-certified vehicles to engines (and vice versa) on a credit 
for credit face-value basis, subject to a 20 percent 
discount.201 The discount is necessary to account for the 
uncertainty in converting between g/mi standards and g/bhp-hr 
standards. We will also allow NOX+NMHC credits from gasoline 
engines certified to the combined standards (including banked credits) 
to be used in the new NOX-only ABT program, also subject to 
the 20 percent discount, for reasons discussed above and in the 
Response to Comments document. This discount would not apply for banked 
or averaged gasoline vehicle credits used within the vehicle ABT 
program, since the existing program is already a NOX-only 
program. In connection to this option, we believe that it would be 
appropriate to allow gasoline engine manufacturers to voluntarily 
participate in an NMHC ABT program, instead of forcing them to convert 
their NOX+NMHC credits into NOX credits when the 
new standards take effect. While we believe that manufacturers will 
generally prefer to use these credits as NOX credits, NMHC 
credits may be of some value to manufacturers since gasoline engine 
emission controls often have a NOX-NMHC emission tradeoff 
much like the NOX-PM tradeoff for diesel engines. Therefore, 
we are extending the ABT programs for gasoline engines and vehicles to 
include NMHC, beginning with the 2007 model year. These NOX 
and NMHC ABT programs parallel the NOX and PM ABT programs 
for diesels. In the NMHC ABT programs, the NMHC credits would be 
subject to the same allowances, restrictions, and discounts as the 
NOX credits. In addition, we are adopting a provision to 
allow vehicle manufacturers to bank NMHC credits before 2008 for 
complete vehicles that are certified to the 2008 standards early. 
(Engine manufacturers are already allowed to bank NOX+NMHC 
credits for model year 2004 and later engines.)
---------------------------------------------------------------------------

    \201\ See preceding footnote.
---------------------------------------------------------------------------

    It is worth noting three other aspects of this new banking program. 
First we recognize that NOX+NMHC credits are not the same as 
NOX-only credits. However, both NMHC reductions and 
NOX reductions have environmental value, although they are 
not necessarily equivalent. Thus, given the 20 percent discount that 
would be applied to the NOX+NMHC credits if they are 
transferred into the new NOX ABT program, we believe that it 
is appropriate to allow those credits to be used in the new 
NOX program. This is especially true for diesels, which are 
expected to have low NMHC levels for model years 2004-2006 (probably 
about one-tenth of the expected NOX levels). Second, the 
final program does not include the proposed provisions for banking 
undiscounted credits by meeting all of the new diesel standards early, 
because we believe that the early compliance option described in 
Section III would accomplish essentially the same flexibility. Finally, 
we are not finalizing any new discounts or restrictions for banked PM 
credits. Considering the simple 100 percent phase-in of the PM 
standards in 2007, we believe that such restrictions are not necessary 
to achieve the goals of this program for PM, especially given the 0.02 
g/bhp-hr PM FEL cap, which is described below.
    The existing ABT program includes limits on how high the emissions 
from credit-using engines can be. These limits are referred to as FEL 
caps. No engine family may be certified above these caps using credits. 
These limits provide the manufacturers compliance flexibility while 
protecting against the

[[Page 5111]]

introduction of unnecessarily high-emitting engines. In the past, we 
have generally set the FEL caps at the emission levels allowed by the 
previous standard, unless there was some specific reason to do 
otherwise. However, we proposed much lower FEL caps, because the 
proposed standard levels were so much lower than the previous levels 
and because we wanted to ensure that manufacturers did not continue to 
produce old-technology high-emitting engines under the new program. In 
today's FRM, for model year 2007 and later diesel engines, we are 
adopting a more flexible cap for NOX emissions during the 
first three years of the program than was proposed, but are adopting 
the proposed FEL cap for PM emissions. We believe that this approach 
for NOX is more consistent with the rest of the ABT program 
(as is described above) than applying the proposed FEL cap during this 
interim period. Specifically, model year 2007 through 2009 diesel 
engines subject to the 0.20 g/bhp-hr standard will not be allowed to 
have NOX emissions higher than 2.0 g/bhp-hr, or PM emissions 
higher than 0.02 g/bhp-hr. The NOX level represents a 
conservative estimate of the emission level that is expected under the 
combined NOX+NMHC standards that will apply beginning in 
model year 2004. The proposed NOX FEL cap of 0.50 g/bhp-hr 
would not apply until model year 2010. We believe that the higher FEL 
cap is appropriate during the transition to the much lower standards, 
to allow some meaningful use of averaging. However, since the 2.0 g/
bhp-hr cap is ten times the level of the new standard, it would not be 
appropriate as a long-term cap.
    The PM cap is also lower than the previous standard of 0.10 g/bhp-
hr. As noted above, this is being done in connection with the absence 
of the kind of restrictions on the use of PM credits that are being set 
for NOX credits. The NOX credits restrictions are 
designed to better coordinate the NOX ABT program with the 
NOX standard phase-in; and the PM standard is not phased-in. 
Without those types of restrictions, we believe that it is appropriate 
to adopt the proposed lower FEL cap to prevent the possibility of PM 
credits being used to delay the implementation of the program and its 
benefits.
    The FEL caps for gasoline vehicles and engines are being set at the 
previous standards, and the approximate NOX and NMHC levels 
inherent in the NOX+NMHC standards that will apply for model 
year 2004-2007 engines. Since engine manufacturers will have the option 
of certifying their engines to a 1.5 g/bhp-hr NOX+NMHC 
standard for model years 2004-2007 (instead of the 2005 standard of 1.0 
g/bhp-hr), those manufacturers choosing that option, will also be 
allowed higher FEL caps for model years 2008-2010. All of these FEL 
caps are shown in Table VI.D-1 and are discussed in more detail in the 
Response to Comments document. These new FEL caps do not apply for the 
phase-out engines and vehicles.

      Table VI.D-1.--New FEL Caps for Averaging Banking and Trading
------------------------------------------------------------------------
                                   NOX FEL cap         PM/NMHC FEL cap
------------------------------------------------------------------------
HDDE........................  0.50 g/bhp-hr a.....  0.02 g/bhp-hr PM.
HDGE........................  0.50 g/bhp-hr b.....  0.30 g/bhp-hr b
                                                     NMHC.
Complete HDGV less than or    0.9 gpm.............  0.28 gpm NMHC.
 equal to 10,000 pounds GVWR.
Complete HDGV over 10,000     1.0 gpm.............  0.33 gpm NMHC.
 pounds GVWR.
------------------------------------------------------------------------
a The NOX FEL cap is 2.0 for model years 2007-2009 diesel engines.
b The NOX and NMHC FEL caps are 0.80 and 0.40 g/bhp-hr, respectively,
  for model years 2008-2010 gasoline engines for manufacturers choosing
  to certify to the 1.5 g/bhp-hr NOX+NMHC level in 2004.

D. FTP Changes to Accommodate Regeneration of Exhaust Emission Controls

    It is expected that some of the exhaust emission control devices 
used to meet today's standards will have discrete regeneration events 
that could affect emission characteristics. For example, NOX 
adsorbers incorporate discrete regenerations. The NOX 
adsorber stores NOX under normal conditions until the 
NOX storage capacity is nearly full, at which point the 
regeneration event is triggered to purge the stored NOX and 
reduce it across a catalyst. We expect that these regeneration events 
would be controlled by the engine computer, and would thus be generally 
predictable. Even passively regenerating catalytic PM trap designs can 
have discrete regeneration events that can be predictable.
    Discrete regeneration events can be important because it is 
possible for exhaust emissions to increase during the regeneration 
process. The regeneration of a NOX adsorber for instance, 
could result in increased particulates, NMHC and NOX due to 
the rich exhaust gas required to purge and reduce the NOX. 
We expect that in most cases, the regeneration events will be 
sufficiently frequent to be included in the measured emissions. Our 
feasibility analysis projects very frequent regeneration of the 
NOX adsorbers, and continuously regenerating PM traps. 
Nevertheless, this issue becomes a regulatory concern because it is 
also conceivable that these emission storage devices could be designed 
in such a way that a regeneration event would not necessarily occur 
over the course of a single heavy-duty FTP cycle, and thus be 
unmeasured by the current test procedure. In addition, desulfation of 
NOX adsorbers is clearly not likely to occur frequently 
enough to reliably be caught in the FTP. Since these regeneration 
events could produce increased emissions during the regeneration 
process, it will be important to make sure that regeneration is 
captured or accounted for as part of the certification testing.
    In order to ensure control of emissions during regeneration 
(including desulfation), we will require manufacturers to determine and 
use a mathematical adjustment of measured emissions to account for 
increased emissions during infrequent regeneration events that do not 
occur during the testing. Conversely, we will also require 
manufacturers to provide us with a consistent reverse adjustment factor 
for tests in which the regeneration does occur. For example, if a 
system requires a desulfation after every 20 FTP transient cycles, and 
PM emissions increase by 0.01 g/bhp-hr during an FTP transient cycle 
with a desulfation, we

[[Page 5112]]

will require measured emissions to be adjusted upward by 0.0005 g/bhp-
hr (0.01 g/bhp-hr divided by 20 cycles) for all tests in which that 
regeneration does not occur. The equivalent reverse adjustment 
(downward) for tests in which the regeneration does occur would be 
0.0095 g/bhp-hr (0.01 g/bhp-hr multiplied by 19/20). The reason that 
the adjustment downward would be so much larger than the adjustment 
upward is that it is correcting for a significant emission increase 
over a single emission test, while the adjustment downward would be 
correcting for that same emission increase over the other 19 tests. No 
adjustment will be made for events that are so frequent that they 
always occur during FTP testing. In designs for which these activities 
are not commanded at regular intervals, such as those based on changes 
in backpressure or NOX levels, the manufacturer would be 
required to determine an average frequency of the regeneration (during 
repeat FTP transient tests). In all cases, manufacturers would need to 
provide information to allow testers to know when an infrequent 
regeneration has occurred during the test, such as by identifying the 
controller command signal for this event. If this information is not 
available, manufacturers would be required to meet the standards during 
all tests, without regard to whether a regeneration occurs.

E. Improvements to the Test Procedures

    In response to manufacturer comments, we are finalizing changes to 
the test procedures to improve the precision of emission measurements. 
The changes fully address the manufacturers concerns about the 
potential effect of measurement precision on the feasibility of the 
standards. It is important to note that these changes are not intended 
to make measurements higher or lower, but only to improve the 
repeatability of the measurements. Based on our experience with these 
modified test procedures, and our discussions with manufacturers about 
their experiences, we are confident that these changes will not affect 
the stringency of the standards. These changes are summarized briefly 
here. A more complete description can be found in a memorandum to the 
docket.202
---------------------------------------------------------------------------

    \202\ Memorandum from Matthew Spears to Docket A-99-06, dated 
December 6, 2000.
---------------------------------------------------------------------------

    Most of the changes being finalized are in three general areas. 
Many of the changes are to the PM sampling procedure. These include 
changes to the type of PM filters that are used, and improvements in 
how PM filters are weighed before and after emission measurements, 
including requirements for more precise microbalances. Another area 
includes changes to the dilution air specifications to allow for lower 
dilution ratios. The final area of change is the NOX 
calibration procedure. The new calibration procedures will result in 
more precise continuous measurement of very low concentrations of 
NOX.
    Other changes are being made to the regulations to allow for other 
measurement options. In some cases, manufacturers will be allowed to 
use their current procedures, even though EPA will adopt the changes 
for our own testing. The reason for this is that some of these changes 
may not be convenient or cost-effective in the short term, and 
manufacturers may be willing to live with some slightly higher 
measurement variability in order to lower testing costs. We believe 
that manufacturers should be able to individually optimize their test 
facilities in this manner. However, it is important for manufacturers 
to understand that we will conduct our confirmatory testing in the 
accurate and precise manner specified in these regulations.
    We are including a new regulatory provision that specifies the 
steps that someone needs to go through to demonstrate that their own 
alternate measurement procedure is as good as or better than the 
procedure specified by our regulations. This provision is found in 40 
CFR Sec. 86.1306-07. It is also worth noting that, although we 
requested comment on changes to the NOX humidity correction 
factors used for FTP testing, we did not receive any such comments. 
Thus we will continue to use the existing NOX humidity 
correction factors for FTP testing.

F. Certification Fuel

    It is well established that measured emissions are affected by the 
properties of the fuel used during the test. For this reason, we have 
historically specified allowable ranges for test fuel properties such 
as cetane and sulfur content. These specifications are intended to 
represent most typical fuels that are commercially available in use. 
Because today's action is lowering the upper limit for sulfur content 
in the field, we are also establishing a new range of allowable sulfur 
content for testing that is 7 to 15 ppm (by weight). We believe that 
this range best represents the fuel that diesel vehicles will 
potentially see in use. Beginning in the 2007 model year, these 
specifications will apply to emission testing conducted for 
Certification and Selective Enforcement Audits, as well as any other 
laboratory engine testing for compliance purposes. Because the same in-
use fuel is used for light- and heavy-duty highway diesel vehicles, we 
are also changing the specifications for light-duty diesel vehicle 
testing.
    It is important to note that while these specifications include the 
maximum sulfur level allowed for in-use fuel, we believe that it is 
generally appropriate to test using the most typical fuels. We expect 
that refineries will typically produce diesel fuel with about 7 ppm 
sulfur, and that the fuel could have slightly higher sulfur levels 
after distribution. Thus, we expect that we would use fuel having a 
sulfur content between 7 and 10 ppm sulfur for our emission testing. 
Should we determine that the typical in-use fuel has significantly more 
sulfur than this, we would adjust this target upward.
    We are including a regulatory change to the heavy-duty gasoline 
test fuel specifications to make them the same as the recently 
established Tier 2 fuel specifications for light-duty vehicles. We are 
also extending to heavy-duty engines and vehicles the Tier 2 allowance 
for manufacturers to use California test gasoline for certification. As 
is the case with Tier 2, this allowance does not affect our authority 
to conduct our own testing using federal fuel. Also consistent with our 
approach under Tier 2, we will consider requests, prior to manufacturer 
or EPA in-use testing, to permit preconditioning procedures designed 
solely to remove the effects of high sulfur gasoline on vehicles 
produced through the 2007 model year.
    We are also allowing as an option the use of the new diesel test 
fuel beginning in the 2004 model year for vehicles employing sulfur-
sensitive technology that are certifying to the Tier 2 standards. This 
allowance to use the new fuel in model years 2004-2006 will only be 
available for vehicles for which the manufacturer recommends to the 
owner that the vehicle be operated on fuel with 15 ppm sulfur or less, 
where available. Any testing that we perform on these vehicles would 
also use fuel meeting this lower sulfur specification. This optional 
certification fuel provision is targeted at encouraging the 
introduction of low-emission light-duty diesel technologies under the 
new Tier 2 standards that will be taking effect at that time. The 
provision accounts for the fact that these vehicles will use the lower 
sulfur fuel during most, perhaps all, of their operating life, given 
the clear manufacturer recommendation for use of low-sulfur fuel in 
these vehicles, combined with prospects for early availability of this 
fuel under the

[[Page 5113]]

incentive provisions discussed in Section IV, and the assured 
availability of this fuel by mid-2006. Furthermore, we will allow 
manufacturers choosing to exercise this option in certifying vehicles 
for sale in both California and the other 49 states to use a fuel that, 
on a specification by specification basis, meets the requirements of 
either the federal or the California fuel specifications. This option 
is appropriate for light-duty vehicles and trucks since they would 
otherwise face a very complicated transition period, in which they 
would need to retest and potentially recalibrate vehicles for as many 
as four different test fuels during a three-year period.

G. Misfueling Concerns for Light- and Heavy-Duty Diesel Vehicles

    As explained in Section III, the emissions standards contained in 
these regulations will make it necessary for manufacturers to employ 
exhaust emission control devices that require low-sulfur fuel to ensure 
proper operation. This action therefore restricts the sulfur content of 
highway diesel fuel sold in the U.S. There are, however, some 
situations in which vehicles requiring low-sulfur fuel may be 
accidentally or purposely misfueled with higher-sulfur fuel. Vehicles 
operated within the continental U.S. may cross into Canada and Mexico, 
countries that may not adopt the same low sulfur requirements on the 
same schedule. High-sulfur nonroad fuel may illegally be used by some 
operators to fuel highway vehicles. Any of these misfueling events 
could seriously degrade the emission performance of sulfur-sensitive 
exhaust emission control devices, or perhaps destroy their 
functionality altogether.
    There are, however, some factors that help to mitigate concerns 
about misfueling. Most operators are very conscious of the need to 
ensure proper fueling and maintenance of their vehicles. The fear of 
large repair and downtime costs may often outweigh the temptation to 
save money through misfueling. The likelihood of misfueling in Canada 
and Mexico is lessened by current cross-border shipment practices and 
prospects for eventual harmonization of standards. Canada has recently 
expressed its intent to harmonize its fuel regulations with U.S. fuels 
standards.\203\ This would offer vehicle owners the option of refueling 
with low-sulfur fuel there. Even if Canada were to lag behind the U.S. 
in mandating low-sulfur fuels, these fuels would likely become 
available along major through routes to serve the needs of U.S. 
commercial traffic that have the need to purchase it. In addition, 
there is less potential for U.S. commercial vehicles needing low-sulfur 
fuel to refuel in Canada because Canadian fuel is currently more costly 
than U.S. fuel. As a result, most vehicle owners will prefer to 
purchase fuel in the U.S., prior to entering Canada, whenever possible. 
This is facilitated by large tractor-trailer trucks that can have long 
driving ranges--up to 2,000 miles per tankful or so--and the fact that 
most of the Canadian population lives within 100 miles of the United 
States/Canada border.
---------------------------------------------------------------------------

    \203\ ``Process Begins to Develop Long Term Agenda to Reduce Air 
Pollution from Vehicles and Fuels'', Environment Canada press 
release, May 26, 2000.
---------------------------------------------------------------------------

    In Mexico, the entrance of trucks beyond the border commercial zone 
has been prohibited since before the conclusion of the North American 
Free Trade Agreement in 1994. This prohibition applies in the U.S. as 
well, as entrance of trucks into the U.S. beyond the border commerce 
zone is also not allowed. Since these prohibitions are contrary to the 
intent of the Free Trade Agreement, a timetable was established to 
eliminate them.\204\ However, these prohibitions remain in force at 
this time.
---------------------------------------------------------------------------

    \204\ See NAFTA, Volume II, Annex I, Reservations for Existing 
Measures and Liberalization Commitments, Pages I-M-69 and 70, and 
Pages I-U-19 and 20.
---------------------------------------------------------------------------

    The NAFTA negotiations included creation of a ``corridor'' where 
commercial truck travel occurs, and where Mexico is obligated to 
provide ``low-sulfur'' fuel. At the time of the NAFTA negotiations, 
``low-sulfur'' fuel was considered 500 ppm, which was the level needed 
to address the needs of engines meeting the 1994 emission standards. 
The travel prohibition currently in place may be lifted at some point. 
At that time, the issue of assuring, for U.S. vehicles, the 
availability of fuel with a sulfur level needed by the new technology 
may need to be addressed.
    Even considering these mitigating factors, we believe it is 
reasonable to adopt additional measures with very minor costs to 
manufacturers, fuel distributors, and consumers. First, we are 
requiring that highway diesel fuel pumps and co-located nonroad diesel 
fuel pumps be prominently labeled, as described in Section VII.
    We are also adopting a requirement that heavy-duty vehicle 
manufacturers notify each purchaser of a model year 2007 or later 
diesel-fueled vehicle that the vehicle must be fueled only with the 
low-sulfur diesel fuel meeting the regulations being adopted in this 
FRM. We believe this requirement is necessary to alert vehicle owners 
to avoid higher sulfur fuel in the U.S. and to seek out low-sulfur fuel 
when operating in areas such as Canada and Mexico where it may not be 
widely available. We are also requiring that model year 2007 and later 
heavy-duty diesel vehicles must be equipped by the manufacturer with 
labels on the dashboard and near the refueling inlet that say: ``Use 
Low Sulfur Diesel Fuel Only'' or ``Low Sulfur Diesel Fuel Only''. For 
non-integrated manufacturers, the engine manufacturer will be required 
to provide such a label to the vehicle manufacturer, which the vehicle 
manufacturer will be required to install. Optionally, if a vehicle 
manufacturer chooses to install its own label, the engine manufacturer 
will not be required to provide the label.
    We believe that these measures will help vehicle owners find and 
use the correct fuel and will be sufficient to address misfueling 
concerns. Thus, more costly provisions, such as vehicles fuel inlet 
restrictors, will not be necessary.
    We are also requiring that the labeling and purchaser notification 
requirements described above for heavy-duty vehicles also be applied to 
the light-duty diesel vehicles certified to the final Tier 2 standards 
using certification test fuel with 15 ppm or less sulfur. These 
vehicles are expected to also need the low-sulfur fuel and be equally 
susceptible to misfueling damage.

H. In-Use Compliance Levels During the Transition Years to New 
Technologies

    The Phase 2 standards will be challenging for diesel and gasoline 
engine manufacturers to achieve, and will require manufacturers to 
develop new technologies for their engines. Not only will manufacturers 
be responsible for ensuring that these technologies will allow engines 
to meet the standards at the time of certification, they will also have 
to ensure that these technologies continue to be highly effective in a 
wide range of in-use environments so that their engines would comply 
in-use when tested by EPA. However, in the early years of a program 
that introduces new technology, there are risks of in-use compliance 
problems that may not appear in the certification process or during 
developmental testing. Thus, we believe that it is appropriate to 
adjust the compliance levels for assessing in-use compliance for low 
emission engines (i.e., diesel engines equipped with the new exhaust 
emission control devices expected for Phase 2 diesel engines, and 
gasoline engines

[[Page 5114]]

employing Tier 2/Phase 2 level technology). This will provide assurance 
to the manufacturers that they will not face recall if they exceed 
standards by a small amount during this transition to clean 
technologies. This approach is very similar to that taken in the Tier 2 
final rule, which involves a similar introduction of new technologies 
(65 FR 6796, February 10, 2000).
    Table VI.H-1 shows the in-use adjustments that we will apply to 
diesel and gasoline engines. These adjustments will be added to the 
appropriate FELs (or for engines certified to the standards without the 
use of credits, to the standards themselves) in determining the in-use 
compliance level for a given in-use mileage. For example, a light HD 
diesel engine with a useful life of 110,000 miles and a NOX 
FEL of 0.20 g/bhp-hr would have an in-use compliance level of 0.30 g/
bhp-hr (0.20 + 0.10) throughout its useful life. A heavy HD diesel 
engine, having a useful life of 435,000 miles and a NOX FEL 
of 0.20 g/bhp would have an in-use compliance level of 0.30 g/bhp-hr 
through 110,000 miles, 0.35 g/bhp-hr from there through 185,000 miles, 
and 0.40 g/bhp-hr through the remainder of its useful life. The 
adjustment levels were chosen to be roughly equivalent to the temporary 
in-use standard adjustments adopted for low-emitting vehicles in the 
Tier 2 program, accounting for the higher mileage requirements 
reflected in the useful lives of the larger heavy-duty engines. Note 
too in the table footnotes the limiting of these adjustments to engine 
certified to levels below certain threshold levels. This is similar to 
the approach taken in the Tier 2 rule which applied the in-use 
standards only to vehicles in certain low-emitting bins.

  Table VI.H-1.--Add-on Levels used in Determining In-use Standards for
                        Diesel & Gasoline Engines
------------------------------------------------------------------------
                                    Diesel \a\
                                       and       Diesel PM   Gasoline\c\
                                     gasoline      Add-on    NMHC Add-on
      Engine mileage (miles)       \b\ NOX Add-   level to     level to
                                   on level to  FEL (g/bhp-  FEL (g/bhp-
                                   FEL (g/bhp-      hr)          hr)
                                       hr)
------------------------------------------------------------------------
110,000..........................         0.10         0.01         0.10
110,000 to 185,000...............         0.15         0.01      \d\ N/A
185,000 to 435,000...............         0.20         0.01     \d\ N/A
------------------------------------------------------------------------
\a\ Applicable to those diesel engines with FELs at or below 1.3 g/bhp-
  hr NOX through 2011.
\b\ Applicable to those gasoline engines with NOX FELs at or below 0.5 g/
  bhp-hr through 2011.
\c\ Applicable to those gasoline engines with NMHC FELs at or below 0.3
  g/bhp-hr through 2011.
\d\ Note that the useful life for gasoline engines is 110,000 miles, so
  these add-on levels have significance only to that mileage for
  gasoline engines.

    Similar examples apply for diesel engine PM, with the exception 
that the PM in-use add-on level is a constant 0.01 regardless of 
mileage. Likewise for gasoline NMHC where the add-on level is a 
constant 0.10 g/bhp-hr through the 110,000 mile useful life.
    These same in-use add-on levels will be applied to the 
certification SET and NTE levels after applying the SET and NTE 
multipliers for the purpose of determining the corresponding in-use 
standards. In other words, for heavy HD diesel engine with a 
NOX FEL of 0.20 g/bhp-hr, the in-use SET standard would be 
0.30, 0.35, and 0.40 g/bhp-hr in each respective mileage range 
(remember that the SET multiplier is 1.0  x  the FTP standard or FEL). 
The in-use NTE standard, with a multiplier of 1.5  x  the FTP standard 
or FEL, would be 0.40, 0.45, and 0.50 g/bhp-hr in each of the 
respective mileage ranges (0.20  x  1.5 = 0.30; + 0.1 = 0.40; + 0.15 = 
0.45; + 0.20 = 0.50).
    Note that these in-use add-on levels apply only to engines 
certified through the 2011 model year and having FELs below the 
specified levels. These levels are very low and represent levels we 
believe will require significant effort by manufacturers to reach. The 
in-use add-ons are available through 2011 because some diesel engine 
models may not incorporate the emission control technology until 2010 
as a result of the final phase-in schedule. Engine models incorporating 
these technologies for the first time in 2010 may account for as many 
as 50 percent of all diesel engines sold in that year. We believe these 
engine models should be provided the in-use adjustment for at least the 
first two years of their market introduction. In the case of gasoline 
engines, the phase-in ends in the 2009 model year. However, we have 
decided to allow the in-use adjustments through model year 2011, 
consistent with the diesel provision.
    For HD complete gasoline vehicles, and any complete diesel vehicles 
choosing the chassis certification option, we will have a flat in-use 
adjustment of 0.1 g/mile NOX, 0.100 g/mile NMHC (gasoline 
vehicles only), and 0.01 PM for all weight classes. These in-use 
adjustments will apply only to those vehicles certified with FELs at or 
below the applicable Phase 2 standards. Further, they will apply for 
vehicles certified through 2010 so that those vehicle models newly 
certified to the Phase 2 standards in 2009 are given two years of 
certification experience prior to elimination of the in-use 
adjustments. Table VI.H-2 shows the adjustments that will apply to HD 
chassis certified vehicles.

                        Table VI.H-2.--In-Use Adjustments for Chassis Certified Vehicles
----------------------------------------------------------------------------------------------------------------
                                                    Durability
               Weight range (GVWR)                period (miles)  NOX \a\ (g/mi)   NMHC \a\ (g/      PM (g/mi)
----------------------------------------------------------------------------------------mi)---------------------
8,500 to 10,000 lbs.............................         120,000             0.1           0.100            0.01
10,000 to 14,000 lbs............................         120,000             0.1           0.100           0.01
----------------------------------------------------------------------------------------------------------------
\a\ Applicable to those vehicles with NOX and/or NMHC FELs at or below the appropriate Phase 2 standards through
  2010.

    During the certification demonstration, manufacturers will still be 
required to demonstrate compliance with the unadjusted Phase 2 
certification standards using deteriorated emission rates. Therefore,

[[Page 5115]]

the manufacturer will not be able to use these in-use standards as the 
design targets for the engine or vehicle. They will need to project 
that most engines would meet the standards in-use without adjustment. 
The in-use adjustments will merely provide some assurance that they 
would not be forced to recall engines or vehicles because of some small 
miscalculation of the expected deterioration rates. Furthermore, given 
that a new diesel fuel will be in place and it will be sold alongside 
higher sulfur diesel fuel being marketed to the existing fleet, there 
is a small likelihood of accidental misfueling during the phase-in 
years as users become familiar with the importance of using the lower 
sulfur fuel. As discussed in detail in sections III.E and III.F, sulfur 
has adverse impacts on exhaust emission control devices.

VII. Highway Diesel Fuel Program: Compliance, Enforcement and 
Downstream Provisions

    For the highway diesel fuel sulfur program that we are adopting 
today to be successful in achieving its large emission reduction goals, 
it is vital for all parties that are affected by the program to 
thoroughly understand what is expected of them to comply, what 
compliance options may apply to them, and how their compliance will be 
assessed and enforced. If you believe that you are or may be subject to 
the program, the most important information is found in the regulatory 
language following this preamble. There, readers will find the detailed 
legal requirements of the program for each party and how we will assess 
and enforce compliance with the program requirements.
    A key purpose of this preamble is to supplement the regulatory 
language by providing a context for and an explanation of the 
requirements of the program. Section IV above discusses in some detail 
most of the requirements under the highway diesel fuel sulfur program 
adopted today. In addition, this section (Section VII) builds on the 
Section IV discussions by addressing specific compliance and 
enforcement provisions we have adopted in today's rule to ensure that 
highway diesel fuel standards are met at all points in the distribution 
system--from the refiner or importer that introduces the fuel into the 
distribution system, through all the parties that may distribute the 
fuel, to the retailers and other parties that provide the fuel to its 
ultimate user. This section also explains certain requirements of the 
program in more detail.
    After touching on a few general aspects of the highway diesel fuel 
program, this section discusses the compliance and enforcement 
provisions that apply to refiners and importers and those that apply to 
the downstream parties that handle diesel fuel. This section also 
discusses diesel fuel sampling and testing for sulfur, reporting and 
recordkeeping requirements, limited exemptions from the program, and 
how liability for any noncompliance would be handled.

A. General Provisions

1. Definition of Diesel Fuel Covered by This Program
    In this preamble, we refer to the fuel covered by the program 
adopted today as ``highway diesel fuel.'' For technical and legal 
consistency with the Clean Air Act and existing fuels regulations, the 
regulatory language associated with today's rule uses the term ``motor 
vehicle diesel fuel'' in order to assure consistency with the language 
in existing laws and regulations. ``Nonroad diesel fuel'' refers to 
diesel fuel intended for use in nonroad vehicles or equipment, and is 
not covered by the highway diesel fuel sulfur requirements of the 
program. However, any fuel that is available for highway vehicles and 
engines, whether or not it is also available for nonroad vehicles and 
engines or for other purposes, is treated as highway diesel fuel under 
today's program.
2. Relationship to Highway Diesel Standards
    As discussed in Section IV above, today's final rule reduces the 
sulfur cap standard for highway diesel fuel from 500 ppm to 15 ppm 
nationally \205\ effective in 2006. (Implementation dates are discussed 
further in Section VII.C.2. below.) The existing standards for cetane 
and aromatics will remain in effect and are not being changed by 
today's action (40 CFR Sec. 80.29(a)). The highway diesel fuel sulfur, 
cetane, and aromatics standards will be enforced through sampling and 
testing at all points in the distribution system, combined with 
inspection of fuel delivery records and other commercial documents. The 
general compliance requirements of this rule are very similar to those 
in the current diesel fuel rule, except that the sulfur standard is 
substantially more stringent (see 40 CFR 80.29 and 80.30). Prior to the 
implementation dates for today's rule, all the requirements and 
prohibitions of the current diesel fuel rule will remain in effect, 
with limited modifications concerning sulfur sampling methods.
---------------------------------------------------------------------------

    \205\ Except as noted elsewhere in the preamble and final rule, 
today's rule applies to all states, including the State of 
California. See Section IV.F for unique implementation provisions 
for Alaska and exemptions for diesel fuel in certain U.S. 
territories.
---------------------------------------------------------------------------

B. What Are the Requirements for Refiners and Importers?

1. General Requirements
    As discussed earlier in this preamble, the sulfur sensitivity of 
emission controls that will be used on model year 2007 and later motor 
vehicles requires that the sulfur content of highway diesel fuel 
dispensed into 2007 and later heavy-duty vehicles not exceed 15 ppm. To 
ensure that highway diesel fuel meets this standard as it leaves the 
refinery or import facility, today's final rule adopts the proposed 
approach that if the sulfur content of highway diesel fuel at a 
refinery or import facility exceeds 15 ppm by any amount, the fuel is 
in violation of the sulfur standard. The determination of compliance 
with the sulfur standard for highway diesel fuel at the refinery level 
is not subject to a test tolerance.\206\
---------------------------------------------------------------------------

    \206\ However, test variability is taken into account in 
determination of compliance for diesel fuel at locations downstream 
of the refinery or import facility. See Section VII.C.1.
---------------------------------------------------------------------------

    Consistent with the proposal, today's final rule does not require 
that refiners or importers engage in mandatory sampling and testing of 
every batch of highway diesel fuel they produce or import.\207\ This is 
because the highway diesel fuel sulfur standard is a national cap 
standard and compliance can be monitored at any point in the 
distribution system by taking samples of fuel for testing. However, 
under the presumptive liability scheme, any refiner producing 
noncomplying product would face liability for fuel in violation of the 
standard, regardless where the violation is discovered. (See Sections 
VII.G. and VII.H. for a discussion of liability and penalties.) 
Consequently, we expect that refiners and importers will voluntarily 
test every batch of highway diesel fuel produced or imported for their 
own purposes, including the need to demonstrate compliance with 
pipeline specifications.
---------------------------------------------------------------------------

    \207\ However, any refiner producing highway diesel fuel 
complying with the 500 ppm standard for use in pre-model year 2007 
motor vehicles, under any of the several refiner flexibility 
options, would have to maintain records designating each batch as 
complying with the 15 ppm standard or the 500 ppm standard.
---------------------------------------------------------------------------

    Today's program requires all refiners that on January 1, 2000 
produced--or by June 1, 2006 expect to produce--highway diesel fuel for 
U.S. sale to

[[Page 5116]]

register with EPA. Similarly, all importers that on January 1, 2000 
imported--or by June 1, 2006 expect to import--highway diesel fuel into 
the U.S. also need to register with EPA. This registration process will 
provide an essentially complete and up-to-date picture of the universe 
of highway diesel suppliers that exist at the beginning of this 
program. Refiners and importer must register by December 31, 2001. See 
Section VII.E. below for more details about registration requirements.
2. Refiner and Importer Temporary Compliance Option Provisions and the 
Credit Trading Program
    As described in Section IV.A.2 above, today's final rule adopts a 
program that allows refiners and importers to transition in the 
production and importation of 15 ppm sulfur content diesel fuel. The 
temporary compliance option is available to all refiners and importers 
and includes a credit averaging, banking, and trading program. This 
temporary compliance option allows a refiner or importer to designate 
and sell a certain percentage of its highway diesel fuel as fuel 
subject to a 500 ppm sulfur standard, for use in pre-2007 model year 
heavy-duty vehicles.
    Section IV.A.2 above describes most of the compliance requirements 
associated with the temporary compliance option. The paragraphs below 
supplement the earlier information.
a. Early Credits Program
    As discussed in Section IV.A.2.a, today's regulation allows 
refiners and importers to generate early credits (prior to June 1, 
2006) under limited circumstances. Most of the compliance requirements 
associated with the early credits program are described in that 
section. The following paragraphs add certain supplemental information.
    The early credits program has two sets of provisions: (1) credits 
generated after May 31, 2005 but before June 1, 2006, and (2) credits 
generated after June 1, 2001 but before May 31, 2005. For a refiner or 
importer to generate early credits after May 31, 2005, it must 
demonstrate that the 15 ppm fuel produced early was segregated in the 
distribution system and not commingled with current 500 ppm sulfur 
fuel. Only that volume the refiner could verify was actually sold as 15 
ppm fuel at retail or to centrally-fueled fleets would be eligible for 
early credits. Prior to generating credits, the refiner or importer 
must submit a notification to EPA and demonstrate how it will ensure 
segregation of the fuel from other highway diesel fuel and that the 
fuel will be sold as 15 ppm fuel (e.g., through voluntary pump labeling 
and/or through information provided in PTDs).
    The program also specifies that early credits can be generated 
prior to June 1, 2005. In this case, however, the refiner or importer 
must demonstrate that the 15 ppm fuel will be used in vehicles 
certified to meet the 2007 particulate matter standard being adopted 
today for heavy-duty engines (0.01 g/bhp-hr) or in vehicles with 
retrofit technologies that achieve emission levels equivalent to the 
2007 NOX or PM standard verified as part of a retrofit 
program administered by EPA or a state. (See Section VIII for further 
discussion of the credit program for heavy-duty engines.) To meet this 
condition, the refiner or importer must notify EPA, and in its 
notification it must demonstrate that any early credits that it claims 
are only for the volume of 15 ppm fuel that is dispensed into vehicles 
meeting the emission standards as described above (e.g., into 
designated fleet vehicles).
    All early credits generated, banked, transferred, obtained or used 
must be identified as early credits in records and in reports. The 
refiner's annual pre-compliance reports must provide the volume of 
early credit fuel produced, credits generated, credits transferred, and 
continued demonstration that the early credit fuel is sold 
appropriately (i.e., as 15 ppm fuel after May 31, 2005, or into 
vehicles meeting the 2007 standards up to May 31, 2005).
b. Credit Use in a Credit Deficit Situation
    Today's rule allows a refinery or importer to have a credit deficit 
in any given year (as long as the deficit does not exceed five percent 
of its annual highway diesel fuel production) so long as the refinery 
or importer makes up for that credit deficit the next year. In other 
words, the year following the deficit the refiner or importer must have 
enough credits (or actual production volume of 15 ppm fuel) to cover 
the previous year's deficit and to cover the current year's compliance. 
A refinery or importer (by PADD) must use credits to cover its own 
compliance before it can transfer credits to another refinery or 
importer, and although a refinery is allowed to be in deficit for a 
given year, it cannot lawfully transfer credits in the deficit year.
c. Resolving Issues of Invalid Credits
    We recognize that there is potential for credits to be generated by 
one party and subsequently purchased and used in good faith by another 
party, yet the credits are later found to have been calculated or 
created improperly, or otherwise found to be invalid. As with the RFG 
rule and the Tier 2/Gasoline Sulfur rule, invalid credits purchased in 
good faith cannot be legally used. To allow such use would not be 
consistent with the environmental goals of the regulation. Further, 
both the seller and purchaser of invalid credits would have to adjust 
their credit calculations to reflect the proper credits and either 
party (or both) could be deemed in violation if the adjusted 
calculations demonstrated noncompliance.
    Nevertheless, our strong preference is to hold the credit seller 
liable for the violation, rather than the credit purchaser. As a 
general matter we would expect to enforce a shortfall in credit 
compliance calculations against the credit seller, and we would expect 
to enforce a compliance shortfall (caused by the good faith purchase of 
invalid credits) against a good faith purchaser only in cases where we 
are unable to recover sufficient valid credits from the seller to cover 
the shortfall. Moreover, in settlement of such cases we would strongly 
encourage the seller to purchase credits to cover the good faith 
purchaser's credit shortfall. EPA will consider the covering of a 
credit deficit through the purchase of valid credits a very important 
factor in mitigation of any case against a good faith purchaser, 
whether the purchase of valid credits is made by the seller or by the 
purchaser.
d. Compliance Provisions
    Today's rule includes compliance provisions under the temporary 
compliance option to allow the determination of the volumes of each of 
the two grades of highway diesel fuel produced or imported by each 
participating refinery or importer. For parties participating in the 
credit program, the rule includes provisions to ensure compliance with 
the credit generation, banking and trading provisions. The requirements 
include the designation of each batch of highway diesel fuel as meeting 
either the 500 ppm sulfur standard or the 15 ppm highway diesel sulfur 
standard; maintenance of records concerning the volumes of each grade 
of highway diesel fuel produced (and for foreign refiners and 
importers, volumes by PADD of import); and maintenance of records 
concerning the generation, use, transfer and purchase of credits, if 
applicable (by PADD in the case of foreign refiners and importers). 
Beginning in 2007, annual compliance reports demonstrating compliance 
with the applicable provisions are required. These recordkeeping and 
reporting

[[Page 5117]]

requirements are discussed more fully in Section VII.E below.
    The rule also includes enforcement and compliance provisions to 
assure that highway diesel fuel subject to the 15 ppm sulfur standard 
is not caused to exceed the standard by being contaminated with highway 
diesel fuel subject to the 500 ppm sulfur standard (or other high 
sulfur products such as nonroad diesel fuel), and to assure that 500 
ppm diesel fuel is not introduced into model year 2007 and later motor 
vehicles. Participating refiners and importers are required to provide 
identifying information on product transfer documents for highway 
diesel fuel subject to the 500 ppm standard to help prevent 
contamination of 15 ppm product. (As discussed more fully below, 
transfers of 15 ppm highway diesel fuel must also be accompanied by 
product transfer documents identifying such fuel.)
e. Additional Provisions for Importers of Diesel Fuel and for Foreign 
Refiners Subject to the Temporary Compliance Option and Hardship 
Provisions
    Since today's final rule includes several compliance options that 
can be used by diesel fuel importers and foreign refiners, we are also 
including specific compliance and enforcement provisions to ensure 
compliance for imported highway diesel fuel. These special foreign 
refiner provisions are similar to those under the conventional gasoline 
regulations and the gasoline sulfur regulations (see 40 CFR 80.94 and 
80.410).
    Under today's rule, standards for highway diesel fuel produced by 
foreign refineries must be met by the importer, unless the foreign 
refiner has been approved to produce highway diesel fuel under the 
temporary compliance option or hardship provisions of today's rule. If 
the foreign refiner is so approved, the volume requirements are to be 
met by the foreign refinery and the foreign refinery would be the 
entity generating, using, banking or trading credits for the highway 
diesel fuel produced and imported into the U.S.
    Any foreign refiner that applies for and obtains approval to 
produce highway diesel fuel subject to the temporary compliance option 
or hardship provisions will be subject to the same requirements as 
domestic refiners operating under the same provisions. Additionally, 
foreign refiners are subject to provisions similar to the provisions at 
40 CFR 80.94 and 80.410, which include:

--Segregating highway diesel fuel produced at the foreign refinery 
until it reaches the U.S. and separately tracking volumes imported into 
each PADD;
--Controls on product designation;
--Load port and port of entry testing;
--Attest requirements; and
--Requirements regarding bonds and sovereign immunity.

    These provisions aid the Agency in tracking highway diesel fuel 
from the foreign refinery to its point of import into this country. We 
believe these provisions are necessary and sufficient to ensure that 
foreign refiners' compliance can be monitored and that the requirements 
of today's rule can be enforced against foreign refiners. (For more 
discussion of the rationale for these enforcement provisions, see 
preamble to the final RFG/CG foreign refineries rule (see 62 FR 45533 
(August 28, 1997) and the gasoline sulfur rule, 40 CFR 80.410).)
3. Refiner Hardship Provisions
a. General Refiner Hardship Provisions
    Section IV.C. above describes two types of hardship provisions for 
which any refiner may petition. We will consider such petitions in 
cases of extreme unforseen circumstances and of extreme hardship 
circumstances. Petitions for extreme unforseen circumstances may be 
submitted at any time; petitions for extreme hardship circumstances 
must be submitted to EPA by June 1, 2002. If any relief granted 
includes allowing the refiner to produce 500 ppm highway diesel fuel 
(or additional 500 ppm highway diesel fuel beyond that allowed under 
the temporary compliance option) for use in pre-2007 heavy-duty 
vehicles and engines, we would apply enforcement provisions at least as 
stringent as those that apply for the temporary compliance option.
    Any application for hardship relief later found to be based on 
false or inaccurate information will be void ab initio.
b. Small Refiner Hardship Provisions
    Section IV.C.1 above describes three small refiner relief 
provisions. Section IV.C.1.b defines ``small refiner,'' Section 
IV.C.1.c describes the special provisions that approved small refiners 
are eligible for, and Section IV.C.1.d describes how a refiner applies 
for status as a small refiner. Section VII.E below describes the 
additional information that small refiners need to include in their 
application for small refiner status, in their pre-compliance reports, 
and in their annual compliance reports (these requirements vary 
depending on which small refiner provision they choose). Any 
application for small refiner status will be void ab initio if approval 
is based on false or inaccurate information.
    For an approved small refiner to use the Diesel/Gasoline Compliance 
Date Option (described in Section IV.C. above) at one or more 
refineries, it must fulfill two main conditions: (1) 100 percent of the 
highway diesel volume it produces during each annual compliance period 
starting June 1, 2006 must meet the 15 ppm standard, and (2) the actual 
volume of highway diesel fuel it produces during each annual compliance 
period through 2010 must be at least 85 percent of its 1998-1999 
baseline highway diesel fuel volume (i.e., through the end date of the 
extended small refiner interim gasoline program). If a refiner at some 
point did not fulfill one or both of these conditions, it would forfeit 
the entire three year extension (or any remaining portion of the 
extension) of its Tier 2/Gasoline Sulfur small refiner standards and 
would thus need to comply with the 30/80 ppm sulfur standards by 
January 1, 2008. During the period when the national gasoline sulfur 
standard would otherwise be in effect for a small refiner (2008-2010), 
if the refiner fails to meet the two conditions above, it would be 
subject to the 30/80 gasoline sulfur standard for that year and future 
years.
    However, a small refiner may elect to petition EPA to permanently 
opt out of this Diesel/Gasoline Compliance Date Option and opt into 
another small refiner option or into the temporary compliance option, 
so long as it does so for the full year that the change in program 
options takes place. Once it makes that election, it must thereafter 
meet the 30/80 gasoline sulfur standard.
c. Relief for Refiners Supplying Gasoline to the Tier 2 Geographic 
Phase-In Area (GPA)
    As discussed in Section IV.B, refiners or importers supplying 
gasoline to the Geographic Phase-In Area (GPA) established in the Tier 
2/Gasoline Sulfur program may apply for an additional two years to meet 
interim Tier 2 GPA gasoline sulfur standards (through December 31, 
2008). Similar to the criteria for small refiners under the Diesel/
Gasoline Compliance Date Option above, a refiner wishing to receive 
this extension of the Tier 2 GPA standards must meet two main 
conditions: (1) 100 percent of the highway diesel volume it produces 
during each annual compliance period starting June 1, 2006 must meet 
the 15 ppm standard, and (2) the actual volume of highway diesel fuel 
it produces during each annual compliance period through 2008 must be 
at least 85 percent

[[Page 5118]]

of its 1998-1999 baseline highway diesel fuel volume (i.e., through the 
end date of the extended GPA gasoline program). Refiners may not 
participate both in this option and the temporary compliance option.
    To be eligible for this option, a refiner must apply to EPA in 
writing by December 31, 2001, at the same time that it registers as a 
highway diesel fuel producer with EPA. As with applications by refiners 
for ``small refiner'' status, a refiner's application must submit its 
average annual highway diesel volume baseline for 1998 and 1999 for 
each of its refineries it expects to be covered by the GPA provisions 
under today's program.
    If a refiner did not fulfill one or both of the conditions above, 
it would forfeit the entire two-year extension of the GPA standards, or 
any remaining extension, and would thus need to comply with the 30/80 
ppm sulfur standards by January 1 of the following year.
    However, a refiner may elect to petition EPA to permanently opt out 
of this GPA program and opt into the temporary compliance option, so 
long as it does so for the full year that the change in program options 
takes place. Once it makes that election, it must thereafter meet the 
30/80 gasoline sulfur standard.

C. What Requirements Apply Downstream of the Refinery or Import 
Facility?

1. Downstream Enforcement of the Standards
    In the NPRM, we proposed an industry-wide 15 ppm cap on sulfur 
content for highway diesel fuel. In the proposal we stated our belief 
that refiners would likely have to produce diesel fuel meeting a 7-8 
ppm average sulfur content in order to ensure compliance downstream. We 
received comments to the NPRM indicating that enforcing the 15 ppm 
sulfur cap at all levels of the distribution system downstream of the 
refinery or import facility would effectively require refiners to 
produce diesel fuel having a maximum sulfur content of 7 ppm due to 
variability in sulfur content test results that may occur between 
laboratories when testing the same sample of diesel fuel for sulfur 
content. Commenters stated that at test reproducibility level of +/-4 
ppm,\208\ refiners would have no assurance of downstream compliance 
with the 15 ppm cap if they produced any fuel with a sulfur content 
greater than 7 ppm. Consequently, commenters suggested either that we 
adopt a less stringent downstream sulfur standard, based on test 
variability, as was done in the Tier 2/Gasoline Sulfur rule (40 CFR 
80.210), or that we state a downstream test tolerance, based on test 
variability.
---------------------------------------------------------------------------

    \208\ The NPRM preamble suggested a possible reproducibility 
level of 4 ppm.
---------------------------------------------------------------------------

    After considering the comments, we agree that it is appropriate to 
recognize test variability in determination of compliance with the 
sulfur standard downstream of the refinery or import facility. However, 
we anticipate that the reproducibility of sulfur test methods is likely 
to improve to two ppm or even less by the time the rule goes into 
effect. Thus, today's rule provides that for all 15 ppm sulfur highway 
diesel fuel at locations downstream of the refinery or import facility, 
sulfur test results can be adjusted by subtracting 2 ppm to account for 
the expected reproducibility of sulfur test methods. The sole purpose 
of this downstream compliance provision is to address test variability 
concerns. With this change, we anticipate that refiners will be able to 
produce diesel fuel at an average level of approximately 7-8 ppm, as 
was intended by the proposal, without fear of causing a downstream 
violation due solely to test variability. As test methods improve in 
the future, we may reevaluate whether two ppm is the appropriate 
allowance for purposes of this compliance provision.
    This change is not expected to undermine the environmental goals of 
the regulation since it should not result in diesel fuel exceeding the 
15 ppm sulfur standard at any point in the distribution system. All 
highway diesel fuel subject to the 15 ppm standard is still required to 
meet the 15 ppm standard at the refinery gate, without allowance for 
test variability.\209\ The purpose of taking testing variability into 
account in compliance determinations for fuel sampled downstream of the 
refinery or import facility is merely to ensure that fuel actually 
meeting the 15 ppm cap is not rejected by pipelines or otherwise 
treated as noncompliant due to concerns about testing variability. It 
is not expected to result in any increase in the actual sulfur content 
of highway diesel fuel above 15 ppm at any point in the distribution 
system.
---------------------------------------------------------------------------

    \209\ Once motor vehicle diesel fuel is moved from the tank in 
which it was blended at the refinery (and which the refiner's 
designation of the fuel as meeting the 15 ppm standard was based), 
the two ppm adjustment applies.
---------------------------------------------------------------------------

2. Other Provisions
a. Implementation Dates
    As discussed in Section IV.A, today's rule staggers the 
implementation dates for highway diesel fuel for use in 2007 and later 
vehicles to comply with the 15 ppm sulfur standard, based on a 
facility's position in the distribution system. Refiners and importers 
must meet the 15 ppm sulfur standard by June 1, 2006. Fuel in the 
distribution system downstream of the refinery or import facility, 
including fuel at truck loading terminals,but not including fuel at 
retail outlets or wholesale purchaser-consumers, must be in compliance 
by July 15, 2006. Highway diesel fuel at retailers' and wholesale 
purchaser-consumers' storage tanks must be in compliance by September 
1, 2006, and pump labeling requirements (see Section VII.C.2.c below) 
also must be in place by that date. We believe the dates finalized in 
today's rule will allow sufficient time for downstream parties to 
transition tanks from 500 ppm sulfur levels to 15 ppm sulfur levels.
    The date by which all highway diesel fuel produced by refiners must 
meet the 15 ppm sulfur standard is June 1, 2010.\210\ The final 
compliance date for all highway diesel fuel in the distribution system 
to meet the 15 ppm standard, other than at retail outlets and wholesale 
purchaser-consumer facilities, is October 1, 2010. The final compliance 
date for all highway diesel fuel at retail and wholesale purchaser-
consumer facilities to meet the 15 ppm sulfur standard is December 1, 
2010.
---------------------------------------------------------------------------

    \24\ Under the temporary compliance option, for the period from 
January 1, 2010 through May 31, 2010, refiners can produce 500 ppm 
fuel only through the use of credits.
---------------------------------------------------------------------------

b. Product Segregation and Contamination
    Under today's diesel sulfur program, it is imperative that 
distribution systems segregate highway diesel fuel from high sulfur 
distillate products such as home heating oil and nonroad diesel fuel. 
The sulfur content of those products is frequently as high as 3,000 
ppm. We are also concerned about potential misfueling at retail outlets 
and wholesale purchaser-consumer facilities, even if segregation of the 
different grades of diesel fuel has been maintained in the distribution 
system. Thus, certain downstream compliance and enforcement provisions 
of the rule are aimed at both preventing contamination of highway 
diesel fuels with fuels containing higher levels of sulfur, and 
preventing misfueling of motor vehicles with high sulfur fuels.
    Similarly, it is imperative that all parties in the distribution 
system avoid contamination of 15 ppm highway diesel fuel with 500 ppm 
highway diesel fuel. Thus, the final rule has adopted a requirement for 
product

[[Page 5119]]

transfer documents accompanying deliveries of motor vehicle diesel fuel 
diesel fuel to identify the sulfur standard it meets and its allowed 
use. All parties in the distribution system face liability if highway 
diesel fuel is contaminated such that it fails to meet the applicable 
standard.
    We are also adopting provisions designed to discourage the 
downgrading of 15 ppm diesel to 500 ppm diesel in the distribution 
system during the initial years of the program when the optional 
compliance provision is in effect. Our concern is that if 15 ppm diesel 
is routinely downgraded and sold as 500 ppm fuel, this practice could 
lead to availability problems (i.e., risk of 15 ppm not being widely 
available across the country). We fully recognize that some amount of 
15 ppm downgrading will be necessary where the 15 ppm fuel becomes 
contaminated in the distribution system (e.g., pipeline interfaces). In 
fact, one advantage of the temporary compliance option is that if 15 
ppm fuel becomes contaminated, it can still be sold as highway fuel 
(downgraded to 500 ppm fuel), rather than downgrading it to off-highway 
fuel. However, we also recognize that there is the potential for 
parties in the distribution system to intentionally mix 15 ppm product 
with 500 ppm fuel, and still sell the product as 500 ppm fuel. While we 
don't expect this practice to be widespread, it could occur, especially 
where there is only a small price differential between the two fuels.
    Therefore, we are restricting the volume of 15 ppm fuel that can be 
downgraded to 500 ppm highway diesel fuel at each point in the 
distribution system (downstream of the refinery gate) to not more than 
20 percent on an annual basis. Each party in the distribution system 
subject to this provision will be required to meet this requirement 
separately, based on the amount of 15 ppm fuel it receives and 
transfers/sells to the next party (or end user, in the case of 
retailers and wholesale purchaser-consumers) on an annual basis. We 
believe that this limit will be more than sufficient to allow for some 
downgrading for any contamination that may occur, while still being 
restrictive enough to discourage downgrading and commingling of 15 ppm 
fuel with 500 ppm fuel. These provisions will be in effect through May 
31, 2010.
    We recognize that, in some parts of the country, highway-grade 
diesel fuel is commonly sold into off-highway markets, due to 
limitations in the distribution system for carrying one grade of 
diesel. We do not want to preclude this practice in the future; thus, 
we are not preventing 15 ppm diesel from being downgraded to off-
highway fuel. The downgrading restriction applies only to 15 ppm 
downgraded to 500 ppm highway diesel fuel. We do not anticipate 
increased instances of downgrading to off-highway diesel fuel relative 
to today, given the increase in the price differential between highway 
diesel and off-highway diesel fuel that will likely result from this 
program. Therefore, we do not believe it is necessary to impose a 
regulatory restriction on downgrading of 15 ppm highway diesel to off-
highway diesel.
    All parties in the distribution system downstream of the refinery 
gate are subject to this provision, except for those retailers that 
offer for sale and wholesale purchaser-consumers that use 15 ppm fuel 
(either as the only grade of diesel or in addition to 500 ppm diesel). 
In other words, the only retailers and wholesale purchaser-consumers 
that are subject to this requirement are those that offer for sale or 
use only 500 ppm diesel (but not 15 ppm diesel).
    Since all parties in the distribution system are required by other 
provisions in this final rule to maintain product transfer documents, 
which will indicate whether the diesel fuel meets the 15 ppm or 500 ppm 
standard as well as the volume of such fuel, we are not requiring new 
recordkeeping requirements beyond these to demonstrate compliance with 
these provisions. The parties will merely have to ensure that at the 
end of each year during the period the temporary compliance option is 
in effect that they comply with the 20 percent requirement based on the 
incoming and outgoing PTD records described in Section VII.E.5 below.
c. Diesel Fuel Pump Labeling
    As discussed in Section IV.A.2 above and in the Chapter IV of the 
RIA, we believe that clear information about the proper fuel to use and 
the consequences of misfueling will minimize the potential for 
misfueling of new-technology vehicles. Under our final fuel program 
approximately 75% of the fuel in each PADD will meet the 15 ppm 
standard during the first few years. We believe that this will ensure 
that the fuel will be widely available in every part of the United 
States. Moreover, within four years all highway diesel fuel will meet 
this standard. Under these circumstances we believe the potential for 
misfueling will be limited. Nevertheless, we did receive considerable 
comment expressing concerns over the potential for misfueling.
    In addition to the required labels on diesel fuel pumps described 
below, we believe that the use of unique nozzles, color-coded 
scuffguards, or dyes to distinguish the grades of diesel fuel may be 
useful in preventing accidental misfueling. While we are not finalizing 
any requirements today, we will plan to work with the vehicle 
manufacturers and representatives of the fuel industry and other 
interested stakeholders over the next several years to develop workable 
solutions that are consistent with current industry practices and other 
regulatory requirements.
    For any multiple-fuel program like the temporary compliance option 
adopted today, clearly labeling diesel fuel pumps is vital for end 
users to distinguish between the two grades of fuel. We received 
comments on the NPRM that concurred with our assessment in the proposal 
that pump labels, in conjunction with vehicle labels, would also have 
the effect of helping to help prevent misfueling of motor vehicles with 
high sulfur diesel fuel. Section VI.G. above describes the labels that 
manufactures will place on vehicle and information that will be 
provided to vehicle owners. Today's rule also adopts pump labeling 
requirements for retailers and wholesale purchaser-consumers similar to 
those we proposed, but with modifications to account for the 
availability of diesel fuel subject to the 500 ppm sulfur standard for 
use in pre-2007 motor vehicles. The text of the labels appears below; 
the specific requirements for label size and appearance are found in 
the regulatory language for this rule.
    For pumps dispensing 15 ppm diesel fuel, the label will read as 
follows:

LOW-SULFUR DIESEL FUEL

    Recommended for use in all diesel highway vehicles.
    Required for model year 2007 and later highway vehicles.
    For pumps dispensing 500 ppm diesel fuel the label will reads as 
follows:

HIGH-SULFUR DIESEL FUEL--WARNING

    May damage model year 2007 and later highway vehicles.
    Federal Law prohibits use in these vehicles.
    Finally, for pumps dispensing nonroad diesel fuel that are located 
at the same retail outlet as highway diesel fuel pumps, the label will 
read as follows:

NONROAD DIESEL FUEL--WARNING

    May damage highway vehicles.
    Federal Law prohibits use in any highway vehicle.

[[Page 5120]]

3. Use of Used Motor Oil in New Diesel Vehicles
    We understand that used motor oil is sometimes disposed of by 
blending it with diesel fuel for use as fuel in diesel vehicles. Such 
practices range from blending used motor oil directly into the vehicle 
fuel tank, to blending it into the fuel storage tanks, to blending 
small amounts of motor oil from the vehicle crank case into the fuel 
system as the vehicle is being operated. To the extent such practices 
could cause vehicles to exceed their emissions standards, the person 
blending the oil, or causing or permitting such blending, could be 
considered to be rendering emission controls inoperative in violation 
of Section 203 of the CAA and potentially liable for a civil penalty 
(Section 203(a)(3) of the Act, 42 U.S.C. 7522(a)(3)).
    Since current formulations of motor oil contain very high levels of 
sulfur, the addition of used oil to highway diesel fuel could 
substantially impair the sulfur-sensitive emissions control equipment 
expected to be used by engine manufacturers to meet the emissions 
standards in today's rule. Depending on how the oil is blended, it 
could increase the sulfur content of the fuel burned in the vehicle by 
as much as 200 ppm. As a result, we believe blending used oil into 
highway diesel fuel could render inoperative the emission control 
technology on the vehicle and potentially cause driveability problems.
    Therefore, today's rule prohibits any person from introducing or 
causing or allowing the introduction of used motor oil, or diesel fuel 
containing used motor oil, into the fuel delivery systems of vehicles 
manufactured in model year 2007 and later. The only exception to this 
is where the engine is explicitly certified to the emission standard 
with oil added and the oil is added in a manner consistent with the 
certification. Please refer to the Response to Comments document for a 
discussion of concerns raised by commenters on this issue.
4. Use of Kerosene in Diesel Fuel
    As we discussed in the NPRM, kerosene is commonly added to highway 
diesel fuel to reduce fuel viscosity in cold weather. Today's rule will 
not limit this practice. Consistent with the proposal, under today's 
rule, kerosene that is used, intended for use, or made available for 
use as or for blending with 15 ppm sulfur highway diesel fuel is itself 
required to be classified as ``motor vehicle diesel fuel'' and meet the 
15 ppm standard, as well as the standards for aromatics and cetane (see 
Section 80.2(y) of the regulatory language following this preamble). 
This classification for highway fuel use may be made by the fuel's 
refiner or may be made by a downstream party at the point when that 
party chooses to use the kerosene in its possession for highway fuel 
use.
    To help ensure that only distillates that comply with the 15 ppm 
highway diesel fuel standard are blended into 15 ppm highway diesel 
fuel, today's rule has adopted the proposed requirement that kerosene 
meeting the 15 ppm standard and distributed by the transferring party 
for use in motor vehicles, must be accompanied by PTDs accurately 
stating that the product meets the 15 ppm sulfur standard (See Section 
VII.E.5. below).
    As a general matter, any party who blends kerosene, or any 
blendstock, into motor vehicle diesel fuel, or who produces motor 
vehicle diesel fuel by mixing blendstocks, is a refiner and would be 
subject the requirements and prohibitions applicable to refiners under 
the rule. However, under today's rule, in deference to the longstanding 
and widespread practice of blending kerosene into diesel fuel at 
downstream locations, downstream parties who only blend kerosene into 
motor vehicle diesel fuel will not be subject to the requirements 
applicable to refiners, provided that they do not alter the fuel in any 
other way. Further, downstream parties choosing to blend kerosene into 
15 ppm highway diesel fuel will be entitled to the 2 ppm adjustment 
factor for both the kerosene and the diesel fuel into which it is 
blended at downstream locations, provided that the kerosene had been 
transferred to the party with a PTD indicating compliance with that 
standard. Sulfur test results from downstream locations of parties who 
do not have such a PTD for their kerosene will not be subject to this 
adjustment factor, either for the kerosene itself, or for the highway 
diesel fuel into which it is blended.
    In order to ensure the continued compliance of 15 ppm fuel with the 
15 ppm standard, downstream parties choosing to blend kerosene into 15 
ppm highway diesel fuel are required by the final rule to either have a 
PTD for that kerosene indicating compliance with the 15 ppm standard, 
or to have test results for the kerosene establishing such compliance.
    Any party who causes the sulfur level of 15 ppm highway diesel fuel 
to exceed 15 ppm by blending kerosene into highway diesel fuel, or by 
using high sulfur kerosene as highway diesel fuel, would be subject to 
liability for violating the sulfur standard. Similarly, parties who 
cause the sulfur level of 500 ppm highway diesel fuel to exceed that 
standard by blending kerosene into the fuel, would also be subject to 
liability.
    The rule does not require refiners or importers of kerosene to 
produce or import kerosene meeting the 15 ppm sulfur standard. However, 
we believe that refiners will produce low sulfur kerosene in the same 
refinery processes that they use to produce low sulfur highway diesel 
fuel, and that the market will drive supply of low sulfur kerosene for 
those areas where, and during those seasons when, the product is needed 
for blending with highway diesel fuel. Comments to the NPRM regarding 
this provision generally supported this approach.
5. Use of Diesel Fuel Additives
    Diesel fuel additives include corrosion inhibitors, cold-
operability improvers, and static dissipaters. Use of such additives is 
distinguished from the use of kerosene by the low concentrations at 
which they are used and their relatively more complex chemistry.\211\ 
We proposed that diesel fuel additives used in highway diesel fuel meet 
the same cap on sulfur content required for the fuel itself. Additive 
manufacturers commented \212\ that there was no need to impose a 15 ppm 
sulfur cap on such additives in order to effectively limit the sulfur 
content of finished diesel fuel. They asserted that imposing such a cap 
would result in unjustified costs and disruptions to the producers and 
users of diesel additives. Additive manufacturers also stated that for 
certain additives, such as static dissipaters needed to prevent 
explosion hazards at terminal facilities, there are currently no 
effective alternatives that comply with a 15 ppm cap on sulfur content.
---------------------------------------------------------------------------

    \211\ Diesel fuel additives are used at concentrations commonly 
expressed in parts per million. Diesel fuel additives can include 
specially-formulated polymers and other complex chemical components. 
Kerosene is used at much higher concentrations, expressed in volume 
percent. Unlike diesel fuel additives, kerosene is a narrow 
distillation fraction of the range of hydrocarbons normally 
contained in diesel fuel. See Section VII.C.4 above regarding the 
requirements associated with the addition of kerosene to diesel 
fuel.
    \212\ See comments of the American Chemistry Council, Docket 
Item IV-D-183 in Docket A-99-06 associated with this rule.
---------------------------------------------------------------------------

    Additive manufacturers suggested an approach whereby shipments of 
additives that have a sulfur content above 15 ppm would be accompanied 
by a product transfer document (PTD) that includes information on 
additive sulfur content, maximum recommended treatment rate, and the 
potential impact

[[Page 5121]]

on the sulfur content of the fuel when the additive is used at the 
maximum recommended treatment rate. Under such an approach, they 
suggested that the use of diesel additives should be permitted to 
result in an increase in the sulfur content of the finished fuel of 
less than 0.5 ppm, such that fuel would effectively be required to meet 
a sulfur cap of 15.5 ppm.
    In response to these comments, we are allowing the use of diesel 
fuel additives with a sulfur content greater than 15 ppm. However, we 
believe that this can be accomplished without allowing the 15 ppm cap 
on fuel sulfur content to be exceeded. The 15 ppm cap is based on our 
understanding of the level that is necessary to ensure the durability 
and proper operation of the emissions control hardware that will be 
used to comply with the emissions standards in today's rule. We believe 
that it is most appropriate for the market to determine how best to 
accommodate increases in the fuel sulfur content from the refinery gate 
to the end user, while maintaining the 15 ppm cap, and whether such 
increases result from contamination in the distribution system or 
diesel additive use. By providing this flexibility, we anticipate that 
market forces will encourage an optimal balance between the competing 
demands of manufacturing fuel lower than the 15 ppm sulfur cap, 
limiting contamination in the distribution system, and limiting the 
additive contribution to fuel sulfur content.
    Our review of data submitted by additive and fuel manufacturers to 
comply with EPA's Fuel and Fuel Additive Registration requirements (40 
CFR Part 79) indicates that additives to meet every purpose (including 
static dissipation) are currently in common use which meet a 15 ppm cap 
on sulfur content (see Chapter IV.D. of the RIA for more information on 
additives). Since such low-sulfur additives are currently in use side-
by-side with high-sulfur additives, it is reasonable to conclude that 
there is not a significant difference in their cost. Even if not yet 
available for certain purposes, we believe that it is reasonable to 
assume that low-sulfur additives will become available before this rule 
is implemented in 2006. The ability of industry to provide low-sulfur 
additives is supported by the fact that diesel fuel meeting a 10 ppm 
cap on sulfur content has been marketed in Sweden for some time, and 
ARCO Petroleum recently began marketing fuel meeting a 15 ppm sulfur 
cap in California.
    The unusually high sulfur content of a few additives may discourage 
their use in diesel fuel that meets a 15 ppm sulfur cap. However, it 
will generally continue to be possible for additive manufacturers to 
market additives that contain greater than 15 ppm sulfur for use in 
highway diesel fuel. Such additives can also continue to be used in 
nonroad diesel fuel. Additive manufacturers that market such additives 
and blenders that use them in highway diesel fuel will have additional 
requirements to ensure that the 15 ppm sulfur cap on highway diesel 
fuel is not exceeded. Although today's rule may encourage the gradual 
retirement of additives that do not meet a 15 ppm sulfur cap for use in 
highway diesel fuel, we do not anticipate that this will result in 
disruption to additive users and producers or a significant increase in 
cost. Additive manufactures commonly reformulate their additives on a 
periodic basis as a result of competitive pressures. We anticipate that 
any reformulation that might need to occur to meet a 15 ppm sulfur cap 
will be substantially accommodated within this normal cycle.
    Today's rule limits the continued use in highway diesel fuel of 
diesel fuel additives that exceed 15 ppm sulfur to additives that are 
used at concentrations of less than one volume percent. We believe that 
this limitation is appropriate and will not cause any undue burden 
because the diesel fuel additives for which this flexibility was 
included are always used today at concentrations well below one volume 
percent. Further, one volume percent is the threshold above which the 
blender of an additive becomes subject to all the requirements 
applicable to a refiner (40 CFR 79.2(d)(1).
    The specific requirements in today's rule regarding the use of 
diesel fuel additives are as follows:

--Additives that have a sulfur content at or below 15 ppm must be 
accompanied by a PTD that states: ``The sulfur content of this additive 
does not exceed 15 ppm.''
--Additives that exceed 15 ppm sulfur may continue to be used in 
highway diesel fuel provided that they are used at a concentration of 
less than one volume percent and their transfer is accompanied by a PTD 
that lists the following:

    (1) The additive's maximum sulfur concentration
    (2) The maximum recommended concentration for use of the additive 
in diesel fuel, and
    (3) The contribution to the sulfur level of the fuel that would 
result if the additive is used at the maximum recommended 
concentration.
    Blenders of additives that exceed 15 ppm in sulfur content will be 
held liable if their actions cause the sulfur content of the finished 
fuel to exceed 15 ppm. In some cases, blenders may not find it feasible 
to conduct testing, or otherwise obtain information on the sulfur 
content of the fuel either before or after additive blending, without 
incurring substantial cost. We anticipate that blenders will manage the 
risk associated with the use of additives above 15 ppm in sulfur 
content under such circumstances with actions such as the following:

--Selecting an additive with minimal sulfur content above 15 ppm that 
is used at a low concentration, and
--Working with their upstream suppliers to provide fuel of sufficiently 
low sulfur content to accommodate the small increase in sulfur content 
which results from the use of the additive.

    This is similar to the way distributors will manage contamination 
from their distribution hardware (tank trucks, etc.). Distributors will 
not necessarily test for fuel sulfur content after each opportunity for 
contamination, but rather will rely on mechanisms set up to minimize 
the contamination, and to obtain fuel sufficiently below the standard 
to accommodate the increase in sulfur content from the contamination.
    The recordkeeping, reporting, and PTD provisions associated with 
these requirements are discussed in Section VII.E below. The liability 
provisions are discussed in Section VII.G below.

D. What Are the Testing and Sampling Methods and Requirements?

1. Diesel Fuel Testing Requirements and Test Methods
    As part of the diesel fuel sulfur program adopted today, EPA is 
designating the test method that we will use in determining compliance 
for samples collected at all points in the distribution system. This 
designated method is called ``Test Method for Total Sulfur in Liquid 
Aromatic Hydrocarbons and Their Derivatives by Oxidative Combustion and 
Electrochemical Detection,'' or ASTM D 6428-99.
    In the notice of proposed rulemaking, we proposed to designate ASTM 
D 2622-98 with minor modifications as the designated test method for 
quantifying the sulfur content of diesel fuel. This designated test 
method would be the one that EPA would utilize in its own laboratory in 
order to determine whether a given sample taken at any point in the 
distribution system is in compliance with the appropriate diesel sulfur 
standard or not. We proposed to apply this designated test method not

[[Page 5122]]

just to this final rule, which will be effective in 2006, but also to 
the existing diesel sulfur requirements, which are currently in effect. 
The modifications were designed to ensure appropriate precision at low 
sulfur levels below 15 ppm. Specifically, the modifications consisted 
of substitution of a measurement blank that more closely resembles the 
boiling point range and density of diesel fuel and a change to the 
calibration line to ensure that it goes through zero.\213\
---------------------------------------------------------------------------

    \213\ For a detailed description of the proposed modifications 
to ASTM D 2622-98, see 65 FR 35530-35531 (June 2, 2000).
---------------------------------------------------------------------------

    We received several comments related to the proposed test method. 
Some parties suggested further modifications to ASTM D 2622-98 and 
others recommended that we select ASTM D 5453-00 entitled, ``Standard 
Test Method for Determination of Total Sulfur in Light Hydrocarbons, 
Motor Fuels and Oils by Ultraviolet Fluorescence'' as the designated 
test method in the regulation. We have considered the comments 
carefully and agree that it is desirable to choose an accepted ASTM 
method as our designated test method. However, we do not believe that 
ASTM D 5453 is capable of measuring all sulfur containing compounds. 
Specifically, we do not believe that it will measure sulfonates, which 
are found in certain diesel additives typically added at terminals. 
Because of the stringent 15 ppm sulfur standard adopted today, the 
sulfonate compounds in these additives may become significant 
contributors to the overall sulfur level of the fuel.
    Under this final rule, there is no requirement for every-batch 
testing for refiners or importers. However, because the diesel sulfur 
standard will be enforced at all points in the fuel distribution 
system, we believe that refiners and importers will engage in such 
testing, because satisfactory test results may be used to form the 
basis for an affirmative defense in the event of a violation. 
Downstream fuel suppliers such as truck loading terminals that blend 
additives to highway diesel fuel may not find it practical to engage in 
testing every time they blend additives into diesel fuel. As described 
in the previous section, manufacturers of fuel additives will be 
required to provide appropriate information about how to blend the 
additive properly (the treatment rate) and will be required to retain 
samples of additive batches for the prescribed time period in order to 
demonstrate compliance with this regulation, as discussed in the 
previous section.
    We believe that there is more than one test method that may be used 
to determine the sulfur content of diesel fuel at low levels and 
believe that it is appropriate to allow alternative analytical test 
methods as long as they are correlated to the designated test method to 
be used by EPA. The ASTM methods that are allowed as alternative test 
methods under this rule are ASTM D 3120-96, ``Standard Test Method for 
Trace Quantities of Sulfur in Light Liquid Petroleum Hydrocarbons by 
Oxidative Microcoulometry.'' and ASTM D 4045-99, ``Standard Test Method 
for Sulfur in Petroleum Products by Hydrogenolysis and Rateometric 
Colorimetry.'' Furthermore, we will allow the use of the modified form 
of ASTM D 2622, which was proposed to be the designated test method, as 
an alternative test method. As stated above, results from the use of 
all alternative analytical test methods must be correlated to the 
designated test method.
    We believe that choosing an appropriate ASTM method as our 
designated test method for enforcement testing purposes and allowing 
the use of these alternative test methods furthers the purposes of the 
``National Technology Transfer and Advancement Act of 1995'' (NTTAA), 
section 12(d) of Public Law 104-113, and Office of Management and 
Budget (OMB) Circular A-119. Both of these documents are designed to 
encourage the adoption of standards developed by ``voluntary consensus 
bodies'' and to reduce reliance on government-unique standards where 
such consensus standards would suffice. In the future, we plan to adopt 
a performance based test method approach that would address the use of 
these alternative methods, including ``in-house'' test methods 
developed by individual refiners and importers. We also intend to 
continue working with the industry and ASTM in the future to develop 
and improve sulfur test methods, and will consider modifications to 
today's rule as developments warrant.
    We also received comments indicating that there would not be any 
field test equipment for 15 ppm diesel fuel available by 2006. With 
regard to field testing, we believe that the technology that will 
enable the development of appropriate equipment or modifications to 
existing equipment exists or will be developed in response to the 
requirements of this rule.
    In the NPRM, we discussed a comment received in response to the 
ANPRM that ASTM D 2622-98 may not be suitable for determining the 
sulfur content of biodiesel fuel, or mixtures of biodiesel and 
conventional diesel fuel. In response to the NPRM, we received comment 
indicating that significant modifications would be required to ASTM D 
2622-98 in order to adapt it for use with biodiesel and biodiesel 
blends. We believe the selected method, ASTM D 6428-99, is appropriate 
for use with biodiesel and biodiesel blends. However, depending on the 
product, any of the test methods allowed by this rule may require some 
adaptation by the operator.
    The test method for determination of sulfur in motor oil is ASTM D 
4297-96, entitled, ``Standard Test Methods for Elemental Analysis of 
Lubricant and Additive Components--Barium, Calcium, Phosphorus, Sulfur, 
and Zinc by Wavelength-Dispersive Fluorescence Spectroscopy.'' This 
method uses the same apparatus as ASTM D 2622-98, but includes specific 
methodology to compensate for interferences caused by additives present 
in motor oil. Consistent with the goals of the NTTAA and OMB Circular 
A-119, and in order to provide greater flexibility for regulated 
parties, we recognize that ASTM D 5453-00 may be selected by regulated 
parties as an appropriate alternative analytical test method for the 
purpose of measuring sulfur in motor oil.
2. Diesel Fuel Sampling Methods
    The final rule adopts the proposed sampling methods. There were no 
negative comments regarding these technical changes. The requirement to 
use these methods is effective June 1, 2001. These same methods were 
adopted for use in the Tier 2/Gasoline Sulfur rule.31\214\ These 
sampling methods are ASTM D 4057-95 (manual sampling) and D 4177-95 
(automatic sampling from pipelines/in-line blending). We are requiring 
the use of these ASTM methods instead of the methods currently provided 
in 40 CFR part 80, Appendix G, for determining compliance under both 
the new 15 ppm sulfur standard, and the 500 ppm standard currently in 
place. That is because these methods have been updated by ASTM, and the 
updates have provided clarification and have eliminated certain 
requirements that are not necessary for sampling petroleum products 
such as diesel fuel.
---------------------------------------------------------------------------

    \214\ 65 FR 6833-34 (Feb. 10, 2000). These methods are also 
proposed for use under the RFG and CG rules. See 62 FR 37337 et seq. 
(July 11, 1997).

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[[Page 5123]]

E. What Are the Recordkeeping, Reporting and Product Transfer Document 
Requirements?

1. Registration of Refiners and Importers
a. All Refiners and Importers
    By December 31, 2001, refiners and importers that may produce or 
supply highway diesel fuel by 2006 must register with EPA. 
Specifically, refiners and importers that are either currently 
producing or supplying highway diesel fuel, or that expect to do so by 
June 1, 2006, must register. The registration must include the 
following information:

--Corporate name and address of the refiner or importer and any parent 
companies and a contact person
--Name and address of all refineries or import facilities (including, 
for importers, the port of entry and PADD)
--A contact person.
--Location of records
--Business activity (refiner or importer)
--Capacity of each refinery in barrels of crude oil per calendar day

b. Prospective Small Refiners
    In addition to the basic registration requirements above, a refiner 
seeking status as a small refiner needs to apply for this status as a 
part of their registration and provide the average number of employees 
for all pay periods from January 1, 1999 to January 1, 2000, for the 
company, all parent companies, and all subsidiaries or joint ventures. 
The application also must include which small refiner option the 
refiner expects to use at each of its refineries.
c. Refiners Seeking an Extension of the GPA Gasoline Sulfur Standards
    In addition to the basic registration requirements above, a refiner 
or importer seeking an extension of the special GPA gasoline sulfur 
standards (see Section IV.B above) must apply for such an extension in 
their registration.
2. Pre-Compliance Reports
a. All Refiners
    As discussed in Section IV above, by June 1, 2003, all refiners and 
importers must report to EPA on their progress toward compliance with 
the highway diesel fuel sulfur standards adopted today. Subsequently, 
these pre-compliance reports are also due on June 1 of 2004 and 2005. 
EPA will maintain the confidentiality of information submitted in pre-
compliance reports. We will present generalized data from the reports 
on a PADD basis in annual reports following the receipt of each year's 
pre-compliance reports. These reports are for information purposes only 
and, while refiners must truthfully report on their projected plans in 
order for this provision to have any value, we will not hold refiners 
liable if their actual actions deviate from these reports. We fully 
expect that refiners' plans may change, which is why we are requiring 
these reports to be updated annually through 2005.
    In their pre-compliance reports, refiners and importers need to 
include the following information:

--Any changes in their basic corporate or facility information since 
registration.
--Estimates of the volumes (in gallons) of 15 ppm fuel and, if 
applicable, 500 ppm fuel to be produced from crude oil in each 
refinery, as well as the volumes of each grade of highway diesel fuel 
produced from other sources.
--For entities expecting to participate in the credit program, 
estimates of numbers of credits to be earned and/or used.
--Information regarding engineering plans (e.g., design and 
construction), the status of obtaining any necessary permits, and 
capital commitments for making the necessary modifications to produce 
low sulfur highway diesel fuel, and actual construction progress. The 
pre-compliance reports due in 2004 an 2005 must provide an update of 
the progress in each of these areas.
b. Small Refiners
    In addition to the information required for all refiners above, 
small refiners must provide additional information in their pre-
compliance reports. The information required varies according to which 
small refiner option the refiner plans to use, as discussed in Section 
IV.C above. The following paragraphs summarize the supplementary 
information required for each small refiner option.

500 ppm Option

    The pre-compliance report for a refiner planning use the 500 ppm 
Option must make a showing that sufficient sources of 15 ppm fuel will 
likely exist in the area. If after 2003 the sources of 15 ppm fuel 
decrease, the pre-compliance reports for 2004 and/or 2005 must identify 
this change and must include a supplementary showing that the sources 
of 15 ppm fuel are still sufficient.

Small Refiner Credit Option

    Pre-compliance reporting for small refiners choosing this Small 
Refiner Credit option is identical to that for the 500 ppm option (that 
is, if the small refiner is also producing 500 ppm highway diesel 
fuel), with the additional requirement that the refiner also report on 
any credits it expects to generate and sell.

Diesel/Gasoline Compliance Date Option

    Pre-compliance reports from any small refiners expecting to use the 
Diesel/Gasoline Compliance Date Option must provide information showing 
that diesel desulfurization plans are on track. In addition to the 
information about the expansion of desulfurization capacity required 
above for all refiners, the pre-compliance reports for small refiners 
expecting to use this option need to reasonably show that the refiner 
will be in a position by June 1, 2006 to produce of 100 percent of the 
refiners highway diesel fuel at 15 ppm sulfur at a volume at least 85 
percent of its baseline highway diesel volume.
c. GPA Refiners
    As with small refiners expecting to use the Diesel/Gasoline 
Compliance Option above, pre-compliance report from any refiners or 
importers expecting to use the extension of the GPA gasoline sulfur 
standards must provide information showing that diesel desulfurization 
plans are on track. In addition to the information about the expansion 
of desulfurization capacity required above for all refiners, the pre-
compliance reports for prospective GPA refiners need to reasonably show 
that the refiner will be in a position by June 1, 2006 to produce of 
100 percent of the refiners highway diesel fuel at 15 ppm sulfur at a 
volume at least 85 percent of its baseline highway diesel volume.
3. Annual Compliance Reports
a. All Refiners
    After the highway diesel sulfur requirements begin June 1, 2006, 
refiners and importers will be required to submit annual compliance 
reports that demonstrate compliance with the requirements of this final 
rule. The first annual compliance report will be due by the end of 
February 2007 (for the period of June 1, 2006 through December 31, 
2006) and would be required annually through February 2011. A refiner's 
annual compliance reports must include the following information, for 
each refinery:

--The volumes of 15 ppm and 500 ppm sulfur highway diesel fuel produced 
from crude oil during the compliance period, as well as the volumes of 
each grade of highway diesel fuel produced from other sources.

[[Page 5124]]

--The number of credits, if any, used to demonstrate compliance with 
the 80 percent requirement for 15 ppm sulfur fuel, and their source(s).
--The number of credits, if any generated.
b. Small Refiners
    As with pre-compliance reports, small refiners must supply 
additional information related to the small refiner option they are 
using in their annual compliance reports.

500 ppm Option and Small Refiner Credit Option

    In their annual compliance reports, small refiners choosing the 500 
ppm Option or the Small Refiner Credit Option need to show that the 
volume they produce of highway diesel fuel meeting the 500 ppm sulfur 
standard meets the lesser of the following values: (1) 105 percent of 
the average highway diesel volume it produced in calendar years 1998 
and 1999 or (2) the average highway diesel volume it produced from 
crude oil in calendar years 2004 and 2005.

Diesel/Gasoline Compliance Date Option

    A small refiner using this option needs to confirm in each annual 
compliance report that it continues to produce 100 percent of its 
highway diesel fuel at 15 ppm sulfur and that its highway diesel volume 
continues to be at least 85 percent of its baseline volume.
4. Initial Confirmation of 15 ppm Fuel Production
    Small refiners using the Diesel/Gasoline Compliance Date Option and 
refiners using the extension of the GPA gasoline sulfur standard must 
confirm to EPA by July 1, 2006 that they began on June 1, 2006 
producing 100 percent of their highway diesel fuel at 15 ppm sulfur.
5. Product Transfer Documents (PTDs)
a. Diesel Fuel
    We are adopting the proposed requirements that refiners and 
importers provide information on commercial PTDs that identifies diesel 
fuel distributed for use in motor vehicles and that states the fuel 
complies with the 15 ppm sulfur standard. Since today's rule adopts 
provisions for production and sale of diesel fuel having a sulfur 
content of 500 ppm for use in pre-2007 model year vehicles, the rule 
also adopts provisions requiring PTDs to identify such fuel and state 
that its use in motor vehicles is limited to pre-2007 motor 
vehicles.\215\ We believe this additional information on commercial 
PTDs is necessary because of the importance of preventing commingling 
of highway diesel fuel with high sulfur distillate products, avoiding 
contamination of 15 ppm highway diesel fuel with 500 ppm highway diesel 
fuel, and preventing misfueling of model year 2007 and later vehicles 
with any fuel having a sulfur content greater than 15 ppm. In addition, 
we are requiring that each PTD include the volume of fuel delivered 
(for each grade, 15 ppm and 500 ppm), that is necessary to demonstrate 
compliance with the fuel downgrading restrictions discussed in Section 
VII.C.2.b above.
---------------------------------------------------------------------------

    \215\ Such fuel can also be used in nonroad vehicles, whose fuel 
is currently unregulated.
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    Except for transfers to truck carriers, retailers and wholesale 
purchaser-consumers, product codes may be used to convey the 
information. More explicit language on PTDs to these parties is 
necessary since employees of such parties are less likely to be aware 
of the meaning of product codes. PTDs are not required for transfers of 
product into motor vehicles at retail outlets or wholesale purchaser-
consumer facilities.
    To assure that downstream parties can determine whether kerosene, 
or other distillates, distributed for use for blending into highway 
diesel fuel to reduce viscosity in cold weather meets the 15 ppm sulfur 
standard, today's rule adopts the proposed requirement for PTD 
identification of distillates distributed for such use as meeting the 
15 ppm standard.
    Today's rule adopts the proposal to retain the current diesel 
rule's PTD requirement regarding the identification of dyed, tax-exempt 
highway diesel fuel. This provision is useful for wholesale purchaser-
consumers that need to know that the diesel fuel they purchase is 
appropriate for tax exempt motor vehicle use despite the presence of 
red dye.\216\
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    \216\ The federal tax code requires the use of red dye in both 
off-highway distillate fuels and in highway diesel fuel sold for tax 
exempt use.
---------------------------------------------------------------------------

b. Additives
    The NPRM proposed that PTDs for additives for use in highway diesel 
fuel would be required to state that the additive complies with the 15 
ppm sulfur standard. Today's rule has been modified to allow the sale 
of additives, for use by fuel terminals or other parties in the diesel 
fuel distribution system, that have a sulfur content greater than 15 
ppm under specified conditions. As a result, under today's rule the PTD 
provisions for such additives are modified as follows:
    For additives that have a sulfur content not exceeding 15 ppm, the 
PTD must state: ``The sulfur content of this additive does not exceed 
15 ppm.''
    For additives that may have a sulfur content exceeding 15 ppm, the 
additive manufacturer's PTD, and PTDs accompanying all subsequent 
transfers, must provide: a warning that the additive's sulfur content 
exceeds 15 ppm; the maximum sulfur content of the additive; the 
appropriate amount of additive to blend to highway diesel fuel, stated 
as gallon of additive per gallon of diesel fuel; and the increase in 
sulfur concentration of the fuel the additive will cause when used at 
the specified concentration.
    The proposed provisions for consumer additives for use in diesel 
motor vehicles are slightly modified in the final rule due to concerns 
that additives designed for nonroad engines could accidentally be 
introduced into motor vehicle engines if they have no label stating 
appropriate use. Under today's rule consumer additives for use in any 
diesel engines must be accompanied by information that states that the 
additive either: complies with the sulfur content requirements for 
diesel motor vehicles; or that it has a sulfur content exceeding 15 ppm 
and is not for use in model year 2007 or later motor vehicles. This 
information is necessary for consumers to determine if an additive is 
appropriate for diesel motor vehicle use.
6. Recordkeeping Requirements
    Refiners that produce (or importers that import) both 500 ppm 
highway diesel fuel and 15 ppm highway diesel fuel under the temporary 
compliance option or any hardship program, or that produce only 15 ppm 
sulfur content diesel fuel and that wish to generate credits (including 
early credits), must maintain records for each batch of highway diesel 
fuel produced, of the batch designations and the batch volumes. The 
refiner must maintain records regarding credit generation, use, 
transfer, purchase, or termination.
    In general, refiners and importers participating in the temporary 
compliance option or any hardship program must keep records of the 
following information, as applicable for each refinery (and in the case 
of foreign refiners, separately by refinery and by PADD of import), or 
for importers, for each PADD:

--The total volume of highway diesel fuel produced or imported;

[[Page 5125]]

--The total volume of highway diesel fuel produced or imported meeting 
the 500 ppm; sulfur standard;
--The total volume of highway diesel fuel produced or imported meeting 
the 15 ppm sulfur standard;
--For small refiners or GPA refiners using the gasoline sulfur program 
extensions, a statement of the baseline volume and whether the volume 
of 15 ppm produced or imported fuel is at least equal to 85 percent of 
the baseline volume;
--The percentage of highway diesel fuel produced or imported meeting 
the 15 ppm sulfur standard before inclusion of credits;
--The volume of 15 ppm highway diesel fuel represented by credits;
--The percentage of 15 ppm highway diesel fuel produced or imported 
that is represented by credits;
--The number of credits in the refinery's or importer's possession at 
the beginning of the compliance period, separately by early credits and 
all other credits;
--The number of credits generated during the compliance period;
--The number of credits used, separately by early credits and all other 
credits;
--If any credits were obtained from or transferred to other parties, 
for each other party, its name, its EPA refiner or importer 
registration number, and the number of credits obtained from or 
transferred to the other party, provided separately for early credits 
and all other credits;
--The percentage of compliance with the 15 ppm motor vehicle diesel 80 
percent volume requirement by use of credits (provided separately for 
early credits and all other credits);
--The number of credits that will carry over to the next averaging 
period, provided separately for early credits and all other credits;
--Records regarding test results, including mandatory quality assurance 
tests; and
--Contracts or other commercial documents that establish each transfer 
of credits.

    Refiners approved for temporary hardship relief due to extreme 
unforseen circumstances or extreme financial hardship must include 
certain information in their application for relief. The required 
information, and the factors we will consider in determining what 
relief, if any, is appropriate, are discussed in Section IV.B.3. Such 
refiners will also have reasonable recordkeeping and reporting 
requirements, which will be fashioned on a case-by-case basis depending 
on the nature of any temporary waiver approved.
7. Record Retention
    Today's rule adopts the NPRM proposal that the retention period for 
all records required to be kept by the rule is 5 years. This is the 
same period of time required in other fuels rules, and it coincides 
with the applicable statute of limitations. We believe that for other 
reasons, most parties in the distribution system would maintain some or 
all of these records for this length of time even without the 
requirement.
    This retention period applies to PTDs, records of any test results 
performed by any regulated party for quality assurance purposes or 
otherwise, along with supporting documentation such as date of sampling 
and testing, batch number, tank number, and volume of product. Business 
records regarding actions taken in response to any violations 
discovered are also required to be maintained for 5 years.
    All records required to be maintained by refiners participating in 
the temporary compliance option or hardship options (or by importers of 
diesel fuel produced by a foreign refiner approved for the temporary 
compliance option or a hardship option), including small refiner and 
farmer cooperative and GPA options, are also covered by the retention 
requirement.

F. Are There Any Exemptions From the Highway Diesel Fuel Requirements?

1. Research and Development
    Today's rule exempts from the sulfur standards diesel fuel used for 
research, development and testing purposes (R & D), as was proposed in 
the NPRM. We recognize that there may be legitimate research programs 
that require the use of highway diesel fuel with higher sulfur levels 
than allowed under today's proposed rule. As a result, today's rule 
contains provisions for obtaining an exemption from the prohibitions 
for persons distributing, transporting, storing, selling, or dispensing 
highway diesel fuel that exceeds the standards, where such diesel fuel 
is necessary to conduct a research, development, or testing program.
    Under the rule, parties seeking an R&D exemption are required to 
submit to EPA an application for exemption that describes the purpose 
and scope of the program and the reasons that the use of the higher-
sulfur diesel fuel is necessary. Upon presentation of the required 
information, an exemption may be granted at the discretion of the 
Administrator, with the condition that EPA may withdraw the exemption 
ab initio in the event the Agency determines the exemption is not 
justified. Fuel subject to this exemption is exempt from the other 
provisions of today's rule, provided certain requirements are met. 
These requirements include the segregation of the exempt fuel from non-
exempt highway diesel fuel, identification of the exempt fuel on 
product transfer documents, pump labeling, and where appropriate, the 
replacement, repair, or removal from service of emission systems 
damaged by the use of the high sulfur fuel.
2. Racing Vehicles
    Today's rule adopts the NPRM proposal to provide no exemption from 
the sulfur content standard and other requirements of today's rule for 
diesel fuel used in racing vehicles. In the NPRM, we requested comment 
on whether such an exemption is needed and we received no comments 
supporting the need for such exemption. As we stated in the NPRM, we 
see no advantage for racing vehicles to use fuel having higher sulfur 
levels (or lower cetane or higher aromatic levels) than are required by 
today's rule, and we are concerned about the potential for misfueling 
of motor vehicles that could result from having a high sulfur (e.g., 
3,000 ppm) automotive fuel available in the marketplace. Consequently, 
the rule does not provide an exemption from the highway diesel fuel 
requirements for vehicles used in racing.
3. Military Fuel
    Based on EPA's existing definition of diesel fuel, we previously 
concluded that JP-8 military fuel is not subject to EPA's existing 
requirements for diesel fuel. Today's rule revises the definition of 
diesel fuel so that JP-5 and JP-8 military fuel that is used or 
intended for use in highway diesel motor vehicles will be subject to 
all of the requirements applicable to diesel fuel under today's 
rule.\217\ However, today's rule also exempts JP-5 and JP-8 fuels from 
EPA's diesel fuel requirements if it is used in tactical military 
vehicles that have a national security exemption or if it is used in 
tactical military vehicles that are not covered by a national security 
exemption but for national security reasons, such as the need to be 
ready for immediate deployment overseas, need to be fueled on the same 
fuel as motor

[[Page 5126]]

vehicles with a national security exemption. Use of JP-5 and JP-8 fuel 
not meeting the highway diesel fuel standards in a motor vehicle other 
than the tactical military vehicles described above is prohibited under 
today's rule.
---------------------------------------------------------------------------

    \217\ Any JP-5, JP-8, or other distillate product that is not 
designated by the refiner or importer as motor vehicle diesel fuel, 
and that does not otherwise meet the definition of motor vehicle 
diesel fuel, would not be included by the refiner or importer in any 
computation of motor vehicle diesel fuel volume for baseline or 
other purposes.
---------------------------------------------------------------------------

    Due to national security considerations, EPA's existing regulations 
allow the military to request and receive national security exemptions 
(NSE) for their motor vehicles from emissions regulations if the 
operational requirements for such vehicles warrant such an exemption. 
These provisions have worked successfully in the past to enable us to 
meet both our national air quality and security goals simultaneously. 
Today's rule does not change these provisions.
    In discussions with the Department of Defense (DOD), DOD stated 
that certain tactical military vehicles must be ready to be shipped 
overseas quickly in response to an emergency and must be ready to be 
fueled on whatever fuel is available under tactical conditions 
(typically JP-8). To avoid problems experienced in the past when 
switching between fuel types in tactical vehicles, JP-8 has been 
selected as the common tactical fuel for use by the military in the 
U.S. and overseas. Thus, the use of the high sulfur fuel, which is 
normally supplied overseas under tactical situations, is expected to 
continue after the implementation of this rule. However, use of the 
high sulfur fuel in these engines equipped with the aftertreatment 
technology, necessary to meet the emissions requirements of today's 
rule could result in engine failure, driveability problems, and 
permanently destroy the emission control system.
    Therefore, it appears that requiring tactical military vehicles 
that may be used outside of the U.S. to comply with the emissions 
requirements in today's rule is not compatible with the operational 
requirements for such vehicles. In their comments on the proposed rule, 
DOD stated that it would be appropriate for EPA to cover the tactical 
military vehicles that would otherwise be subject to the emissions 
regulations in today's rule under a national security exemption. We 
recognize the national security concerns raised by DOD, and will 
address this issue using the Agency procedures established for this 
purpose.\218\ These guidelines are contained in EPA's ``Guidelines for 
National Security Exemptions of Motor Vehicles and Motor Vehicle 
Engines--Guidelines for Tactical Vehicles/Engines.''
---------------------------------------------------------------------------

    \218\ These guidelines are contained in EPA's ``Guidelines for 
National Security Exemptions of Motor Vehicles and Motor Vehicle 
Engines--Guidelines for Tactical Vehicles/Engines''
---------------------------------------------------------------------------

    We also recognize that there are tactical military vehicles 
manufactured before the requirements of today's rule become effective 
that for national security purposes need to continue to be operated on 
JP-5 or JP-8 fuel while in the U.S. to facilitate their readiness to be 
fueled on whatever fuel is available overseas. Consistent with an 
exemption for certain military vehicles, EPA is also exempting diesel 
fuel from the sulfur standard in this rule, where the fuel is used in 
vehicles exempted from the emissions standards in this rule (pursuant 
to 40 CFR 85.1708) or in tactical motor vehicles that are not covered 
by a national security exemption but for national security reasons need 
to be fueled on the same fuel as motor vehicles with a national 
security exemption. To more clearly identify the tactical motor 
vehicles to be covered by the diesel fuel exemption the Department of 
Defense will submit a notification to EPA describing the rationale and 
supporting data for the request and a description of the covered 
tactical motor vehicles. The one-time notification should be sent to 
EPA by December 15, 2003 in order to provide sufficient time for EPA to 
review the information as well as lead time to the Department of 
Defense for logistics planning purposes. EPA will then respond to DOD 
identifying all vehicles that are covered by the fuel exemption. Based 
on data provided by the Department of Defense to date, EPA believes 
that providing an exemption for JP-5 and JP-8 fuel used in tactical 
motor vehicles does not have any significant environmental impact.

G. Liability and Penalty Provisions for Noncompliance

1. General
    The liability and penalty provisions of the diesel sulfur rule are 
similar to the liability and penalty provisions found in the gasoline 
sulfur rule, RFG rule and other EPA fuels regulations.\219\ Regulated 
parties are subject to prohibitions which are typical in EPA fuels 
regulations, such as selling or distributing fuel that does not comply 
with the standard, and causing others to commit prohibited acts. 
Liability also arises under the diesel rule for prohibited acts 
specific to the diesel sulfur control program, such as introducing 
diesel fuel not meeting the 15 ppm sulfur standard into diesel motor 
vehicles of model year 2007 and later. In addition, parties will be 
liable for a failure to meet certain requirements, such as the 
recordkeeping, reporting, or PTD requirements, or causing others to 
fail to meet such requirements.
---------------------------------------------------------------------------

    \219\ See section 80.5 (penalties for fuels violations); section 
80.23 (liability for lead violations); section 80.28 (liability for 
volatility violations); section 80.30 (liability for diesel 
violations); section 80.79 (liability for violation of RFG 
prohibited acts); section 80.80 (penalties for RFG/CG violations); 
section 80.395 (liability for gasoline sulfur violations); section 
80.405 (penalties for gasoline sulfur regulations).
---------------------------------------------------------------------------

    Under today's rule, the party in the diesel fuel's distribution 
system that controls the facility where the violation occurred, and 
other parties in that fuel's distribution system (such as the refiner, 
reseller, and distributor), are presumed to be liable for the 
violation.\220\ As in the Tier 2 gasoline sulfur rule (``Tier 2 sulfur 
rule''), today's diesel sulfur rule explicitly prohibits causing 
another person to commit a prohibited act or causing non-conforming 
diesel fuel to be in the distribution system. Non-conforming means: (1) 
Diesel fuel with sulfur content above 15 ppm incorrectly designated as 
appropriate for model year 2007 and above motor vehicles or (2) diesel 
fuel with sulfur content above 500 ppm incorrectly designated as 
appropriate for any model year motor vehicle. Parties outside the 
diesel fuel distribution system, such as diesel additive manufacturers 
and distributors, would also be subject to liability for those diesel 
rule violations which could have been caused by their conduct.
---------------------------------------------------------------------------

    \220\ An additional type of liability, vicarious liability, is 
also imposed on branded refiners under these fuels programs.
---------------------------------------------------------------------------

    Affirmative defenses are provided for each party deemed 
presumptively liable for a violation, and all presumptions of liability 
are rebuttable. In general, in order to rebut the presumption of 
liability, parties are required to establish that: (1) The party did 
not cause the violation; (2) PTD(s) exist which establish that the fuel 
or diesel additive was in compliance while under the party's control; 
and (3) the party conducted a quality assurance sampling and testing 
program. Diesel fuel refiners, diesel fuel additive manufacturers, and 
blenders of high sulfur additives into diesel fuel, would also be 
required to provide test results establishing the conformity of the 
product prior to leaving that party's control.\221\ Branded

[[Page 5127]]

refiners have additional affirmative defense elements to establish. The 
defenses under the diesel sulfur rule are similar to those available to 
parties for violations of the RFG, volatility, and the Tier 2 sulfur 
regulations. Today's final rule also clarifies that parent corporations 
are liable for violations of subsidiaries, in a manner consistent with 
the Tier 2 sulfur rule. Finally, the final diesel sulfur rule mirrors 
the Tier 2 sulfur rule by clarifying that each partner to a joint 
venture will be jointly and severally liable for the violations at the 
joint venture facility or by the joint venture operation.
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    \221\ The requirement of conforming test results was not 
included in the NPRM as an affirmative defense element for the fuel 
refiner. However, under both the NPRM and today's final rule, 
refiners need to establish that they didn't cause the violation. As 
a practical matter, refiners generally establish their lack of 
causation using such test results. The Agency believes that it is 
nonetheless important to require these test results as an 
affirmative defense element for refiners because under today's final 
rule, refiners are given the ability to produce high sulfur highway 
diesel fuel as well as low sulfur product. This makes the 
possibility of refiner causation of violations much more likely, and 
the production of conforming test results--the one most convincing 
piece of evidence which would establish the refiner's lack of 
causation--much more essential. Further, conducting such testing 
should not be a significant burden for refiners to comply with. 
Refiners typically already test their batches to assure component 
quality for commercial reasons, and refiners are usually the party 
in the distribution system with the most resources--both financial 
and analytical--to conduct quality testing. In any case, refiners 
may choose not to conduct this testing, since it is merely an 
affirmative defense element, and the tests would only become 
relevant once a violation is discovered.
---------------------------------------------------------------------------

    As is the case with the other EPA fuels regulations, today's final 
diesel sulfur rule applies the provisions of section 211(d)(1) of the 
Clean Air Act (Act) for the collection of penalties. These penalty 
provisions subject any person that violates any requirement or 
prohibition of the diesel sulfur rule to a civil penalty of up to 
$27,500 for every day of each such violation and the amount of economic 
benefit or savings resulting from the violation. A violation of a 
diesel sulfur cap standard constitutes a separate day of violation for 
each day the diesel fuel giving rise to the violation remains in the 
fuel's distribution system. Under the regulation, the length of time 
the diesel fuel in question remains in the distribution system is 
deemed to be twenty-five days unless there is evidence that the fuel 
remained in its distribution system a lesser or greater amount of 
time--the same time presumption that is incorporated in the RFG and 
Tier 2 sulfur rules. The penalty provisions are similar to the penalty 
provisions for violations of the RFG and the Tier 2 sulfur regulations.
    EPA has included in today's rule two prohibitions for ``causing'' 
violations: (1) Causing another to commit a violation; and (2) causing 
non-complying diesel fuel to be in the distribution system. These 
causation prohibitions are like similar prohibitions included in the 
Tier 2 gasoline sulfur regulations, and, as discussed in the preamble 
to that rule, EPA believes they are consistent with EPA's 
implementation of prior motor vehicle fuel regulations. See the 
liability discussion in the preamble to the Tier 2 final rule, at 65 FR 
6812 et seq.
    The prohibition against causing another to commit a violation would 
apply where one party's violation is caused by the actions of another 
party. For example, EPA may conduct an inspection of a terminal and 
discover that the terminal is offering for sale highway diesel fuel 
designated as complying with the 15 ppm sulfur standard, while it, in 
fact, had an actual sulfur content greater than the standard.\222\ In 
this scenario, parties in the fuel's distribution system, as well as 
parties in the distribution system of any diesel additive that had been 
blended into the fuel, would be presumed liable for causing the 
terminal to be in violation. Each party, of course, would have the 
right to present an affirmative defense to rebut this presumption.
---------------------------------------------------------------------------

    \222\ The violation would occur if EPA's test result showed a 
sulfur content of greater than 17 ppm, which takes into account the 
two ppm adjustment factor for testing reproducibility for downstream 
parties.
---------------------------------------------------------------------------

    The prohibition against causing non-complying diesel fuel to be in 
the distribution system would apply, for example, if a refiner 
transfers non-complying diesel fuel to a pipeline. This prohibition 
could encompass situations where evidence shows high sulfur diesel fuel 
was transferred from an upstream party in the distribution system, but 
EPA may not have test results to establish that parties downstream also 
committed violations with this fuel.
    The Agency intends to enforce the liability scheme of the diesel 
sulfur rule in the same manner that we have enforced the similar 
liability schemes in our prior fuels regulations. As in other fuels 
programs, we will attempt to identify the party most responsible for 
causing the violation in determining that party that should primarily 
be liable for penalties for the violation.
2. What Is the Liability That Additive Manufacturers and Distributors, 
and Parties That Blend Additives Into Diesel Fuel, Are Subject To?
a. General
    In the NPRM, the Agency did not propose that additive manufacturers 
or distributors would be presumed liable for any violations of the 
diesel regulation. Only parties that were in the diesel fuel 
distribution system were to be presumed liable for diesel fuel 
violations. Parties in the additive distribution system would only be 
subject to liability for fuels violations where the Agency established 
that they caused others (such as fuel distributors or retailers) to be 
in violation. This approach was followed because the NPRM prohibited 
the downstream blending into highway diesel fuel of any additive whose 
sulfur content exceeded the 15 ppm standard. This limitation reduced 
the potential that the additive could be the cause of sulfur non-
compliance in fuel within the diesel distribution system.
    Various additive manufacturers provided comments regarding the need 
for certain diesel fuel additives that may exceed the 15 ppm sulfur 
standard. Today's final rule, therefore, permits the blending of diesel 
additives with sulfur content in excess of 15 ppm into 15 ppm highway 
diesel fuel under limited circumstances, in response to those comments. 
As more fully discussed in section VII(C)(5) of this preamble, today's 
rule permits downstream parties to blend into 15 ppm highway diesel 
fuel additives having a sulfur content exceeding 15 ppm, provided that: 
(1) The blending of the additive does not cause the diesel fuel's 
sulfur content to exceed the 15 ppm sulfur standard; (2) the additive 
is added in an amount no greater than one volume percent of the blended 
product; and (3) the downstream party obtained from its additive 
supplier a product transfer document (``PTD'') with the additive's 
sulfur content and the recommended treatment rate, and that it complied 
with such treatment rate, as appropriate.
    Since the final rule permits the limited use in highway diesel fuel 
of additives with high sulfur content, the Agency believes it is now 
more likely that a diesel fuel sulfur violation could be caused by the 
use of high sulfur additives. This could result from the additive 
manufacturer's misrepresentation or inaccurate statement of the 
additive's sulfur content or recommended treat rate on the additive's 
PTD, or an additive distributor's contamination of low sulfur additives 
with high sulfur additives during transportation. The increased 
probability that parties in the additive distribution system could 
cause a violation of the sulfur standard warrants the imposition by the 
Agency of increased liability for such parties under the final rule. As 
one example of this, the final rule explicitly makes parties in the 
additive distribution system liable for the sale of nonconforming 
diesel fuel additives, even if such additives have not yet been blended 
into diesel fuel. In addition, the

[[Page 5128]]

final rule imposes presumptive liability on parties in the additive 
distribution system if diesel fuel into which the additive has been 
blended is determined to have a sulfur level in excess of its permitted 
concentration. This presumptive liability differs depending on whether 
the blended additive was designated as meeting the 15 ppm sulfur 
standard (a ``15 ppm additive'') or designated as a greater than 15 ppm 
sulfur additive (a ``high sulfur additive''), as discussed below.
b. Liability When the Additive Is Designated as Complying With the 15 
ppm Sulfur Standard
    With the sole exception of diesel additives blended into highway 
diesel fuel at a concentration no greater than one percent by volume of 
the blended fuel, any additive blended into diesel fuel downstream of 
the refinery must have a sulfur content no greater than 15 ppm, and 
must be accompanied by PTD(s) accurately identifying them as complying 
with the 15 ppm sulfur standard.
    All parties in the fuel and additive distribution systems are 
subject to presumptive liability if the blended fuel exceeds the sulfur 
standard (with the two ppm downstream adjustment applied when EPA tests 
the fuel subject to the 15 ppm sulfur standard). Low sulfur additives 
present a less significant threat to diesel fuel sulfur compliance than 
would occur with the use of additives designated as possibly exceeding 
15 ppm sulfur. Thus, parties in the additive distribution system of the 
low sulfur additive will be permitted to rebut the presumption of 
liability by showing the following: (1) Additive distributors will only 
be required to produce PTDs asserting that the additive complies with 
the 15 ppm sulfur standard (2) additive manufacturers will also be 
required to produce PTDs complying in an accurate manner with the 
regulatory requirements, as well as producing test results (or retained 
samples on which tests could be run) establishing the additive's 
compliance with the 15 ppm sulfur standard prior to leaving the 
manufacturer's control. Once their presumptive liability would be 
refuted by producing such documentation in a convincing manner, these 
additive system parties would only be held responsible for the diesel 
fuel non-conformity in situations in which EPA can establish that the 
party actually caused the violation.
    Under today's final rule, parties in the diesel fuel distribution 
system will have the typical presumptive liability defenses as 
proposed. For parties blending an additive into their diesel fuel, the 
requirement of producing PTDs showing that the product complied with 
the regulatory standards will necessarily include PTDs for the additive 
that was used, affirming the additive's compliance as well as the 
fuel's.
c. Liability When the Additive Is Designated as Having a Possible 
Sulfur Content Greater Than 15 ppm
    Under today's rule, if an additive manufacturer produces an 
additive for use in 15 ppm highway diesel fuel at a concentration no 
greater than one volume percent of the blended fuel, then the additive 
is permitted to have a maximum sulfur content above 15 ppm. However, if 
highway diesel fuel containing that additive is found by EPA to have 
high sulfur content, then all the parties in both the additive's and 
the fuel's distribution chain will be presumed liable for causing the 
diesel fuel violation. Since this type of high sulfur additive presents 
a much greater probability of causing diesel fuel non-compliance, 
parties in the additive's distribution system will have to satisfy an 
additional element to establish an affirmative defense. In addition to 
the elements of an affirmative defense described above, parties in the 
distribution system for such a high sulfur additive must also establish 
that they did not cause the violation, an element of an affirmative 
defense that is typically required in EPA fuel programs to rebut 
presumptive liability.
    Parties in the diesel fuel's distribution system will essentially 
have to establish the same affirmative elements as proposed, with one 
addition. Blenders of high sulfur additives into 15 ppm sulfur diesel 
fuel, by the act of blending such an additive into that fuel, subject 
themselves to the need for establishing a more rigorous quality control 
program than would exist without the addition of such a high sulfur 
addition. The Agency believes that parties blending high sulfur 
additives into their 15 ppm sulfur diesel fuel should be required to 
produce test results establishing that the blended fuel was in 
compliance with the 15 ppm sulfur standards after being blended with 
the high sulfur additive. This additional defense element is required 
as an added safeguard to ensure diesel fuel compliance, since the 
blender has voluntarily chosen to use an additive which increases the 
risk of diesel fuel non-compliance.

H. How Will Compliance With the Sulfur Standards Be Determined?

    In the NPRM, EPA proposed that compliance with the diesel sulfur 
standards would be determined based on the sulfur level of the diesel 
fuel, as measured using the regulatory testing methodology. We further 
proposed that any evidence from any source or location could be used to 
establish the diesel fuel sulfur level, provided that such evidence is 
relevant to whether the level would have been in compliance if the 
regulatory sampling and testing methodology had been correctly 
performed. In today's action, consistent with the approach taken under 
the Tier 2 sulfur rule, EPA is adopting the proposed regulatory 
provisions.
    The final regulations provide that the primary determinant of 
compliance with the standards will be the specified regulatory test 
method.\223\ Additionally, other information may be used under the 
rule, including test results using non-designated test methods, if the 
evidence is relevant to determining whether the sulfur level would meet 
applicable standards had compliance been determined using the specified 
test methodology. Moreover, since evidence other than regulatory test 
results must be relevant to compliance using the regulation test 
method, EPA believes that the rule enables parties to rely with 
confidence on the proper use of the regulatory method.
---------------------------------------------------------------------------

    \223\ Under today's final rule, several specified alternative 
test methods are also permitted, provided they have been properly 
correlated with the regulatory method.
---------------------------------------------------------------------------

    For example, the Agency might not have sulfur results derived from 
the regulatory test method for diesel fuel sold by a terminal, yet the 
terminal's own test results, based on testing using methods other than 
those specified and approved in the regulations, could reliably show an 
exceedence of the sulfur standard. Under today's rule, evidence from 
the non-regulatory test method could be used to establish the diesel 
fuel's sulfur level that would have resulted if the regulatory test 
method had been conducted. This type of evidence is available for use 
by either the EPA or the regulated party, and could be used to show 
either compliance or noncompliance. Similarly, absent the existence of 
sulfur test results using the regulation method, commercial documents 
asserting the sulfur level of diesel fuel or additive could be used as 
some evidence of that sulfur level if the product would have been 
tested using the regulatory method.\224\
---------------------------------------------------------------------------

    \224\ The ability to use such evidence is in addition to the 
presumption established under the final rule, that when a mandated 
product transfer document asserts that diesel fuel complies with the 
500 ppm sulfur standard, the fuel accompanied by that transfer 
document will be presumed to comply with the 500 standard and not to 
comply with the 15 ppm standard, unless the party can establish 
otherwise.

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[[Page 5129]]

    The Agency believes that the same statutory authority for EPA to 
adopt the Tier 2 sulfur rule's evidentiary provisions (Clean Air Act 
section 211(c)), provides appropriate authority for our adoption of the 
evidentiary provisions of today's diesel rule. For a fuller explanation 
of this statutory authority, see Section VI(I) of the Tier 2 final rule 
preamble, 65 FR 6815, February 10, 2000.

VIII. Standards and Fuel For Nonroad Diesel Engines

    Although this program covers only highway diesel engines and 
highway diesel fuel, our potential plans for nonroad diesel engines, 
and especially the sulfur content of nonroad diesel, fuel are clearly 
related. For example, depending on whether and how nonroad diesel fuel 
is regulated, factors including the costs, leadtime, environmental 
impacts, and impacts on competitive relationships in the marketplace 
associated with this program could be affected. We would need to 
address these factors in any future regulatory action on nonroad diesel 
fuel.
    Because of these factors, various stakeholders inquired during the 
public comment period about the potential requirements that could apply 
to nonroad diesel fuel. Several states, environmental organizations, 
and other commenters urged us to take action on nonroad because of the 
nonroad contribution to air quality problems. The remainder of this 
section summarizes the background behind this issue and our current 
thinking about the future regulation of nonroad diesel engines and 
fuel.
    After establishing an initial set of emission standards for nonroad 
diesel engines in 1994, we proposed in 1997, and finalized in 1998, a 
comprehensive program of emission standards for most diesel engines 
designed for nonroad use.\225\ This program established NMHC + 
NOX and PM standards that are phasing in over the 1999-2006 
time frame, with engines of different horsepower ranges coming into the 
program in different years. At the same time, we set long-term (``Tier 
3'') NMHC + NOX standards, but not PM standards, for medium 
and high horsepower engines, to begin in 2006. This rule also included 
a plan to reassess the Tier 3 NMHC + NOX standards and to 
establish a PM test cycle and associated standards in the 2001 time 
frame. In addition, the 1998 rule anticipated an EPA reassessment of 
the NMHC + NOX standards for the smaller engines (less than 
50 horsepower), which are to be phased in beginning in 2004 (referred 
to as nonroad ``Tier 2'' standards).
---------------------------------------------------------------------------

    \225\ See the final rule, 63 FR 56968, October 23, 1998 for more 
about the history of these regulations.
---------------------------------------------------------------------------

    We did not include regulations on nonroad diesel fuel in the first 
diesel fuel sulfur control program which was established in 1993 for 
highway diesel fuel. We estimate that the average sulfur content for 
nonroad diesel fuel is currently around 3000 ppm, \226\ as compared to 
the cap for highway diesel fuel of 500 ppm.\227\
---------------------------------------------------------------------------

    \226\ National Institute for Petroleum and Energy Research 
(NIPER) report, Diesel Fuel Oils, 1996.
    \227\ Information from recent national fuel surveys by NIPER and 
the Alliance of Automobile Manufacturers.
---------------------------------------------------------------------------

    We believe that any specific new requirements for nonroad diesel 
fuel would need to be carefully considered in the context of a proposal 
for further nonroad diesel engine emission standards. For the nonroad 
program, we expect to use the same systems-based approach as we used 
for the Tier 2/Gasoline Sulfur program and today's highway diesel fuel 
and heavy-duty engine standards program. This is because of the close 
interrelationship between fuels and engines--the best emission control 
solutions may not come through either fuel changes or engine 
improvements alone, but perhaps through an appropriate balance between 
the two. This is especially significant given that engine manufacturers 
and diesel fuel refiners would need to address potential challenges 
such as capital cost, leadtime, and engineering and construction 
resources, of simultaneously meeting the highway standards under this 
program with the nonroad standards that may be implemented. Thus we 
need to address issues in both the fuel and engine arenas together.
    The many issues connected with any rulemaking for nonroad engines 
and fuel warrant serious attention, and we believe it would be 
premature today for us to attempt to raise potential resolutions to 
them. We plan to initiate action in the future to formulate thoughtful 
proposals covering both nonroad diesel fuel and engines.

IX. Public Participation

    A wide variety of interested parties participated in the rulemaking 
process that culminates with this final rule. The formal comment period 
and five public hearings associated with the NPRM provided additional 
opportunities for public input. EPA also met with a variety of 
stakeholders, including environmental and public health organizations, 
oil company representatives, auto company representatives, emission 
control equipment manufacturers, and states at various points in the 
process.
    We prepared a detailed Response to Comments document that describes 
the comments received on the NPRM and presents our response to each of 
these comments. The Response to Comments document is available in the 
docket for this rule and on the Office of Transportation and Air 
Quality internet home page. Comments and our responses are also 
included throughout this preamble for several key issues.

X. Administrative Requirements

A. Administrative Designation and Regulatory Analysis

    Under Executive Order 12866 (58 FR 51735, October 4, 1993), the 
Agency is required to determine whether this regulatory action will be 
``significant'' and therefore subject to review by the Office of 
Management and Budget (OMB) and the requirements of the Executive 
Order. The order defines a ``significant regulatory action'' as any 
regulatory action that is likely to result in a rule that may:
     Have an annual effect on the economy of $100 million or 
more or adversely affect in a material way the economy, a sector of the 
economy, productivity, competition, jobs, the environment, public 
health or safety, or State, local, or tribal governments or 
communities;
     Create a serious inconsistency or otherwise interfere with 
an action taken or planned by another agency;
     Materially alter the budgetary impact of entitlements, 
grants, user fees, or loan programs or the rights and obligations of 
recipients thereof; or,
     Raise novel legal or policy issues arising out of legal 
mandates, the President's priorities, or the principles set forth in 
the Executive Order.
    Pursuant to the terms of Executive Order 12866, EPA has determined 
that this rule is a ``significant regulatory action'' because the 
engine standards, diesel fuel sulfur standards, and other regulatory 
provisions will have an annual effect on the economy in excess of $100 
million. Accordingly, we have prepared a Final Regulatory Impact 
Analysis (RIA) which is available in the docket for this rulemaking and 
at the internet address listed under ADDRESSES above. This action was 
submitted to the Office of Management and Budget (OMB) for review as 
required by Executive Order 12866. Written comments from OMB on today's 
action

[[Page 5130]]

and responses from EPA to OMB comments are in the public docket for 
this rulemaking.

B. Regulatory Flexibility Analysis

    EPA has decided to prepare a Final Regulatory Flexibility Analysis 
in connection with this final rule. For purposes of assessing the 
impact of today's rule on small entities, small entities are defined as 
described under section X.B.3 below.
    In accordance with section 603 of the RFA, EPA prepared an initial 
regulatory flexibility analysis (IRFA) for the proposed rule and 
convened a Small Business Advocacy Review Panel to obtain advice and 
recommendations of representatives of the regulated small entities in 
accordance with section 609(b) of the RFA (see 65 FR 35541, June 2, 
2000). A detailed discussion of the Panel's advice and recommendations 
is found in the Panel Report contained in the docket for this 
rulemaking. A summary of the Panel's recommendations is presented at 65 
FR 35541.
    We have also prepared a final regulatory flexibility analysis 
(FRFA) for today's final rule. The FRFA addresses the issues raised by 
public comments on the IRFA, which was part of the proposal of this 
rule. The FRFA is available for review in the docket and is summarized 
below.\228\ The key elements of the FRFA include:
---------------------------------------------------------------------------

    \228\ The Final RFA is contained in Chapter VIII of the RIA.

--The need for, and objectives of, the rule;
--The significant issues raised by public comments on the Initial RFA, 
a summary of the Agency's assessment of those issues, and a statement 
of any changes made to the proposed rule as a result of those comments;
--The types and number of small entities to which the rule will apply;
--The reporting, recordkeeping, and other compliance requirements of 
the rule, including the classes of small entities that will be affected 
and the type of professional skills necessary to prepare the report or 
record;
--The steps taken to minimize the significant impact on small entities 
consistent with the stated objectives of the applicable statute, 
including a statement of the factual, policy and legal reasons why the 
Agency selected the alternatives we did, and why other significant 
alternatives to the rule which affect the impact on small entities were 
rejected.

    We summarize the key elements of the FRFA below. A fuller 
discussion of each of these elements can be found in the FRFA (Chapter 
VIII of the RIA).
1. Need for and Objectives of the Rule
    Section I of this preamble provides a summary of the need for and 
objectives of this rule. As discussed in detail in Section II of this 
preamble, emissions from heavy-duty vehicles contribute greatly to a 
number of serious air pollution problems, and would have continued to 
do so into the future absent further controls to reduce these 
emissions. Although the air quality problems caused by diesel heavy-
duty vehicles are challenging, we believe they can be resolved through 
the application of high-efficiency emissions control technologies. 
Based on the Clean Air Act requirements discussed in Section I.B.3, we 
are setting stringent new emission standards that will result in the 
use of these diesel exhaust emission control devices (see Section III). 
We are also finalizing changes to diesel fuel sulfur standards in order 
to enable these high-efficiency technologies (Section IV). In 
consideration of the impacts that sulfur has on the efficiency, 
reliability, and fuel economy impact of diesel engine exhaust emission 
control devices, we believe that controlling the sulfur content of 
highway diesel fuel to the 15 ppm level is necessary, feasible and cost 
effective. The standards will result in substantial benefits to public 
health and welfare and the environment through significant reductions 
in emissions of nitrogen oxides, particulate matter, nonmethane 
hydrocarbons, carbon monoxide, sulfur oxides, and air toxics.
2. Summary of Significant Public Comments on the IRFA
    EPA received many comments from small refiners and others 
pertaining to the options for hardship relief described in the NPRM. In 
general, many small refiners commented on the financial difficulty 
their refinery would face in complying with the proposed diesel sulfur 
program, and encouraged EPA to provide hardship relief. Many small 
refiners acknowledged that there was not one single hardship relief 
option to best suit the needs of all small refiners, and thus supported 
a menu of options. Section IV.C of the preamble discusses the three 
hardship relief options available to small refiners under today's 
program. These three options are based on concepts which were 
considered by the SBAR Panel and on which we requested and received 
comment in the proposal. A summary of the comments pertaining to 
regulatory alternatives for small refiners, and our response to them, 
is contained in the Response to Comments document contained in the 
docket.
3. Types and Number of Small Entities
    Today's program, which establishes new emission standards for 
heavy-duty engines and new standards for the sulfur content of highway 
diesel fuel, will directly affect manufacturers of heavy-duty engines 
and petroleum refiners that produce highway diesel fuel, respectively. 
In addition, but to a lesser extent, the program will directly affect 
diesel distributors and marketers.
    We have not identified any manufacturers of heavy-duty engines that 
meet SBA's definition of a small business. However, we have identified 
several petroleum refiners that produce highway diesel fuel and meet 
the SBA's definitions for a small business for the industry category. 
According to the SBA's definition of a small business for a petroleum 
refining company (Standard Industrial Classification (SIC) 2911), which 
we have used for purposes of assessing the impact of today's rule on 
small entities, a company must have 1500 or fewer employees to qualify 
as an SBA small business. Of the approximately 158 refineries in the 
U.S. today, we estimate that approximately 24 refiners (owning 27 
refineries) would meet the SBA definition and produce highway diesel 
fuel. We estimate that these 24 refiners produce approximately five 
percent of highway diesel fuel nationwide.
    EPA also has identified several thousand businesses in the diesel 
distribution and marketing industry that meet SBA's definitions of 
small business. More information about these industries is contained in 
the Final RFA. The low sulfur diesel fuel rule contains certain 
downstream compliance and enforcement provisions, for all parties in 
the diesel fuel distribution system downstream of the refinery gate, to 
prevent (1) contamination of highway diesel fuels with fuels containing 
higher levels of sulfur and (2) misfueling of motor vehicles with high 
sulfur fuels.
    Under this rule, distributors and retailers may choose to handle 
500 ppm diesel fuel, 15 ppm diesel fuel, or both (as permitted under 
the temporary compliance option and small refiner hardship provisions 
described in the preamble). However, distributors and marketers will 
have to segregate low sulfur diesel fuel from other distillates just as 
they do today with 500 ppm diesel fuel. Retailers and wholesale 
purchaser-consumers will be responsible for ensuring that only low 
sulfur diesel fuel is sold for use in model year 2007 and later heavy-
duty

[[Page 5131]]

vehicles. Under the temporary compliance option for refiners and small 
refiner hardship provisions (described in Section IV), where two grades 
of highway diesel fuel are allowed for the initial years of the 
program, some distributors and marketers may voluntarily decide 
(presumably based on economics) to add tankage or make additional 
modifications to accommodate two grades of highway diesel fuel. We have 
taken such costs into account in our diesel fuel cost analysis 
(described in more detail in Chapter V of the RIA).
    The low sulfur diesel fuel rule also includes a product downgrading 
restriction that is designed to discourage the intentional downgrading 
of 15 ppm diesel fuel to 500 ppm diesel fuel in the distribution system 
during the initial years of the program when the optional compliance 
provision is in effect. This provision and its impacts on affected 
entities is discussed more in Section VII of this preamble and in the 
FRFA. This provision does not require any new recordkeeping or 
reporting requirements beyond those required of the rest of the 
program.
4. Reporting, Recordkeeping and Other Compliance Requirements
    As with all refiners complying with the highway diesel fuel 
program, small refiners will be subject to registration, pre-compliance 
reporting, annual compliance reporting, and product transfer document 
requirements. In addition, the low sulfur diesel fuel program contains 
several hardship options to assist small refiners in producing low 
sulfur diesel fuel. Under these options, small refiners may be subject 
to additional reporting and recordkeeping requirements to help ensure 
compliance with the options and the integrity of the low sulfur diesel 
fuel as it moves from the refinery gate to the retail outlet. For 
example, all refiners producing diesel fuel are required to provide us 
with basic data on their progress toward compliance in 2003-2005 under 
the pre-compliance reporting requirements described in Section IV.A. As 
a part of their pre-compliance reports, small refiners must provide a 
limited amount of additional information specific to the option they 
choose. However, we believe the benefits of these hardship options will 
far outweigh any burdens imposed by their associated recordkeeping and 
reporting requirements.
    The low sulfur diesel fuel program does not impose any new 
reporting requirements for small diesel marketers or distributors. 
However, this program does impose new record keeping requirements for 
such parties, specifically product transfer documents that track 
transfers of diesel fuel. Such transfer records are currently 
maintained by most parties for business and/or tax reasons. In 
addition, the record keeping requirements for downstream parties are 
fairly consistent with those in place today under other EPA fuel 
programs, including the current highway diesel fuel program. Therefore, 
we expect that the new record keeping requirements for downstream 
parties will not impose a significant burden.
    These recordkeeping, reporting and compliance requirements are 
discussed in more detail in Sections IV and VII of this preamble and in 
the FRFA.
5. Regulatory Alternatives To Minimize Impact on Small Entities
    The Small Business Advocacy Review Panel was convened by EPA on 
November 12, 1999. The Panel consisted of representatives of the Small 
Business Administration (SBA), the Office of Management and Budget 
(OMB) and EPA. During the development of the proposal to this rule, EPA 
and the Panel were in contact with representatives from the small 
businesses that will be subject to the provisions in today's rule. In 
addition to verbal comments from industry noted by the Panel at 
meetings and teleconferences, written comments were received from each 
of the affected industry segments or their representatives. The Panel 
report contains a summary of these comments and the Panel's 
recommendations on options that could mitigate the adverse impacts on 
small businesses.
    The Panel considered a range of options and regulatory alternatives 
for providing small businesses with flexibility in complying with new 
sulfur standards for highway diesel fuel. As part of the process, the 
Panel requested and received comment on several ideas for flexibility 
that were suggested by small entity representatives (SERs) and Panel 
members. The Panel's recommendations are discussed in detail in the 
Panel Report, contained in the docket. In the NPRM, EPA sought public 
comment on several ideas that stemmed from the Panel's recommendations, 
as well as on the Panel's recommendations. Taking into consideration 
the comments received on these ideas, as well as additional business 
and technical information gathered about potentially affected small 
entities, we are finalizing certain of those options today, as 
discussed in detail in Section IV above.
    In addition to our participation in the SBREFA process, we 
conducted our own outreach, fact-finding, and analysis of the potential 
impacts of our regulations on small businesses. Some of the small 
refiners with whom we and the Panel met indicated their belief that 
their businesses may close due to the substantial costs, capital and 
other impacts of meeting the 15 ppm diesel fuel standard without either 
additional time or flexibility with respect to gasoline sulfur 
compliance. Based on these discussions and analyses, the Panel and we 
agree that small refiners would likely experience a significant and 
disproportionate financial hardship in reaching the objectives of our 
diesel fuel sulfur program. However, the Panel also noted that the 
burden imposed upon the small refiners by our sulfur requirements 
varied from refiner to refiner and could not be alleviated with a 
single provision. We agree with the Panel and are offering qualifying 
small refiners three options to choose from in moving toward compliance 
with the low sulfur diesel fuel requirements.
    For today's action, we have structured a selection of temporary 
flexibilities for qualifying small refiners, both domestic and foreign, 
based on the factors described below. Generally, we structured these 
provisions to address small refiner hardship while expeditiously 
achieving air quality benefits and ensuring that the low sulfur diesel 
fuel coincides with the introduction of 2007 model year diesel 
vehicles. First, the compliance deadlines in the program, combined with 
flexibility for small refiners, will quickly achieve the air quality 
benefits of the program, while helping to ensure that small refiners 
will have adequate time to raise capital for new or revamped equipment. 
Second, we believe that allowing time for refinery sulfur-reduction 
technologies to be proven out by larger refiners before small refiners 
have to put them in place will likely allow for lower costs of these 
improvements in desulfurization technology (e.g., better catalyst 
technology or lower-pressure hydrotreater technology). Third, providing 
small refiners more time to comply will increase the availability of 
engineering and construction resources. Since most large and small 
refiners must install additional processing equipment to meet the 
sulfur requirements, there will be a tremendous amount of competition 
for technology services, engineering manpower, and construction 
management and labor. Finally, because the gasoline and diesel sulfur 
requirements will occur in approximately the same time frame, small 
refiners that produce both fuels

[[Page 5132]]

will have a greater difficulty than most other refiners in securing the 
necessary financing. Hence, any effort that increases small refiners' 
ability to stagger investments for low sulfur gasoline and diesel will 
facilitate compliance with the two programs. These factors are 
discussed further in Section IV.C.
    Providing these options to assist small refiners experiencing 
hardship circumstances enables us to go forward with the 15 ppm sulfur 
standard beginning in 2006. Without this flexibility, the benefits of 
the 15 ppm standard would possibly not be achieved as quickly. By 
providing temporary relief to those refiners that need additional time, 
we are able to adopt a program that expeditiously reduces diesel sulfur 
levels in feasible manner for the industry as a whole. In addition, we 
believe the volume of diesel that will be affected by this hardship 
provision is marginal. We estimate that small refiners contribute 
approximately five percent of all domestic highway diesel fuel 
production.
    The Final RFA evaluates the financial impacts of today's program on 
small entities. EPA believes that the regulatory alternatives finalized 
in this rule will provide substantial relief to qualifying small 
businesses from the potential adverse economic impacts of complying 
with today's rule. The three hardship options available to small 
refiners under today's rule are summarized below, and are discussed in 
more detail in Section IV.C and the FRFA.

500 ppm Option. A small refiner may continue to produce and sell diesel 
fuel meeting the current 500 ppm sulfur standard for four additional 
years, until May 31, 2010, provided that it reasonably ensures the 
existence of sufficient volumes of 15 ppm fuel in the marketing area(s) 
that it serves.
Small Refiner Credit Option. A small refiner that chooses to produce 15 
ppm fuel prior to June 1, 2010 may generate and sell credits under the 
broader temporary compliance option. Since a small refiner has no 
requirement to produce 15 ppm fuel under this option, any fuel it 
produces at or below 15 ppm sulfur will qualify for generating credits.
Diesel/Gasoline Compliance Date Option. For small refiners that are 
also subject to the Tier 2/Gasoline sulfur program (40 CFR Part 80), 
the refiner may choose to extend by three years the duration of its 
applicable interim gasoline standards, provided that it also produces 
all its highway diesel fuel at 15 ppm sulfur beginning June 1, 2006.

    One alternative for which we sought public comment, but are not 
finalizing today, is an option of allowing small refiners to produce 
highway diesel fuel meeting a less stringent sulfur standard (e.g., 50 
ppm). Some small refiners, and other refiners, commented that the costs 
of meeting a 50 ppm sulfur cap would be significantly less than those 
to meet a 15 ppm cap. However, we are not adopting less stringent 
sulfur standards for small refiners today, because the new diesel 
exhaust emissions control devices require diesel fuel with a sulfur 
content capped at 15 ppm in order to be viable and capable to meeting 
the 2007 emission standards. The need for 15 ppm sulfur diesel fuel is 
discussed in detail in Section III. Additional discussion of this issue 
can be found in the Response to Comments document. Additional 
information on the factual, policy, and legal reasons for the selection 
of alternatives considered for small refiners, and on any rejected 
alternatives, can be found in the FRFA, as well as in appropriate 
sections of the Preamble, RIA, and RTC.
    As required by Section 212 of SBREFA, EPA also is preparing a small 
entity compliance guide to help small entities comply with this rule. 
Once available, small businesses will be able to obtain a copy through 
our web site at http://www.epa.gov/otaq.

C. Paperwork Reduction Act

    This action establishes a standard for low sulfur diesel fuel that 
will become effective in 2006 and that involves the collection of 
information under the Paperwork Reduction Act, 44 U.S.C. 3501 et seq. 
An Agency may not conduct or sponsor, and a person is not required to 
respond to a collection of information, unless it displays a currently 
valid OMB control number. The OMB control numbers for our regulations 
are listed in 40 CFR Part 9 and 48 CFR Chapter 15.
    For 500 ppm diesel fuel standards currently in effect, the existing 
ICR is ``Regulations of Fuel and Fuel Additives; Fuel Quality 
Regulations for Highway Diesel Sold in 1993 and Later Calendar Years; 
Recordkeeping Requirements,'' OMB Control Number 2060-0308, EPA ICR 
Number 1718.12 (expires July 31, 2001). Copies of this ICR may be 
obtained from Delores Evans, Office of Policy, Regulatory Information 
Division, U.S. Environmental Protection Agency (Mail Code 2137), 1200 
Pennsylvania Avenue, NW., Washington, DC 20460. Please mark requests, 
``Attention: Desk Officer for EPA'' and include the ICR in any 
correspondence.
    The Paperwork Reduction Act stipulates that ICR documents estimate 
the burden of activities that will be required of regulated parties 
within a three year time period. Burden means the total time, effort, 
or financial resources expended by persons to generate, maintain, 
retain, or disclose or provide information to or for a Federal agency. 
This includes the time needed to review instructions; develop, acquire, 
install, and utilize technology and systems for the purposes of 
collecting, validating, and verifying information, processing and 
maintaining information, and disclosing and providing information; 
adjust the existing ways to comply with any previously applicable 
instructions and requirements; train personnel to be able to respond to 
a collection of information; search data sources; complete and review 
the collection of information; and transmit or otherwise disclose the 
information.
    The information collection requirements (ICR) for this rule as it 
relates to low sulfur (15 ppm) diesel fuel will undergo any required 
public notice and comment and be submitted for approval to OMB under 
the Paperwork Reduction Act, 44 U.S.C. 3501 et seq. prior to any 
required information collection.

D. Intergovernmental Relations

1. Unfunded Mandates Reform Act
    Title II of the Unfunded Mandates Reform Act of 1995 (UMRA), Public 
Law 104-4, establishes requirements for federal agencies to assess the 
effects of their regulatory actions on state, local, and tribal 
governments, and the private sector. Under Section 202 of the UMRA, EPA 
generally must prepare a written statement, including a cost-benefit 
analysis, for proposed and final rules with ``federal mandates'' that 
may result in expenditures to state, local, and tribal governments, in 
the aggregate, or to the private sector, of $100 million or more for 
any single year. Before promulgating a rule, for which a written 
statement is needed, Section 205 of the UMRA generally requires EPA to 
identify and consider a reasonable number of regulatory alternatives 
and adopt the least costly, most cost effective, or least burdensome 
alternative that achieves the objectives of the rule. The provisions of 
Section 205 do not apply when they are inconsistent with applicable 
law. Moreover, Section 205 allows EPA to adopt an alternative that is 
not the least costly, most cost effective, or least burdensome

[[Page 5133]]

alternative if EPA provides an explanation in the final rule of why 
such an alternative was adopted.
    Before we establish any regulatory requirement that may 
significantly or uniquely affect small governments, including tribal 
governments, we must develop a small government plan pursuant to 
Section 203 of the UMRA. Such a plan must provide for notifying 
potentially affected small governments, and enabling officials of 
affected small governments to have meaningful and timely input in the 
development of our regulations with significant federal 
intergovernmental mandates. The plan must also provide for informing, 
educating, and advising small governments on compliance with the 
regulatory requirements.
    This rule contains no federal mandates for state, local, or tribal 
governments as defined by the provisions of Title II of the UMRA. The 
rule imposes no enforceable duties on any of these governmental 
entities. Nothing in this rule will significantly or uniquely affect 
small governments.
    EPA has determined that this rule contains federal mandates that 
may result in expenditures of more than $100 million to the private 
sector in any single year. EPA considered and evaluated a wide range of 
regulatory alternatives before arriving at the program finalized today. 
EPA believes that today's final rule represents the least costly, most 
cost effective approach to achieve the air quality goals of the rule. 
The cost-benefit analysis required by the UMRA is discussed in Section 
V above and in the RIA. See the ``Administrative Designation and 
Regulatory Analysis'' Section (XI.A.) in today's preamble for further 
information regarding these analyses.
2. Executive Order 13084: Consultation and Coordination With Indian 
Tribal Governments
    Under Executive Order 13084, EPA may not issue a regulation that is 
not required by statute, that significantly or uniquely affects the 
communities of Indian Tribal governments, and that imposes substantial 
direct compliance costs on those communities, unless the federal 
government provides the funds necessary to pay the direct compliance 
costs incurred by the tribal governments, or EPA consults with those 
governments. If EPA complies by consulting, Executive Order 13084 
requires EPA to provide to the OMB, in a separately identified section 
of the preamble to the rule, a description of the extent of EPA's prior 
consultation with representatives of affected tribal governments, a 
summary of the nature of their concerns, and a statement supporting the 
need to issue the regulation. In addition, Executive Order 13084 
requires EPA to develop an effective process permitting elected 
officials and other representatives of Indian tribal governments ``to 
provide meaningful and timely input in the development of regulatory 
policies on matters that significantly or uniquely affect their 
communities.''
    Today's rule does not significantly or uniquely affect the 
communities of Indian Tribal governments. The engine emissions, diesel 
fuel, and other related requirements for private businesses in today's 
rule will have national applicability, and thus will not uniquely 
affect the communities of Indian Tribal Governments. Further, no 
circumstances specific to such communities exist that will cause an 
impact on these communities beyond those discussed in the other 
sections of this rule. Thus, EPA's conclusions regarding the impacts 
from the implementation of today's rule discussed in the other sections 
of this preamble are equally applicable to the communities of Indian 
Tribal governments. Accordingly, the requirements of Section 3(b) of 
Executive Order 13084 do not apply to this rule.

E. National Technology Transfer and Advancement Act

    Section 12(d) of the National Technology Transfer and Advancement 
Act of 1995 (NTTAA), Section 12(d) of Public Law 104-113, directs EPA 
to use voluntary consensus standards in its regulatory activities 
unless it would be inconsistent with applicable law or otherwise 
impractical. Voluntary consensus standards are technical standards 
(e.g., materials specifications, test methods, sampling procedures, and 
business practices) developed or adopted by voluntary consensus 
standards bodies. The NTTAA directs EPA to provide Congress, through 
OMB, explanations when the Agency decides not to use available and 
applicable voluntary consensus standards.
    This rule references technical standards adopted by the Agency 
through previous rulemakings. No new technical standards are 
established in today's rule. The standards referenced in today's rule 
involve the measurement of diesel fuel parameters and engine emissions. 
The measurement standards for diesel fuel parameters referenced in 
today's rule are all voluntary consensus standards. The engine 
emissions measurement standards referenced in today's rule are 
government-unique standards that were developed by the Agency through 
previous rulemakings. These standards have served the Agency's 
emissions control goals well since their implementation and have been 
well accepted by industry. EPA is not aware of any voluntary consensus 
standards for the measurement of engine emissions. Therefore, the 
Agency is using the existing EPA-developed standards found in 40 CFR 
Part 86 for the measurement of engine emissions.

F. Executive Order 13045: Children's Health Protection

    Executive Order 13045, ``Protection of Children from Environmental 
Health Risks and Safety Risks'' (62 FR 19885, April 23, 1997) applies 
to any rule that (1) is determined to be ``economically significant'' 
as defined under Executive Order 12866, and (2) concerns an 
environmental health or safety risk that EPA has reason to believe may 
have a disproportionate effect on children. If the regulatory action 
meets both criteria, Section 5-501 of the Order directs the Agency to 
evaluate the environmental health or safety effects of the planned rule 
on children, and explain why the planned regulation is preferable to 
other potentially effective and reasonably feasible alternatives 
considered by the Agency.
    This rule is subject to the Executive Order because it is an 
economically significant regulatory action as defined by Executive 
Order 12866 and it concerns in part an environmental health or safety 
risk that EPA has reason to believe may have a disproportionate effect 
on children.
    This rulemaking will achieve significant reductions of various 
emissions from heavy-duty engines, including NOX, PM, VOCs 
and air toxics. These pollutants raise concerns regarding environmental 
health or safety risks that EPA has reason to believe may have a 
disproportionate effect on children, such as impacts from ozone, PM and 
certain toxic air pollutants. See Section II and the RIA for a further 
discussion of these issues.
    The effects of ozone and PM on children's health were addressed in 
detail in EPA's rulemaking to establish the NAAQS for these pollutants, 
and EPA is not revisiting those issues here. The emission reductions 
from the strategies in this rulemaking will further reduce air toxics 
and the related adverse impacts on children's health. In a separate 
rulemaking under Section 202(l) of the Act, EPA addresses the emissions 
of hazardous air pollutants from motor vehicles and fuels, and the 
appropriate level of control of HAPs from these sources. It is 
important to note that the air toxics reductions that the Agency 
expects to achieve based on

[[Page 5134]]

today's action are an integral part of the Agency's comprehensive 
strategy to address air toxics from motor vehicles under section 
202(l).
    In this rule, EPA has evaluated several regulatory strategies for 
reductions in emissions from heavy-duty engines. (See Section III of 
this rule as well as the RIA.) For the reasons described there, EPA 
believes that the strategies are preferable under the CAA to other 
potentially effective and reasonably feasible alternatives considered 
by the Agency, for purposes of reducing emissions from these sources as 
a way of helping areas achieve and maintain the NAAQS for ozone and PM. 
Moreover, EPA believes that it has selected for this rule the most 
stringent and effective control reasonably feasible at this time, in 
light of the technology and cost requirements of the Act.

G. Executive Order 13132: Federalism

    Executive Order 13132, entitled ``Federalism'' (64 FR 43255, August 
10, 1999), requires EPA to develop an accountable process to ensure 
``meaningful and timely input by State and local officials in the 
development of regulatory policies that have federalism implications.'' 
``Policies that have federalism implications'' is defined in the 
Executive Order to include regulations that 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.''
    Under Section 6 of Executive Order 13132, EPA may not issue a 
regulation that has federalism implications, that imposes substantial 
direct compliance costs, and that is not required by statute, unless 
the Federal government provides the funds necessary to pay the direct 
compliance costs incurred by State and local governments, or EPA 
consults with State and local officials early in the process of 
developing the regulation. EPA also may not issue a regulation that has 
federalism implications and that preempts State law, unless the Agency 
consults with State and local officials early in the process of 
developing the regulation.
    Section 4 of the Executive Order contains additional requirements 
for rules that preempt State or local law, even if those rules do not 
have federalism implications (i.e., the rules 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). Those 
requirements include providing all affected State and local officials 
notice and an opportunity for appropriate participation in the 
development of the regulation. If the preemption is not based on 
express or implied statutory authority, EPA also must consult, to the 
extent practicable, with appropriate State and local officials 
regarding the conflict between State law and Federally protected 
interests within the agency's area of regulatory responsibility.
    This rule 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, as 
specified in Executive Order 13132. Section 211(d)(4)(A) of the CAA 
prohibits states from prescribing or attempting to enforce controls or 
prohibitions respecting any fuel characteristic or component if EPA has 
prescribed a control or prohibition applicable to such fuel 
characteristic or component under Section 211(c)(1) of the Act. This 
rule merely modifies existing EPA diesel fuel and heavy-duty vehicle 
standards and therefore will merely continue an existing preemption of 
State and local law as discussed in Section VI. Thus, Executive Order 
13132 does not apply to this rule.
    Although Section 6 of Executive Order 13132 does not apply to this 
rule, EPA did consult with representatives of various State and local 
governments in developing this rule. In particular EPA consulted with 
the State of Alaska in the design of the program as it applies to them, 
as discussed in Section IV. EPA also talked to representatives from the 
State of California as well as representatives from STAPPA/ALAPCO, 
which represents state and local air pollution officials.

H. Congressional Review Act

    The Congressional Review Act, 5 U.S.C. 801 et seq., as added by the 
Small Business Regulatory Enforcement Fairness Act of 1996, generally 
provides that before a rule may take effect, the agency promulgating 
the rule must submit a rule report, which includes a copy of the rule, 
to each House of the Congress and to the Comptroller General of the 
United States. EPA will submit a report containing this rule and other 
required information to the U.S. Senate, the U.S. House of 
Representatives, and the Comptroller General of the United States prior 
to publication of the rule in the Federal Register. This rule is a 
``major rule'' as defined by 5 U.S.C. 804(2).

XI. Statutory Provisions and Legal Authority

    Statutory authority for the engine controls finalized in this 
document can be found in Sections 202, 203, 206, 207, 208, and 301 of 
the CAA, as amended, 42 U.S.C. 7521, 7522, 7525, 7541, 7542, and 7601.
    Statutory authority for the fuel controls finalized in this notice 
comes from Section 211(c) and 211(i) of the CAA, which allows EPA to 
regulate fuels that either contribute to air pollution which endangers 
public health or welfare or which impair emission control equipment 
which is in general use or has been in general use. Additional support 
for the procedural and enforcement-related aspects of the fuel's 
controls in today's rule, including the record keeping requirements, 
comes from Sections 114(a) and 301(a) of the CAA.

List of Subjects

40 CFR Part 69

    Environmental protection, Air pollution control.

40 CFR Part 80

    Environmental protection, Fuel additives, Gasoline, Imports, 
Incorporation by reference, Labeling, Motor vehicle pollution, 
Penalties, Reporting and recordkeeping requirements.

40 CFR Part 86

    Environmental protection, Administrative practice and procedure, 
Confidential business information, Incorporation by reference, 
Labeling, Motor vehicle pollution, Reporting and recordkeeping 
requirements.

    Dated: December 21, 2000.
Carol M. Browner,
Administrator.

    For the reasons set forth in the preamble, we amend parts 69, 80 
and 86 of title 40 of the Code of Federal Regulations to read as 
follows:

PART 69--SPECIAL EXEMPTIONS FROM THE REQUIREMENTS OF THE CLEAN AIR 
ACT

    1. The authority citation for part 69 is revised to read as 
follows:

    Authority: 42 U.S.C. 7545(c), (g) and (i), and 7625-1.

Subpart E--Alaska

    2. Section 69.51 of subpart E is revised to read as follows:


Sec. 69.51  Motor vehicle diesel fuel.

    (a) Diesel fuel that is designated for use only in Alaska and is 
used only in

[[Page 5135]]

Alaska, is exempt from the sulfur standard of 40 CFR 80.29(a)(1) and 
the dye provisions of 40 CFR 80.29(a)(3) and 40 CFR 80.29(b) until the 
implementation dates of 40 CFR 80.500, provided that:
    (1) The fuel is segregated from non-exempt diesel fuel from the 
point of such designation; and
    (2) On each occasion that any person transfers custody or title to 
the fuel, except when it is dispensed at a retail outlet or wholesale 
purchaser-consumer facility, the transferor must provide to the 
transferee a product transfer document stating:

    This diesel fuel is for use only in Alaska. It is exempt from 
the federal low sulfur standards applicable to highway diesel fuel 
and red dye requirements applicable to non-highway diesel fuel only 
if it is used in Alaska.

    (b) Beginning on the implementation dates in 40 CFR 80.500, diesel 
fuel that is designated for use in Alaska or is used in Alaska, is 
subject to the applicable provisions of 40 CFR Part 80, Subpart I, 
except as provided under paragraph (c) of this section. The Governor of 
Alaska may submit for EPA approval, by April 1, 2002, a plan for 
implementing the sulfur standard in Alaska as an alternative to the 
temporary compliance option provided under Secs. 80.530-80.532. If EPA 
approves an alternative plan, the provisions as approved by EPA under 
that plan shall apply to the diesel fuel subject to this paragraph (b).
    (c) If such diesel fuel is designated as fuel that does not comply 
with the standards and requirements for motor vehicle diesel fuel under 
40 CFR Part 80, Subpart I, it is exempt from the dye presumption of 40 
CFR 80.520(b)(2) provided that:
    (1) The fuel is segregated from all motor vehicle diesel fuel.
    (2) On each occasion that any person transfers custody or title to 
the fuel, except when it is dispensed at a retail outlet or wholesale 
purchaser-consumer facility, the transferor must provide to the 
transferee a product transfer document complying with the requirements 
of 40 CFR 80.590(a) through (d) and (g), and stating:

    This diesel fuel is for use only in Alaska and is not for use in 
highway vehicles. It is exempt from the red dye requirement 
applicable to non-highway diesel fuel only if it is used in Alaska.

    (3) Any pump dispensing the fuel must comply with the labeling 
requirements in 40 CFR 80.570(c).

PART 80--REGULATION OF FUELS AND FUEL ADDITIVES

    3. The authority citation for part 80 is revised to read as 
follows:

    Authority: 42 U.S.C. 7414, 7545, and 7601(a).

    4. Section 80.2 is amended by revising paragraphs (x) and (y) and 
adding paragraphs (bb), (nn), and (xx) to read as follows:


Sec. 80.2  Definitions.

* * * * *
    (x) Diesel fuel means any fuel sold in any state or Territory of 
the United States and suitable for use in diesel motor vehicles, diesel 
motor vehicle engines or diesel nonroad engines, and which is commonly 
or commercially known or sold as diesel fuel.
    (y) Motor vehicle diesel fuel means any diesel fuel, or any 
distillate product, that is used, intended for use, or made available 
for use, as a fuel in diesel motor vehicles or diesel motor vehicle 
engines.
* * * * *
    (bb) Sulfur percentage is the percentage of sulfur in diesel fuel 
by weight, as determined using the applicable sampling and testing 
methodologies set forth in Sec. 80.580.
* * * * *
    (nn) Batch of motor vehicle diesel fuel means a quantity of diesel 
fuel which is homogeneous with regard to those properties that are 
specified for motor vehicle diesel fuel under subpart I of this part.
* * * * *
    (xx) Motor vehicle diesel fuel additive means any substance not 
composed solely of carbon and/or hydrogen, or of diesel blendstocks, 
that is added, intended for adding, used, or offered for use in motor 
vehicle diesel fuel subsequent to the production of diesel fuel by 
processing crude oil from refinery processing units, or in diesel motor 
vehicle fuel systems.
* * * * *

    5. Section 80.29 is amended by revising paragraphs (a) and (b), to 
read as follows:


Sec. 80.29  Controls and prohibitions on diesel fuel quality.

    (a) Prohibited activities. Beginning October 1, 1993 and continuing 
until the implementation dates for subpart I of part 80 as specified in 
Sec. 80.500, except as provided in 40 CFR 69.51, no person, including 
but not limited to, refiners, importers, distributors, resellers, 
carriers, retailers or wholesale purchaser-consumers, shall 
manufacture, introduce into commerce, sell, offer for sale, supply, 
store, dispense, offer for supply or transport any diesel fuel for use 
in motor vehicles, unless the diesel fuel:
    (1) Has a sulfur percentage, by weight, no greater than 0.05 
percent;
    (2)(i) Has a cetane index of at least 40; or
    (ii) Has a maximum aromatic content of 35 volume percent; and
    (3) Is free of visible evidence of the dye solvent red 164; unless 
it is used in a manner that is tax-exempt as defined under section 4082 
of the Internal Revenue Code (26 U.S.C. 4082).
    (b) Determination of compliance. (1) Any diesel fuel which does not 
show visible evidence of being dyed with dye solvent red 164 (which has 
a characteristic red color in diesel fuel) shall be considered to be 
available for use in diesel motor vehicles and motor vehicle engines, 
and shall be subject to the prohibitions of paragraph (a) of this 
section.
    (2) Compliance with the sulfur, cetane, and aromatics standards in 
paragraph (a) of this section shall be determined based on the level of 
the applicable component or parameter, using the sampling methodologies 
specified in Sec. 80.330(b), as applicable, and the appropriate testing 
methodologies specified in Sec. 80.580(a) for sulfur, Sec. 80.2(w) for 
cetane index, and Sec. 80.2(z) for aromatic content. Any evidence or 
information, including the exclusive use of such evidence or 
information, may be used to establish the level of the applicable 
component or parameter in the diesel fuel, if the evidence or 
information is relevant to whether that level would have been in 
compliance with the standard if the appropriate sampling and testing 
methodology had been correctly performed. Such evidence may be obtained 
from any source or location and may include, but is not limited to, 
test results using methods other than the compliance methods in this 
paragraph (b), business records, and commercial documents.
    (3) Determination of compliance with the requirements of this 
section other than the standards described in paragraph (a) of this 
section, and determination of liability for any violation of this 
section, may be based on information obtained from any source or 
location. Such information may include, but is not limited to, business 
records and commercial documents.
* * * * *

    6. Section 80.30 is amended by revising paragraphs (g)(2)(ii) and 
(g)(4)(i), and adding paragraph (h), to read as follows;

[[Page 5136]]

Sec. 80.30  Liability for violations of diesel fuel controls and 
prohibitions.

* * * * *
    (g) Defenses. * * *
* * * * *
    (2) * * *
    (ii) Test results, performed in accordance with the applicable 
sampling and testing methodologies set forth in Secs. 80.2(w), 80.2(z), 
80.2(bb), and 80.580, which evidence that the diesel fuel determined to 
be in violation was in compliance with the diesel fuel standards of 
Sec. 80.29(a) when it was delivered to the next party in the 
distribution system;
* * * * *
    (4) * * *
    (i) Test results, performed in accordance with the applicable 
sampling and testing methodologies set forth in Secs. 80.2(w), 80.2(z), 
80.2(bb), and 80.580, which evidence that the diesel fuel determined to 
be in violation was in compliance with the diesel fuel standards of 
Sec. 80.29(a) when it was delivered to the next party in the 
distribution system;
* * * * *
    (h) Detection of violations. In paragraphs (a) through (f) of this 
section, the term ``is detected at'' means that the violation existed 
at the facility in question, and the existence of the violation at that 
facility may be established through evidence obtained or created at 
that facility, at any other location, and by any party.

    7. Section 80.215 is amended by revising paragraph (b) to read as 
follows:


Sec. 80.215  What is the scope of the geographic phase-in program?

* * * * *
    (b) Duration of the program. (1) The geographic phase-in program 
applies to the 2004, 2005, and 2006 annual averaging periods, except as 
provided in paragraph (b)(2) of this section.
    (2) Subject to the provisions of Sec. 80.540, the geographic phase-
in program shall also apply to the 2007 and 2008 annual averaging 
period for refiners approved for GPA standards in 2007 and 2008 under 
Sec. 80.540.
* * * * *

    8. Section 80.220 is amended by adding paragraph (c) to read as 
follows:


Sec. 80.220  What are the downstream standards for GPA gasoline?

* * * * *
    (c) Notwithstanding paragraph (a) of this section, the sulfur 
content standard of 326 ppm at any downstream location may be extended 
as provided under Sec. 80.540(m).

    9. Section 80.240 is amended by adding paragraph (e), to read as 
follows:


Sec. 80.240  What are the small refiner gasoline sulfur standards?

* * * * *
    (e) Notwithstanding paragraph (a) of this section, the temporary 
sulfur standards for small refiners may be extended as provided under 
Sec. 80.553.

    10. Subpart I is added to part 80 to read as follows:

Subpart I--Motor Vehicle Diesel Fuel

General Information

Sec.
80.500  What are the implementation dates for the diesel fuel sulfur 
control program?
80.501  What diesel fuel is subject to the provisions of this 
subpart?
80.502-80.519  [Reserved]

Motor Vehicle Diesel Fuel Standards and Requirements

80.520  What are the standards and dye requirements for motor 
vehicle diesel fuel?
80.521  What are the standards and identification requirements for 
motor vehicle diesel fuel additives?
80.522  May used motor oil be dispensed into diesel motor vehicles?
80.523  What diesel fuel designation requirements apply to refiners 
and importers?
80.524  What sulfur content standard applies to motor vehicle diesel 
fuel downstream of the refinery or importer?
80.525  What requirements apply to kerosene blenders?
80.526   [Reserved]
80.527   Under what conditions may motor vehicle diesel fuel subject 
to the 15 ppm sulfur standard be downgraded as motor vehicle diesel 
fuel subject to the 500 ppm sulfur standard?
80.528--80.529   [Reserved]

Temporary Compliance Option

80.530  Under what conditions can 500 ppm motor vehicle diesel fuel 
be produced or imported?
80.531  How are motor vehicle diesel fuel credits generated?
80.532  How are credits used and transferred?
80.533-80.539  [Reserved]

Geographic Phase-In Provisions

80.540  How may a refiner be approved to produce gasoline under the 
GPA gasoline sulfur standards in 2007 and 2008?
80.541-80.549  [Reserved]

Small Refiner Hardship Provisions

80.550  What is the definition of a small refiner under this 
subpart?
80.551  How does a refiner obtain approval as a small refiner under 
this subpart?
80.552  What compliance options are available to small refiners?
80.553  Under what conditions may the small refiner gasoline sulfur 
standards be extended for a small refiner of motor vehicle diesel 
fuel?
80.554-80.559  [Reserved]

Other Hardship Provisions

80.560  How can a refiner seek temporary relief from the 
requirements of this subpart in case of extreme hardship 
circumstances?
80.561  How can a refiner or importer seek temporary relief from the 
requirements of this subpart in case of extreme unforseen 
circumstances?
80.562-80.569  [Reserved]

Labeling Requirements

80.570  What labeling requirements apply to retailers and wholesale 
purchaser-consumers of motor vehicle diesel fuel?
80.571-80.579  [Reserved]

Sampling and Testing

80.580  What are the sampling and testing methods for sulfur?
80.581-80.589  [Reserved]

Recordkeeping and Reporting Requirements

80.590  What are the product transfer document requirements for 
motor vehicle diesel fuel?
80.591  What are the product transfer document requirements for 
additives to be used in motor vehicle diesel fuel?
80.592  What records must be kept?
80.593  What are the reporting and registration requirements for 
refiners and importers of motor vehicle diesel fuel subject to 
temporary refiner relief standards?
80.594  What are the pre-compliance reporting requirements?
80.595  How does a refiner apply for a motor vehicle diesel fuel 
volume baseline?
80.596  How is a refinery motor vehicle diesel fuel volume baseline 
calculated?
80.597  What are the registration requirements?
80.598-80.599  [Reserved]

Exemptions

80.600  What are the requirements for obtaining an exemption for 
motor vehicle diesel fuel used for research, development or testing 
purposes?
80.601  What requirements apply to motor vehicle diesel fuel for use 
in the Territories?
80.602  What exemption applies to diesel fuel used in vehicles 
having a national security exemption from motor vehicle emissions 
standards?
80.603-80.609  [Reserved]

Violation Provisions

80.610  What acts are prohibited under the diesel fuel sulfur 
program?
80.611  What evidence may be used to determine compliance with the 
prohibitions and requirements of this subpart and liability for 
violations of this subpart?
80.612  Who is liable for violations of this subpart?
80.613  What defenses apply to persons deemed liable for a violation 
of a prohibited act?
80.614  What penalties apply under this subpart?

[[Page 5137]]

80.615-80.619  [Reserved]

Provisions for Foreign Refiners and Importers for Motor Vehicle 
Diesel Fuel Subject to a Temporary Compliance Option or Hardship 
Provision


80.620  What are the additional requirements for motor vehicle diesel 
fuel produced by foreign refineries subject to a temporary refiner 
compliance option or hardship provisions?

Subpart I--Motor Vehicle Diesel Fuel

General Information


Sec. 80.500  What are the implementation dates for the diesel fuel 
sulfur control program?

    The implementation dates for standards for motor vehicle diesel 
fuel and diesel fuel additives, and for other provisions of this 
subpart, are as follows:
    (a) Implementation date for standards applicable to production or 
importation of motor vehicle diesel fuel, and to motor vehicle diesel 
fuel additives. Except as provided in paragraph (d) of this section, 
beginning June 1, 2006:
    (1) The standards and requirements under Sec. 80.520(a) and (b) 
shall apply to any motor vehicle diesel fuel produced or imported by 
any refiner or importer; and
    (2) The standards and requirements under Sec. 80.521 shall apply to 
any motor vehicle diesel fuel additive.
    (b) Implementation date for standards applicable to motor vehicle 
diesel fuel downstream of the refinery or importer. Except as provided 
in paragraphs (c) and (d) of this section, beginning July 15, 2006, the 
standards and requirements under Sec. 80.520(a) and (b) shall apply to 
any motor vehicle diesel fuel at any downstream location.
    (c) Implementation date for standards applicable to motor vehicle 
diesel fuel at retail outlets and wholesale purchaser-consumer 
facilities. Except as provided in paragraph (d) of this section, 
beginning September 1, 2006, the standards and requirements under 
Sec. 80.520(a) and (b) shall apply to any motor vehicle diesel fuel at 
any retail outlet or wholesale purchaser-consumer facility.
    (d) Implementation date for motor vehicle diesel fuel subject to 
the 500 ppm sulfur content standard in Sec. 80.520(c). (1) Beginning 
June 1, 2006, the sulfur content standard of Sec. 80.520(c) shall apply 
to motor vehicle diesel fuel, but only where authorized under, and 
subject to, an applicable provision of this Subpart.
    (2) Beginning June 1, 2010, the sulfur content standard of 
Sec. 80.520(c) shall no longer apply to any motor vehicle diesel fuel 
produced or imported by any refiner or importer.
    (3) Beginning October 1, 2010, the sulfur content standard of 
Sec. 80.520(c) shall no longer apply to any motor vehicle diesel fuel 
at any downstream location other than a retail or wholesale purchaser-
consumer facility.
    (4) Beginning December 1, 2010, the sulfur content standard of 
Sec. 80.520(c) shall no longer apply to any motor vehicle diesel fuel.
    (e) Other provisions. All other provisions of this subpart apply 
beginning June 1, 2006, unless another date is specified.
    (f) For purposes of this subpart, the term ``downstream location'' 
shall mean any point in the diesel fuel distribution system downstream 
from refineries and import facilities, including diesel fuel at 
facilities of distributors, carriers, retailers, kerosene blenders, and 
wholesale purchaser-consumers.


Sec. 80.501  What diesel fuel is subject to the provisions of this 
subpart?

    (a) Included fuel and additives. The provisions of this subpart 
apply to motor vehicle diesel fuel as defined in Sec. 80.2(y), motor 
vehicle diesel fuel additives as defined in Sec. 80.2(xx), and motor 
oil that is used as or intended for use as fuel in diesel motor 
vehicles or is blended with diesel fuel for use in diesel motor 
vehicles at any downstream location, as provided in Sec. 80.500(f).
    (b) Excluded fuel. The provisions of this subpart do not apply to 
motor vehicle diesel fuel that is designated for export outside the 
United States, and identified for export by a transfer document as 
required under Sec. 80.590.


Secs. 80.502-80.519  [Reserved]

Motor Vehicle Diesel Fuel Standards and Requirements


Sec. 80.520  What are the standards and dye requirements for motor 
vehicle diesel fuel?

    (a) Standards. All motor vehicle diesel fuel is subject to the 
following per-gallon standards:
    (1) Sulfur content. 15 parts per million (ppm) maximum, except as 
provided in paragraph (c) of this section;
    (2) Cetane index and aromatic content. (i) A minimum cetane index 
of 40; or
    (ii) A maximum aromatic content of 35 volume percent.
    (b) Dye requirements. (1) All motor vehicle diesel fuel shall be 
free of visible evidence of dye solvent red 164 (which has a 
characteristic red color in diesel fuel), except for motor vehicle 
diesel fuel that is used in a manner that is tax exempt under section 
4082 of the Internal Revenue Code.
    (2) Any diesel fuel that does not show visible evidence of dye 
solvent red 164 shall be considered to be motor vehicle diesel fuel and 
subject to all the requirements of this subpart for motor vehicle 
diesel fuel, except for diesel fuel designated or classified for use 
only in:
    (i) The State of Alaska as provided under 40 CFR 69.51; or
    (ii) Jet aircraft, a research and development testing program 
exempted under 80.600, or motor vehicles covered by an exemption under 
Sec. 80.602.
    (c) Pursuant and subject to the provisions of Secs. 80.530-80.532, 
80.552(a), 80.560-80.561, and 80.620, only motor vehicle diesel fuel 
produced or imported in full compliance with the requirements of those 
provisions is subject to the following per-gallon standard for sulfur 
content: 500 ppm maximum.
    (d) Kerosene and any other distillate product, that meets the 
definition of motor vehicle diesel fuel, is subject to the standards 
and requirements under this section.


Sec. 80.521  What are the standards and identification requirements for 
motor vehicle diesel fuel additives?

    (a) Except as provided in paragraph (b) of this section, any motor 
vehicle diesel fuel additive that is added, intended for adding, used, 
or offered for use in motor vehicle diesel fuel subject to the 15 ppm 
sulfur content standard, at any downstream location must:
    (1) Have a sulfur content not exceeding 15 ppm; and
    (2) Be accompanied a product transfer document pursuant to 
Sec. 80.591 indicating that the additive complies with the 15 ppm 
standard for motor vehicle diesel fuel, except for those diesel fuel 
additives which are only sold in containers for use by the ultimate 
consumer of motor vehicle diesel fuel and which are subject to the 
requirements of Sec. 80.591(d).
    (b) Any motor vehicle diesel fuel additive that is added, intended 
for adding, used, or offered for use in motor vehicle diesel fuel 
subject to the 15 ppm sulfur content standard may have a sulfur content 
exceeding 15 ppm provided that:
    (1) The additive is added or used in the motor vehicle diesel fuel 
in a quantity less than 1% by volume of the resultant additive/diesel 
fuel mixture;
    (2) The product transfer document pursuant to Sec. 80.591 indicates 
that the additive may exceed the 15 ppm sulfur standard, that improper 
use of the additive may result in non-complying fuel, and that the 
additive complies

[[Page 5138]]

with the sulfur information requirements of Sec. 80.591(b)(3); and
    (3) The additive is not used or intended for use by an ultimate 
consumer in diesel motor vehicles.


Sec. 80.522  May used motor oil be dispensed into diesel motor 
vehicles?

    No person may introduce used motor oil, or used motor oil blended 
with diesel fuel, into the fuel system of model year 2007 or later 
diesel motor vehicles, unless both of the following requirements have 
been met:
    (a) The vehicle or engine manufacturer has received a Certificate 
of Conformity under 40 CFR Part 86 and the certification of the vehicle 
or engine configuration is explicitly based on emissions data with the 
addition of motor oil; and
    (b) The oil is added in a manner and rate consistent with the 
conditions of the Certificate of Conformity.


Sec. 80.523  What diesel fuel designation requirements apply to 
refiners and importers?

    Any refiner or importer shall accurately and clearly designate all 
fuel it produces or imports for use in diesel motor vehicles as either 
motor vehicle diesel fuel meeting the 15 ppm sulfur standard under 
Sec. 80.520(a)(1) or as motor vehicle diesel fuel meeting the 500 ppm 
sulfur standard under Sec. 80.520(c).


Sec. 80.524  What sulfur content standard applies to motor vehicle 
diesel fuel downstream of the refinery or importer?

    (a) Except as provided in paragraph (b) of this section or 
otherwise in the provisions of this Subpart I, the 15 ppm sulfur 
content standard of Sec. 80.520(a) shall apply to all motor vehicle 
diesel fuel at any downstream location.
    (b) Prior to the October 1, 2010 and December 1, 2010 dates 
specified in Sec. 80.500(d)(3) and (4), the 500 ppm sulfur content 
standard of Sec. 80.520(c) shall apply to motor vehicle diesel fuel at 
any downstream location, provided the following conditions are met:
    (1) The product transfer documents comply with the requirements of 
Sec. 80.590, including indicating that the fuel complies with the 500 
ppm sulfur standard for motor vehicle diesel fuel and is for use only 
in model year 2006 and older diesel motor vehicles, or the fuel is 
downgraded pursuant to the provision of Sec. 80.527 to motor vehicle 
diesel fuel subject to the 500 ppm sulfur standard;
    (2) The motor vehicle diesel fuel is not represented or intended 
for sale or use as subject to the 15 ppm sulfur content standard, and 
is not dispensed, or intended to be dispensed, into model year 2007 and 
later motor vehicles by a retailer or wholesale purchaser-consumer; and
    (3) For retailers or wholesale purchaser-consumers, the pump 
labeling requirements of Sec. 80.570(a) are satisfied.


Sec. 80.525  What requirements apply to kerosene blenders?

    (a) For purposes of this subpart, a kerosene blender means any 
refiner who produces motor vehicle diesel fuel by adding kerosene to 
motor vehicle diesel fuel downstream of the refinery that produced the 
motor vehicle diesel fuel or of the import facility where the motor 
vehicle diesel fuel was imported, without altering the quality or 
quantity of the motor vehicle diesel fuel in any other manner.
    (b) Kerosene blenders are not subject to the requirements of this 
subpart applicable to refiners of motor vehicle diesel fuel, but are 
subject to the requirements and prohibitions applicable to downstream 
parties.
    (c) For purposes of compliance with Sec. 80.524(b)(1), the product 
transfer documents must indicate that the fuel to which kerosene is 
added complies with the 500 ppm sulfur standard for motor vehicle 
diesel fuel and is for use only in model year 2006 and older diesel 
motor vehicles, or the fuel is properly downgraded pursuant to the 
provisions of Sec. 80.527 to motor vehicle diesel fuel subject to the 
500 ppm sulfur standard.
    (d) Kerosene that a kerosene blender adds or intends to add to 
motor vehicle diesel fuel subject to the 15 ppm sulfur content standard 
must meet the 15 ppm sulfur content standard, and the following 
requirements:
    (1) The product transfer document received by the kerosene blender 
indicates that the kerosene is motor vehicle diesel fuel that complies 
with the 15 ppm sulfur content standard; or
    (2) The kerosene blender has test results indicating the kerosene 
complies with the 15 ppm sulfur standard.


Sec. 80.526  [Reserved]


Sec. 80.527  Under what conditions may motor vehicle diesel fuel 
subject to the 15 ppm sulfur standard be downgraded as motor vehicle 
diesel fuel subject to the 500 ppm sulfur standard?

    (a) Definition. As used in this section, downgrade means changing 
the classification of motor vehicle diesel fuel subject to the 15 ppm 
sulfur standard under Sec. 80.520(a)(1) to motor vehicle diesel fuel 
subject to the 500 ppm sulfur standard under Sec. 80.520(c). A 
downgrade occurs when the change in classification takes place. 
Changing the classification of motor vehicle diesel fuel subject to the 
15 ppm sulfur standard under Sec. 80.520(a)(1) to any fuel that is not 
motor vehicle diesel fuel is not a downgrade for purposes of this 
section and is not limited by the provisions of this section.
    (b) Who may downgrade. Any person in the motor vehicle diesel fuel 
distribution system who has custody or title to motor vehicle diesel 
fuel may downgrade it.
    (c) Downgrading limitation. (1) Except as provided in paragraphs 
(d) and (e) of this section, a person described in paragraph (c)(4) of 
this section may not downgrade a total of more than 20% of the motor 
vehicle diesel fuel (by volume) that is subject to the 15 ppm sulfur 
standard of Sec. 80.520(a)(1) while such person has title to or custody 
of such fuel. In addition, a refiner or importer may only downgrade 
(subject to the 20% limit) motor vehicle diesel fuel designated under 
Sec. 80.523 as subject to 15 ppm sulfur standard under 
Sec. 80.520(a)(1) after it has been so designated and after it has been 
moved from the refinery's, or import facility's, storage tank or other 
vessel where the diesel fuel batch was designated as subject to the 
sulfur standard of Sec. 80.520(a) under Sec. 80.523.
    (2) The limitation of paragraph (c)(1) of this section applies 
separately to each person who has custody or title of the fuel when it 
is downgraded.
    (3) Compliance with the limitation of paragraph (c)(1) of this 
section shall be on an annual, calendar year basis (except in 2006 
compliance shall be for the period June 1, 2006 through December 31, 
2006, and in 2010 compliance shall be for the period January 1 through 
May 31).
    (4) The limitation of this section applies to persons who sell, 
offer for sale, dispense, supply, store or transport diesel fuel. The 
limitation does not apply to persons who are transferred custody or 
title to motor vehicle diesel fuel when it is dispensed into motor 
vehicles at retail outlets.
    (d) Diesel fuel in violation of the 15 ppm standard. Where motor 
vehicle diesel fuel subject to the sulfur standard of Sec. 80.520(a)(1) 
is found to be in violation of any standard under Sec. 80.520(a) and is 
consequently downgraded, the person, or persons, having custody and 
title to the fuel at the time it is found to be in violation must 
include the volume of such fuel toward its 20% volume limitation under 
paragraph (c)(1) of this section, unless the person, or persons, 
demonstrates that it did not cause the violation.
    (e) Special provisions for retail outlets and wholesale purchaser-
consumer facilities. Notwithstanding the

[[Page 5139]]

provisions of paragraph (c)(1) of this section, retailers and wholesale 
purchaser-consumers shall comply with the downgrading limitation as 
follows:
    (1) Retailers and wholesale purchaser-consumers who sell, offer for 
sale, or dispense motor vehicle diesel fuel that is subject to the 15 
ppm sulfur standard under Sec. 80.520(a)(1) are exempt from the volume 
limitations of paragraph (c)(1) of this section.
    (2) A retailer or wholesale purchaser-consumer who does not sell, 
offer for sale, or dispense motor vehicle diesel fuel subject to the 15 
ppm sulfur standard under Sec. 80.520(a)(1) may not downgrade a volume 
of motor vehicle diesel fuel classified as subject to the 15 ppm sulfur 
standard greater than 20% of the total volume of motor vehicle diesel 
fuel that it sells, offers for sale, or dispenses annually.
    (f) Product transfer documents. If the custody or title to any 
motor vehicle diesel fuel that is downgraded under this section is 
transferred, the product transfer documents under Sec. 80.590 for such 
fuel must reflect the change in classification to motor vehicle diesel 
fuel subject to the 500 ppm sulfur standard.
    (g) Recordkeeping requirement. Any person subject to the provisions 
of this section, as described in paragraph (c)(4) of this section, who 
downgrades any motor vehicle diesel fuel previously classified as 
subject to the 15 ppm sulfur standard under Sec. 80.520(a)(1) during 
any calendar year, must make and maintain records sufficient to show 
compliance with the requirements and limitations of this section.
    (h) Termination of downgrading limitations. The provisions of this 
section shall not apply after May 31, 2010.


Secs. 80.528-80.529  [Reserved.]

Temporary Compliance Option


Sec. 80.530  Under what conditions can 500 ppm motor vehicle diesel 
fuel be produced or imported?

    (a) Beginning June 1, 2006, a refiner or importer may produce or 
import motor vehicle diesel fuel subject to the 500 ppm sulfur content 
standard of Sec. 80.520(c) if all of the following requirements are 
met:
    (1) Each batch of motor vehicle diesel fuel subject to the 500 ppm 
sulfur content standard must be designated by the refiner or importer 
as subject to such standard, pursuant to Sec. 80.523.
    (2) The refiner or importer must meet the requirements for product 
transfer documents in Sec. 80.590 for each batch subject to the 500 ppm 
sulfur content standard.
    (3)(i) The volume V500 of diesel fuel that is produced 
or imported during a compliance period, as provided in paragraph (a)(5) 
of this section, may not exceed the following volume limit:
    (A) For compliance periods prior to 2010, 20% of the volume 
Vt of diesel fuel that is produced or imported during a 
compliance period plus an additional volume of motor vehicle diesel 
fuel represented by credits properly generated and used pursuant to the 
requirements of Secs. 80.531 and 80.532.
    (B) For the compliance period of January 1, 2010 through May 31, 
2010, the volume of motor vehicle diesel fuel represented by credits 
properly generated and used pursuant to the requirements of 
Secs. 80.531 and 80.532.
    (ii) The terms V500 and Vt have the meaning 
specified in Sec. 80.531(a)(2).
    (4) Compliance with the volume limit in paragraph (a)(3) of this 
section must be determined separately for each refinery. For an 
importer, such compliance must be determined separately for each Credit 
Trading Area (as defined in Sec. 80.531) into which motor vehicle 
diesel fuel is imported. If a party is both a refiner and an importer, 
such compliance shall be determined separately for the refining and 
importation activities.
    (5) Compliance with the volume limit in paragraph (a)(3) of this 
section shall be determined on a calendar year basis, where the 
calendar year period is from January 1st through December 31st. For the 
year 2006, compliance shall be determined for the period June 1, 2006 
through December 31, 2006. For the year 2010, compliance shall be 
determined for the period of January 1, 2010 through May 31, 2010.
    (6) Any motor vehicle diesel fuel produced or imported above the 
volume limit in paragraph (a)(3) of this section shall be subject to 
the 15 ppm sulfur content standard. However, for any compliance period 
prior to and including 2009, a refiner or importer may exceed the 
volume limit in paragraph (a)(3) of this section by no more than 5 
percent of the volume Vt of diesel fuel produced or imported 
during the compliance period, provided that for the immediately 
following calendar year:
    (i) The refiner or importer complies with the volume limit in 
paragraph (a)(3) of this section; and
    (ii) The refiner or importer produces or imports a volume of motor 
vehicle diesel fuel subject to the 15 ppm sulfur standard, or obtains 
credits properly generated and used pursuant to the requirements of 
Secs. 80.531 and 80.532 that represent a volume of motor vehicle diesel 
fuel, equal to the volume of the exceedence for the prior compliance 
period.
    (b) After May 31, 2010, no refiner or importer may produce or 
import motor vehicle diesel fuel subject to the 500 ppm sulfur content 
standard pursuant to this section.


Sec. 80.531  How are motor vehicle diesel fuel credits generated?

    (a) Generation of credits from June 1, 2006 through December 31, 
2009. (1) A refiner or importer may generate credits during the period 
June 1, 2006 through December 31, 2009, for motor vehicle diesel fuel 
produced or imported that is designated as subject to the 15 ppm sulfur 
content standard under Sec. 80.520(a)(1). Credits may be generated only 
if the volume of motor vehicle diesel fuel designated under Sec. 80.523 
as subject to the 15 ppm sulfur standard of Sec. 80.520(a) exceeds 80% 
of the total volume of diesel fuel produced or imported as described in 
paragraph (a)(2) of this section.
    (2) The number of credits generated shall be calculated for each 
compliance period (as specified in Sec. 80.530(a)(5)) as follows:
    C = V15 - (0.80  x  Vt)

Where:
C = the positive number of credits generated, in gallons.
V15 = the total volume in gallons of motor vehicle diesel 
fuel produced or imported that is designated under Sec. 80.523 as 
subject to the standards of Sec. 80.520(a) during the compliance 
period.
V500 = the total volume in gallons of motor vehicle 
diesel fuel produced or imported that is designated under 
Sec. 80.523 as subject to the 500 ppm sulfur standard under 
Sec. 80.520(c) plus the total volume of any other diesel fuel (not 
including V15, or diesel fuel that is dyed in accordance 
with Sec. 80.520(b) at the refinery or import facility where the 
diesel fuel is produced or imported) represented as having a sulfur 
content not exceeding 500 ppm.
Vt = V15 + V500.

    (3) Credits shall be generated and designated as follows:
    (i) Credits shall be generated separately for each refinery of a 
refiner.
    (ii) Credits shall be generated separately for each credit trading 
area (CTA), as defined in paragraph (a)(5) of this section, into which 
motor vehicle diesel fuel is imported by an importer.
    (iii) Credits shall be designated separately by year of generation 
and by CTA of generation. In the case of a refiner, credits shall also 
be designated by refinery, and in the case of an importer, credits 
shall also be designated by port of import.
    (iv) Credits may not be generated by both a foreign refiner and by 
an importer for the same motor vehicle diesel fuel.

[[Page 5140]]

    (4) Credits shall be generated by a foreign refiner as provided in 
Sec. 80.620(c) and this section.
    (5) For purposes of this subpart, the CTAs are:
    (i) PADDs 1, 2, 3 and 4, as described in Sec. 80.41(r), except as 
provided in paragraph (a)(5)(iv) of this section. The CTAs shall be 
designated as CTA 1, 2, 3, and 4, respectively, and correspond to PADD 
1, 2, 3, and 4, respectively;
    (ii) CTA 5 shall correspond to PADD 5, as described in 
Sec. 80.41(r), except as provided in paragraphs (a)(5)(iii) and (iv) of 
this section;
    (iii) The states of Hawaii and Alaska shall each be treated as a 
separate CTA and not a part of CTA 5. Alaska shall be CTA 6. Hawaii 
shall be CTA 7;
    (iv) If any state (through a waiver of federal preemption under 
Section 211(c)(4) of the Clean Air Act, 42 U.S.C. 7545(c)(4)) 
implements a law or regulation that requires a greater volume of motor 
vehicle diesel fuel to meet a sulfur standard of less than or equal to 
15 ppm than the volume that is required under this subpart, no motor 
vehicle diesel fuel produced in that state or imported directly into 
that state may generate credits under this subpart, effective on the 
implementation date of the sulfur program under the state statute or 
regulation that implements the more stringent state requirements.
    (6) No credits may be generated under this paragraph (a) after 
December 31, 2009.
    (7) No refinery may generate credits under both this paragraph (a) 
and under paragraph (e) of this section.
    (b) Generation of early credits from June 1, 2001 through May 31, 
2005. (1) Beginning June 1, 2001, a refiner or importer may generate 
one credit for each gallon of motor vehicle diesel fuel meeting the 
sulfur content standard in Sec. 80.520(a)(1) that is used in vehicles 
with engines that are certified to meet the model year 2007 heavy duty 
engine PM standard under 40 CFR 86.007-11, or vehicles with retrofit 
technologies that achieve emission levels equivalent to the 2007 
NOX or PM emission standard verified as part of a retrofit 
program administered by EPA or a state. Such refiners and importers 
must comply with the requirements of paragraphs (b) and (d) of this 
section.
    (2)(i) Any refiner or importer planning to generate credits under 
this paragraph must provide notice of intent to generate early credits 
at least 120 calendar days prior to the date it begins generating 
credits under this paragraph by submitting such notice to Attn: Early 
Diesel Credits Notice, at the address in Sec. 80.595.
    (ii) The notice shall include a detailed plan that demonstrates 
that the motor vehicle diesel fuel meeting the 15 ppm sulfur standard 
of Sec. 80.520(a)(1) for which credits are generated under this 
paragraph will be used in vehicles with engines that are certified to 
meet the model year 2007 heavy duty engine PM standard under 40 CFR 
86.007-11 or in vehicles with retrofit technologies that achieve 
emission levels equivalent to the 2007 NOX or PM emission 
standard verified as part of a retrofit program administered by EPA or 
a state. The notice must include the refiner's or importer's detailed 
plan for ensuring that all motor vehicle diesel fuel that generates 
early credits under this paragraph will be segregated from all other 
motor vehicle diesel fuel not meeting the sulfur standard under 
Sec. 80.520(a)(1), from the refinery or import facility to its ultimate 
use in motor vehicles.
    (3) No credits may be generated under this paragraph (b) after May 
31, 2005.
    (4) A refiner or importer may generate credits under this paragraph 
and also generate credits under paragraph (a) of this section, and a 
small refiner, as defined under Sec. 80.550, may generate credits under 
this paragraph (b) and paragraph (e) of this section.
    (c) Generation of early credits from June 1, 2005 through May 31, 
2006. (1) Beginning June 1, 2005, a refiner or importer may generate 
one credit for each gallon of motor vehicle diesel fuel that is 
dispensed at retail outlets or at wholesale-purchaser consumer 
facilities exclusively as motor vehicle diesel fuel meeting the 15 ppm 
sulfur standard in Sec. 80.520(a)(1). Such refiners and importers must 
comply with the requirements of this paragraph (c) and paragraph (d) of 
this section.
    (2)(i) Any refiner or importer planning to generate credits under 
this paragraph must provide notice of intent to generate early credits 
at least 120 calendar days prior to the date it begins generating 
credits under this paragraph (c).
    (ii) The notice shall include a detailed plan that demonstrates 
that the motor vehicle diesel fuel meeting the sulfur standard under 
Sec. 80.520(a)(1) will be dispensed exclusively at retail outlets or at 
wholesale-purchaser consumer facilities as 15 ppm sulfur content motor 
vehicle diesel fuel. The plan must demonstrate that the refiner or 
importer will assure that all motor vehicle diesel fuel that generates 
early credits under this paragraph (c) will be segregated from all 
other motor vehicle diesel fuel from the refinery or import facility to 
its ultimate use in motor vehicles.
    (3) No credits may be generated under this paragraph after May 31, 
2006.
    (4) A refiner or importer may generate credits under this paragraph 
(c) and also generate credits under paragraph (a) of this section, and 
a small refiner, as defined under Sec. 80.550, may generate credits 
under this paragraph (c) and paragraph (e) of this section.
    (d) Additional requirements for early credits. Early credits 
generated under paragraphs (b) and (c) of this section are subject to 
the following additional requirements:
    (1) The designation requirements of Sec. 80.523, and all 
recordkeeping and annual reporting requirements of Secs. 80.592, 80.593 
and 80.594.
    (2) Credits generated under paragraphs (b) and (c) of this section 
shall be generated separately by CTA as defined in paragraph (a)(5) of 
this section and must be designated by CTA of generation, and by the 
refiner and refinery, or by importer and port of import, as applicable.
    (3) Credits may not be generated for the same fuel by both a 
foreign refiner and an importer.
    (4) The plan under paragraph (b)(2)(ii) or (c)(2)(ii) of this 
section must include provisions to include information on product 
transfer documents and on pump stands dispensing the fuel identifying 
the fuel as 15 ppm sulfur content motor vehicle diesel fuel. The plan 
must also identify the specific retail outlets or wholesale purchaser-
consumer facilities that the fuel will be provided to. The 
Administrator may require a refiner or importer to submit additional 
information, as needed.
    (5) In addition to the reporting requirements under paragraph 
(d)(1) of this section, the refiner or importer must submit a report to 
the Administrator no later than the last day of February for the prior 
calendar year period (or for the period June 1, 2001 through December 
31, 2001, the period June 1, 2005 through December 31, 2005, or the 
period January 1, 2006 through May 31, 2006, as applicable) 
demonstrating that all the motor vehicle diesel fuel produced or 
imported for which credits were generated met the applicable 
requirements of paragraph (b), (c), or (d)(4) of this section. If the 
Administrator finds that such credits did not in fact meet the 
requirements of paragraphs (b)(1) and (c)(1) of this section, as 
applicable, or if the Administrator determines that there is 
insufficient information to determine the validity of such credits, the 
Administrator may deny the credits submitted in whole or in part.
    (e) Credits generated by small refiners. (1) Notwithstanding the 
provisions of paragraph (a) of this section, a small refiner that is 
approved by the EPA as

[[Page 5141]]

a small refiner under Sec. 80.551(g) may generate credits under 
Sec. 80.552(b). Such a small refiner may generate one credit for each 
gallon of motor vehicle diesel fuel produced that is designated under 
Sec. 80.523 as subject to the 15 ppm sulfur standard under 
Sec. 80.520(a)(1).
    (2)(i) Credits may be generated under this paragraph (e) and 
Sec. 80.552(b) only during the compliance periods beginning June 1, 
2006 and ending on May 31, 2010. Credits shall be designated separately 
by refinery, separately by CTA of generation, and separately by annual 
compliance period. The annual compliance period for 2006 shall be June 
1, 2006 through December 31, 2006. The annual compliance period for 
2010 shall be January 1, 2010 through May 31, 2010.
    (ii) The small refiner must meet the requirements of paragraphs 
(d)(1), (d)(2) and (d)(3) of this section, and the recordkeeping and 
reporting requirements of Secs. 80.592, 80.593 and 80.594.
    (iii) In addition, a foreign refiner that is approved by the 
Administrator to generate credits under Sec. 80.552(b) shall comply 
with the requirements of Sec. 80.620.


Sec. 80.532  How are credits used and transferred?

    (a) Credit use. Credits generated under Sec. 80.531 may be used to 
meet the volume limit of Sec. 80.530(a)(3) provided that:
    (1) The credits were generated and reported according to the 
requirements of this subpart; and
    (2) The requirements of paragraphs (b), (c), (d), and (e) of this 
section are met.
    (b) Credits generated under Sec. 80.531 may be used by a refinery 
or by an importer to comply with section 80.530 by applying one credit 
for every gallon of motor vehicle diesel fuel needed to meet compliance 
with the volume limit of Sec. 80.530(a)(3).
    (c) Credits generated may be banked for use or transfer in a later 
compliance period or may be transferred to another refinery or importer 
for use as provided in paragraph (d) of this section.
    (d) Credit transfers. (1) Credits obtained from another refinery or 
from another importer, including early credits and small refiner 
credits as described in Sec. 80.531 (b), (c) (d), and (e), may be used 
to satisfy the volume limit of Sec. 80.530(a)(3) if all the following 
conditions are met:
    (i) The credits were generated in the same CTA as the CTA in which 
credits are used to achieve compliance;
    (ii) The credits are used in compliance with the time period 
limitations for credit use in this subpart;
    (iii) Any credit transfer takes place no later than the last day of 
February following the compliance period when the credits are used;
    (iv) No credit may be transferred more than twice, as follows: The 
first transfer by the refiner or importer who generated the credit may 
only be made to a refiner or importer who intends to use the credit; if 
the transferee cannot use the credit, it may make a second and final 
transfer only to a refiner or importer who intends to use the credit. 
In no case may a credit be transferred more than twice before being 
used or terminated;
    (v) The credit transferor must apply any credits necessary to meet 
the transferor's annual compliance requirements before transferring 
credits to any other refinery or importer;
    (vi) No credits may be transferred that would result in the 
transferor having a negative credit balance; and
    (vii) Each transferor must supply to the transferee records 
indicating the year the credits were generated, the identity of the 
refiner (and refinery) or importer who generated the credits, the CTA 
of credit generation, and the identity of the transferring party, if it 
is not the same party who generated the credits.
    (2) In the case of credits that have been calculated or created 
improperly, or are otherwise determined to be invalid, the following 
provisions apply:
    (i) Invalid credits cannot be used to achieve compliance with the 
transferee's volume requirements regardless of the transferee's good 
faith belief that the credits were valid.
    (ii) The refiner or importer who used the credits, and any 
transferor of the credits, must adjust their credit records, reports 
and compliance calculations as necessary to reflect the proper credits.
    (iii) Any properly created credits existing in the transferor's 
credit balance after correcting the credit balance, and after the 
transferor applies credits as needed to meet the compliance 
requirements at the end of the compliance period, must first be applied 
to correct the invalid transfers before the transferor trades or banks 
the credits.
    (e) Limitations on credit use. (1) Credits may not be used to 
achieve compliance with any requirements of this subpart other than the 
volume limit of Sec. 80.530(a)(3), unless specifically approved by the 
Administrator pursuant to a hardship relief petition under Sec. 80.560 
or Sec. 80.561.
    (2) A refiner or importer possessing credits must use all credits 
in its possession prior to applying the credit deficit provisions of 
Sec. 80.530(a)(6).
    (3) No credits may be used to meet compliance with this subpart 
subsequent to the compliance period ending May 31, 2010.


Secs. 80.533-80.539  [Reserved]

Geographic Phase-In Provisions


Sec. 80.540  How may a refiner be approved to produce gasoline under 
the GPA gasoline sulfur standards in 2007 and 2008?

    (a) A refiner that has been approved by EPA under Sec. 80.217 for 
the geographic phase-in area (GPA) gasoline sulfur content standards 
under Sec. 80.216 may apply to EPA for approval to produce gasoline 
subject to the GPA standards in 2007 and 2008. Such application shall 
be submitted to EPA, at the address provided in Sec. 80.595(b), by 
December 31, 2001. A foreign refiner must apply under the provisions of 
paragraph (n) of this section.
    (b) The refiner must submit an application in accordance with the 
provisions of Secs. 80.595 and 80.596. The application must also 
include information, as provided in Sec. 80.594(c), demonstrating that 
starting no later than June 1, 2006, all motor vehicle diesel fuel 
produced by the refinery for United States use will comply with the 15 
ppm sulfur content standard under Sec. 80.520(a)(1), and that the 
volume of motor vehicle diesel fuel produced will comply with the 
volume requirements of paragraph (e) of this section.
    (c) The Administrator may approve a refiner's application to 
produce gasoline subject to the GPA gasoline sulfur content standards 
in 2007 and 2008 if the provisions of paragraph (b) of this section are 
satisfied. In approving an application, the Administrator shall 
establish a motor vehicle diesel fuel volume baseline under 
Secs. 80.595 and 80.596.
    (d) Starting June 1, 2006, and continuing through December 31, 
2008, all motor vehicle diesel fuel produced by a refiner that has been 
approved under paragraph (c) of this section to produce gasoline 
subject to the GPA gasoline sulfur content standards in 2007 and 2008, 
must be accurately designated under Sec. 80.523 as meeting the 15 ppm 
sulfur content standard of Sec. 80.520(a)(1).
    (e) The total volume of motor vehicle diesel fuel produced for use 
in the United States and designated as meeting the 15 ppm sulfur 
content standard under paragraph (d) of this section must meet or 
exceed 85% of the baseline volume established under paragraph (c) of 
this section, except that for the year

[[Page 5142]]

2006, the total volume must meet or exceed 50% of the baseline volume.
    (f) Compliance with the volume requirements in paragraph (e) of 
this section shall be determined on a calendar year basis, except that 
for the year 2006 compliance shall be determined for the period June 1, 
2006 through December 31, 2006.
    (g) If a refiner fails to comply with the requirements of paragraph 
(d) of this section, or if the approval of the application, including 
the baseline, was based on false or inaccurate information, the 
approval to produce gasoline subject to the GPA gasoline sulfur content 
standards under this section during the years 2007 and 2008 shall be 
void ab initio, and gasoline produced for use in the GPA must meet the 
gasoline sulfur content standards of subpart H of this Part as if there 
had been no approval to produce gasoline subject to the GPA gasoline 
sulfur content standards in 2007 and 2008.
    (h) If for any compliance period a refiner fails to meet the volume 
requirements in paragraph (e) of this section, the approval to produce 
gasoline subject to the GPA gasoline sulfur content standards shall be 
void for that compliance period and for all succeeding compliance 
periods, and gasoline produced for use in the GPA must meet the 
gasoline sulfur standards under subpart H of this subpart as if there 
had been no approval to produce gasoline subject to the GPA gasoline 
sulfur content standards under this section in 2007 and 2008.
    (i) A refiner that is approved for production of gasoline subject 
to the GPA gasoline sulfur standards under this section in 2007 and 
2008 must meet all applicable recordkeeping and reporting requirements 
of Secs. 80.592, 80.593, and 80.594, and shall meet all the 
recordkeeping and reporting requirements under Secs. 80.219, 80.365 and 
80.370.
    (j) A refiner approved to produce gasoline subject to the GPA 
gasoline sulfur standards under this section in 2007 and 2008 may not 
generate or use credits under Sec. 80.531(a) or (e), or Sec. 80.532 
unless the approval is vacated as provided in paragraph (k) of this 
section.
    (k) A refiner may petition the Administrator to vacate approval to 
produce gasoline subject to the GPA gasoline sulfur content standards 
in 2007 and 2008. EPA may grant such a petition, effective January 1 of 
the compliance period following EPA's receipt of such petition (or 
effective June 1, in 2006, if applicable). Upon such effective date and 
thereafter, gasoline produced for use in the GPA must meet the gasoline 
sulfur content standards under subpart H of this Part as if there had 
been no approval to produce gasoline subject to the GPA gasoline sulfur 
content standards under this section in 2007 and 2008. Upon such 
effective date, the refiner shall not be subject to the requirements of 
this section.
    (l) The provisions of this section shall apply separately for each 
refinery of a refiner.
    (m) If any refinery is approved for production of gasoline subject 
to GPA gasoline sulfur content standards under this section in 2007 and 
2008, the GPA downstream gasoline sulfur standard under 
Sec. 80.220(a)(2) shall apply as follows:
    (1) During the period of February 1, 2005 through January 31, 2009, 
the sulfur content of GPA gasoline at any downstream location other 
than at a retail outlet or wholesale purchaser-consumer facility shall 
not exceed 326 ppm.
    (2) During the period of March 1, 2005 through February 28, 2009, 
the sulfur content of GPA gasoline at any downstream location shall not 
exceed 326 ppm.
    (n) A foreign refiner may apply to the Administrator to produce 
gasoline that is subject to the gasoline sulfur standards for GPA 
gasoline under Sec. 80.216 for the compliance years 2007 and 2008. Such 
application must be submitted to the EPA, at the address in 
Sec. 80.595(b), by December 31, 2001.
    (1) The Administrator may approve such interim GPA gasoline sulfur 
standards for the foreign refiner provided that the foreign refiner 
applies for a gasoline sulfur baseline under paragraph (n)(2) of this 
section and complies with:
    (i) The requirements of paragraphs (b) through (l) of this section;
    (ii) The requirements for the import of motor vehicle diesel fuel 
under Sec. 80.620; and
    (iii) All applicable gasoline requirements for refiners under 
subpart H of this Part, including the foreign refiner requirements 
under Sec. 80.410, the attest requirements of Sec. 80.415, the 
recordkeeping and reporting requirements of Secs. 80.365 and 80.370, 
the designation and product transfer document requirements of 
Sec. 80.219, the sampling and testing requirements of Sec. 80.330, and 
the sample retention requirements of Sec. 80.335.
    (2) The refiner must submit an application for a gasoline sulfur 
baseline under the provisions of Secs. 80.216(a), 80.295, and 
80.410(b).
    (3) After review of the foreign refiner's individual refinery 
gasoline sulfur baseline, its individual refinery motor vehicle diesel 
fuel baseline, and other information submitted with the application, 
the Administrator may approve such baselines and the application for 
GPA gasoline sulfur standards for 2007 and 2008.
    (o) An importer is not eligible for approval to import gasoline 
subject to the GPA standards in 2007 or 2008 under this section.


Secs. 80.541--80.549  [Reserved]

Small Refiner Hardship Provisions


Sec. 80.550  What is the definition of a small refiner under this 
subpart?

    (a) A small refiner is defined as any person, as defined by 42 
U.S.C. 7602(e), who:
    (1) Produces diesel fuel at a refinery by processing crude oil 
through refinery processing units;
    (2) Employed an average of no more than 1,500 people, based on the 
average number of employees for all pay periods from January 1, 1999, 
to January 1, 2000; and
    (3) Had an average crude capacity less than or equal to 155,000 
barrels per calendar day (bpcd) for 1999.
    (b) For the purpose of determining the number of employees and 
crude capacity under paragraph (a) of this section, the refiner shall 
include the employees and crude capacity of any subsidiary companies, 
any parent company and subsidiaries of the parent company in which the 
parent has 50% or greater ownership, and any joint venture partners.
    (c) The definition under paragraph (a) of this section applies to 
domestic and foreign refiners. For any refiner owned by a governmental 
entity, the number of employees as specified in paragraph (a) of this 
section shall include all employees and total crude capacity of the 
government of which the governmental entity is a part.
    (d) Notwithstanding the provisions of paragraph (a) of this 
section, a refiner that acquires a refinery after January 1, 2000, or 
reactivates a refinery that was shutdown or was non-operational between 
January 1, 1999, and January 1, 2000, may apply for small refiner 
status in accordance with the provisions of Sec. 80.551(c)(1)(ii).
    (e) Ineligible parties. The following are ineligible for the small 
refiner provisions:
    (1) Refiners or refineries built or started up after January 1, 
2000;
    (2) Persons who exceed the employee or crude oil capacity criteria 
under this section on January 1, 2000, but who meet these criteria 
after that date, regardless of whether the reduction in

[[Page 5143]]

employees or crude oil capacity is due to operational changes at the 
refinery or a company sale or reorganization;
    (3) Importers; and
    (4) Refiners who produce motor vehicle diesel fuel other than by 
processing crude oil through refinery processing units.
    (f)(1) Refiners who qualify as small refiners under this section 
and who subsequently employ more than 1500 people as a result of merger 
with or acquisition of another entity, are disqualified as small 
refiners. If this occurs, the refiner shall notify EPA in writing no 
later than 20 days following this disqualifying event.
    (2) Any refiner whose status changes under this paragraph shall 
comply with the sulfur standard of Sec. 80.520(a)(1) beginning January 
1 of the calendar year following the disqualifying event in paragraph 
(f)(1) of this section.
    (g) Notwithstanding the criteria in paragraph (a) of this section, 
any small refiner that has been approved by EPA as a small refiner 
under Sec. 80.235 and meets the criteria of paragraph (a)(1) of this 
section, will be considered a small refiner under this section as well, 
for as long as they are a small refiner under Sec. 80.225. The 
provisions of paragraph (f) of this section apply to any such refiner.


Sec. 80.551  How does a refiner obtain approval as a small refiner 
under this subpart?

    (a)(1) Applications for small refiner status must be submitted to 
EPA by December 31, 2001 as part of the refiner's registration under 
Sec. 80.597.
    (2) In the case of a refiner who acquires a refinery after January 
1, 2000, or reactivates a refinery that was shutdown between January 1, 
1999, and January 1, 2000, the application for small refiner status 
must be submitted to EPA by June 1, 2003.
    (b) Applications for small refiner status must be sent via 
certified mail with return receipt or express mail with return receipt 
to: U.S. EPA-Attn: Diesel Small Refiner Status (6406J), 1200 
Pennsylvania Avenue, NW (6406J), Washington, DC 20460 (certified mail/
return receipt) or Attn: Diesel Small Refiner Status, Transportation 
and Regional Programs Division,501 3rd Street, NW (6406J), Washington, 
DC 20001 (express mail/return receipt).
    (c) The small refiner status application must contain the following 
information for the company seeking small refiner status, plus any 
subsidiary companies, any parent company and subsidiaries of the parent 
company in which the parent has 50% or greater ownership, and any joint 
venture partners:
    (1)(i) A listing of the name and address of each location where any 
employee worked during the 12 months preceding January 1, 2000; the 
average number of employees at each location based upon the number of 
employees for each pay period for the 12 months preceding January 1, 
2000; and the type of business activities carried out at each location; 
or
    (ii) In the case of a refiner who acquires a refinery after January 
1, 2000, or reactivates a refinery that was shutdown between January 1, 
1999, and January 1, 2000, a listing of the name and address of each 
location where any employee of the refiner worked since the refiner 
acquired or reactivated the refinery; the average number of employees 
at any such acquired or reactivated refinery during each calendar year 
since the refiner acquired or reactivated the refinery; and the type of 
business activities carried out at each location.
    (2) The total corporate crude capacity of each refinery as reported 
to the Energy Information Administration (EIA) of the U.S. Department 
of Energy (DOE) for the most recent 12 months of operation. The 
information submitted to EIA is presumed to be correct. In cases where 
a company disagrees with this information, the company may petition EPA 
with appropriate data to correct the record when the company submits 
its application for small refiner status. EPA may accept such alternate 
data at its discretion.
    (3) An indication of whether the refiner, for each refinery, is 
applying for:
    (i) The ability to produce motor vehicle diesel fuel subject to the 
500 ppm sulfur content standard under Sec. 80.520(c) or generate 
credits under Sec. 80.531, pursuant to the provisions of Sec. 80.552(a) 
or (b); or
    (ii) An extension of the duration of its small refiner gasoline 
sulfur standard under Sec. 80.553, pursuant to the provisions of 
Sec. 80.552(c).
    (4) A letter signed by the president, chief operating or chief 
executive officer of the company, or his/her designee, stating that the 
information contained in the application is true to the best of his/her 
knowledge.
    (5) Name, address, phone number, facsimile number and e-mail 
address (if available) of a corporate contact person.
    (d) For joint ventures, the total number of employees includes the 
combined employee count of all corporate entities in the venture.
    (e) For government-owned refiners, the total employee count 
includes all government employees.
    (f) Approval of small refiner status for refiners who apply under 
Sec. 80.550(d) will be based on all information submitted under 
paragraph (c) of this section, except as provided in Sec. 80.550(d).
    (g) EPA will notify a refiner of approval or disapproval of small 
refiner status by letter. If disapproved, the refiner must comply with 
the sulfur standard in Sec. 80.520, except as otherwise provided in 
this subpart.
    (h) If EPA finds that a refiner provided false or inaccurate 
information on its application for small refiner status, upon notice 
from EPA the refiner's small refiner status will be void ab initio.
    (i) Upon notification to EPA, an approved small refiner may 
withdraw its status as a small refiner. Effective on January 1 of the 
year following such notification, the small refiner will become subject 
to the sulfur standard of Sec. 80.520 unless one of the hardship 
provisions of this subpart apply.


Sec. 80.552  What compliance options are available to small refiners?

    (a) A refiner that has been approved by EPA as a small refiner 
under Sec. 80.551(g) may produce motor vehicle diesel fuel subject to 
the 500 ppm sulfur content standard pursuant to the provisions of 
Sec. 80.530, except that the volume limits of Sec. 80.530(a)(3) shall 
only apply to that volume V\500\ of diesel fuel that is produced or 
imported during a calendar year that exceeds 105% of the baseline 
volume established under Sec. 80.595. The calendar year period shall be 
from January 1st through December 31st. For the period June 1, 2006 
through December 31, 2006, the volume limits shall only apply to that 
volume VV\500\ that exceeds 60% of the baseline volume.
    (b) A refiner that has been approved by EPA as a small refiner 
under Sec. 80.551(g) may generate motor vehicle diesel fuel credits 
pursuant to the provisions of Sec. 80.531, except that for purposes of 
Sec. 80.531(a) the term Credit shall equal VV\15\, without further 
adjustment.
    (c) A refiner that has been approved by EPA as a small refiner 
under Sec. 80.551(g) may apply for an extension of the duration of its 
small refiner gasoline sulfur standards pursuant to Sec. 80.553.
    (d) A refiner that produces motor vehicle diesel fuel under the 
provisions of paragraph (a) of this section or generates credits under 
the provisions of paragraph (b) of this section may not receive an 
extension of its small refiner gasoline sulfur standard under the 
provisions of paragraph (c) of this section. A refiner that receives an 
extension of its small refiner gasoline

[[Page 5144]]

sulfur standard under the provisions of paragraph (c) of this section 
may not produce motor vehicle diesel fuel under the provisions of 
paragraph (a) of this section and may not generate credits under the 
provisions of paragraph (b) of this section.
    (e) The provisions of this section shall apply separately for each 
refinery owned or operated by a small refiner.


Sec. 80.553  Under what conditions may the small refiner gasoline 
sulfur standards be extended for a small refiner of motor vehicle 
diesel fuel?

    (a) A refiner that has been approved by EPA for small refiner 
gasoline sulfur standards under Sec. 80.240 may apply, under 
Sec. 80.551, for an extension of the duration of its small refiner 
gasoline sulfur standards through the calendar year 2010 annual 
averaging period.
    (b) As part of its application, the refiner must submit an 
application for a motor vehicle diesel fuel baseline in accordance with 
the provisions of Secs. 80.595 and 80.596. The application must also 
include information, as provided in Sec. 80.594, demonstrating that 
starting no later than June 1, 2006, all motor vehicle diesel fuel 
produced by the refiner will comply with the 15 ppm sulfur content 
standard under Sec. 80.520(a)(1), and that the volume of motor vehicle 
diesel fuel produced will comply with the volume requirements of 
paragraph (e) of this section.
    (c) The Administrator may approve an application for extension of 
the small refiner gasoline sulfur standards if the provisions of 
paragraph (b) of this section and Secs. 80.595 and 80.596 are 
satisfied. In approving an application for extension, the Administrator 
shall establish a motor vehicle diesel fuel volume baseline under 
Secs. 80.595 and 80.596.
    (d) Beginning June 1, 2006, and continuing through December 31, 
2010, all motor vehicle diesel fuel produced by a refiner that has 
received an extension of its small refiner gasoline sulfur standards 
under this section must be accurately designated under Sec. 80.523 as 
meeting the 15 ppm sulfur content standard under Sec. 80.520(a)(1).
    (e) The total volume of motor vehicle diesel fuel produced for use 
in the United States and designated as meeting the 15 ppm sulfur 
content standard under paragraph (d) of this section must meet or 
exceed 85% of the baseline volume established under paragraph (c) of 
this section, except that for the year 2006, the total volume must meet 
or exceed 50% of the baseline volume.
    (f) Compliance with the volume requirements in paragraph (e) of 
this section shall be determined on a calendar year basis, except that 
for the year 2006 compliance shall be determined for the period June 1, 
2006 through December 31, 2006.
    (g) If a refiner fails to comply with the requirements of paragraph 
(d) of this section, or if approval of the application, including the 
baseline, was based on false or inaccurate information, the extension 
of the applicable small refiner gasoline sulfur standards under this 
section shall be void ab initio, and all gasoline produced by the 
refinery must meet the gasoline sulfur standards under subpart H of 
this Part as if there had been no extension of the small refiner 
gasoline sulfur standards.
    (h) If for any compliance period a refiner fails to meet the volume 
requirements in paragraph (e) of this section, the extension of the 
small refiner gasoline sulfur standards shall be void for that 
compliance period and for all succeeding compliance periods and all 
gasoline produced by the refinery must meet the gasoline sulfur 
standards under subpart H of this part as if there had been no 
extension of the small refiner gasoline sulfur standards under this 
section for such compliance periods.
    (i) A refiner that is approved for an extension of the interim 
small refiner gasoline sulfur standards under this section must meet 
all applicable recordkeeping and reporting requirements of 
Secs. 80.592, 80.593, and 80.594, and shall meet all the recordkeeping 
and reporting requirements under Secs. 80.210, 80.365 and 80.370. Any 
foreign refiner shall meet all additional requirements under 
Secs. 80.620 and 80.410.
    (j) A refiner approved for the small refiner gasoline sulfur 
standards extension under this section may not generate or use credits 
under Sec. 80.531(a) or (e), or Sec. 80.532.
    (k) A refiner may petition the Administrator to vacate an extension 
of the small refiner gasoline sulfur content standards. EPA may grant 
such a petition, effective January 1 of the compliance period following 
receipt of such petition (or effective June 1, 2006, if applicable). 
Upon such effective date, all gasoline produced by the refiner must 
meet the gasoline sulfur content standards under subpart H of this Part 
as if there had been no extension of the small refiner gasoline sulfur 
content standards under this section. Upon such effective date, the 
refiner shall not be subject to the requirements of this section.
    (l) The provisions of this section shall apply separately for each 
refinery of a refiner.


Secs. 80.554-80.559  [Reserved]

Other Hardship Provisions


Sec. 80.560  How can a refiner seek temporary relief from the 
requirements of this subpart in case of extreme hardship circumstances?

    (a) EPA may, at its discretion, grant a refiner, for one or more of 
its refineries, temporary relief from some or all of the provisions of 
this subpart. Such relief shall be no less stringent than the small 
refiner compliance options specified in Sec. 80.552. EPA may grant such 
relief provided that the refiner demonstrates that:
    (1) Unusual circumstances exist that impose extreme hardship and 
significantly affect the refiner's ability to comply by the applicable 
date; and
    (2) It has made best efforts to comply with the requirements of 
this subpart.
    (b) Applications must be submitted to EPA by June 1 2002 to the 
following address: Applications for small refiner status must be sent 
via certified mail with return receipt or express mail with return 
receipt to: U.S. EPA-Attn: Diesel Hardship (6406J), 1200 Pennsylvania 
Avenue, NW (6406J), Washington, DC 20460 (certified mail/return 
receipt) or Attn: Diesel Hardship, Transportation and Regional Programs 
Division, 501 3rd Street, NW (6406J), Washington, DC 20001 (express 
mail/return receipt). EPA reserves the right to deny applications for 
appropriate reasons, including unacceptable environmental impact. 
Approval to distribute motor vehicle diesel fuel not subject to the 15 
ppm sulfur standard may be granted for such time period as EPA 
determines is appropriate, but shall not extend beyond May 31, 2010.
    (c) Applications must include a plan demonstrating how the refiner 
will comply with the requirements of this subpart as expeditiously as 
possible. The plan shall include a showing that contracts are or will 
be in place for engineering and construction of desulfurization 
equipment a plan for applying for and obtaining any permits necessary 
for construction or operation, projected timeline for beginning and 
completing construction, and for beginning actual operation of such 
equipment, and a description of plans to obtain necessary capital, and 
a detailed estimate of when the requirements of this subpart will be 
met.
    (d) Applicants must provide, at a minimum, the following 
information:
    (1) Detailed description of efforts to obtain capital for refinery 
investments and efforts made to obtain credits for compliance under 
Sec. 80.531;
    (2) Bond rating of entity that owns the refinery (in the case of 
joint ventures,

[[Page 5145]]

include the bond rating of the joint venture entity and the bond 
ratings of all partners; in the case of corporations, include the bond 
ratings of any parent or subsidiary corporations); and
    (3) Estimated capital investment needed to comply with the 
requirements of this subpart by the applicable date.
    (e) In addition to the application requirements of paragraph (b) of 
this section, a refiner's application for temporary relief under this 
paragraph must also include a compliance plan. Such compliance plan 
shall demonstrate how the refiner will engage in a quality assurance 
testing program to ensure that its motor vehicle diesel fuel subject 
solely to the sulfur standards under Sec. 80.520(c) has not caused 
motor vehicle diesel fuel subject to the 15 ppm standard 
Sec. 80.520(a)(1) to fail to comply with that standard. The quality 
assurance program must at least include periodic sampling and testing 
at the party's own facilities and at downstream facilities in the 
refiner's or importer's diesel fuel distribution system, to determine 
compliance with the applicable sulfur standards for both categories of 
motor vehicle diesel fuel; examination at the party's own facilities 
and at applicable downstream facilities, of product transfer documents 
to confirm appropriate transfers and deliveries of both products; and 
inspection of retailer and wholesale purchaser-consumer pump stands for 
the presence of the labels and warning signs required under this 
section. Any violations that are discovered shall be reported to EPA 
within 48 hours of discovery.
    (f) Applications under this section must be accompanied by:
    (1) A letter signed by the president, chief operating or chief 
executive officer of the company, or his/her designee, stating that the 
information contained in the application is true to the best of his/her 
knowledge.
    (2) The name, address, phone number, facsimile number and e-mail 
address of a corporate contact person.
    (g) Applicants must also provide any other relevant information 
requested by EPA.
    (h) Refiners who are granted a hardship relief standard for any 
refinery, and importers of fuel subject to temporary refiner relief 
standards, may not distribute the diesel fuel subject to the sulfur 
standard under Sec. 80.520(c) for use in model year 2007 and later 
vehicles and must comply with all applicable provisions of this 
subpart, including the provisions of this subpart.
    (i) EPA may impose any reasonable conditions on waivers under this 
section, including limitations on the refinery's volume of motor 
vehicle diesel fuel subject to a temporary refiner relief standards.
    (j) The provisions of this section are available only to refineries 
that produce diesel fuel from crude.
    (k) The individual refinery sulfur standard and the compliance plan 
will be approved or disapproved by the Administrator, and approval will 
be effective when the refiner (or importer, as applicable, in the case 
of compliance plans) receives an approval letter from EPA. If 
disapproved, the refiner or importer must comply with the motor vehicle 
diesel fuel standard under Sec. 80.520(a)(1) by the appropriate 
compliance date specified in Sec. 80.500.
    (l) If EPA finds that a refiner provided false or inaccurate 
information on its application for small refiner status, upon notice 
from EPA the refiner's small refiner status will be void ab initio.


Sec. 80.561  How can a refiner or importer seek temporary relief from 
the requirements of this subpart in case of extreme unforseen 
circumstances?

    In appropriate extreme, unusual, and unforseen circumstances (e.g., 
natural disaster or refinery fire) which are clearly outside the 
control of the refiner or importer and which could not have been 
avoided by the exercise of prudence, diligence and due care, EPA may 
permit a refiner or importer, for a brief period, to distribute motor 
vehicle diesel fuel which does not meet the requirements of this 
subpart if:
    (a) It is in the public interest to do so (e.g., distribution of 
the nonconforming diesel fuel is necessary to meet projected shortfalls 
which cannot otherwise be compensated for);
    (b) The refiner or importer exercised prudent planning and was not 
able to avoid the violation and has taken all reasonable steps to 
minimize the extent of the nonconformity;
    (c) The refiner or importer can show how the requirements for motor 
vehicle diesel fuel will be expeditiously achieved;
    (d) The refiner or importer agrees to make up any air quality 
detriment associated with the nonconforming motor vehicle diesel fuel, 
where practicable;
    (e) The refiner or importer pays to the U.S. Treasury an amount 
equal to the economic benefit of the nonconformity minus the amount 
expended pursuant to paragraph (d) of this section, in making up the 
air quality detriment; and
    (f) In the case of motor vehicle diesel fuel distributed under this 
section that does not meet the 15 ppm sulfur standard under 
Sec. 80.520(a)(1), such diesel fuel shall not be distributed for use in 
model year 2007 or later motor vehicles, and must meet all the 
requirements and prohibitions of this subpart applicable to diesel fuel 
meeting the sulfur standard under Sec. 80.520(c), or to diesel fuel 
that is not motor vehicle diesel fuel, as applicable.


Secs. 80.562-80.569  [Reserved]

Labeling Requirements


Sec. 80.570  What labeling requirements apply to retailers and 
wholesale purchaser-consumers of motor vehicle diesel fuel?

    (a) Any retailer or wholesale purchaser-consumer who sells, 
dispenses, or offers for sale or dispensing, motor vehicle diesel fuel 
subject to the 500 ppm sulfur standard of Sec. 80.520(c), must 
prominently and conspicuously display in the immediate area of each 
pump stand from which motor vehicle fuel subject to the 500 ppm 
standard is offered for sale or dispensing, the following legible 
label, in block letters of no less than 36-point bold type, printed in 
a color contrasting with the background:

HIGH-SULFUR DIESEL FUEL--WARNING

May damage model year 2007 and later highway vehicles.
Federal Law prohibits use in these vehicles.

    (b) Any retailer or wholesale purchaser-consumer who sells, 
dispenses, or offers for sale or dispensing, motor vehicle diesel fuel 
subject to the 15 ppm sulfur standard of Sec. 80.520(a)(1), must affix 
the following conspicuous and legible label, in block letters of no 
less than 36-point bold type, and printed in a color contrasting with 
the background, to each pump stand:

LOW-SULFUR DIESEL FUEL

Recommended for use in all diesel vehicles.
Required for model year 2007 and later vehicles.

    (c) Any retailer or wholesale purchaser-consumer who sells, 
dispenses, or offers for sale or dispensing, diesel fuel for nonroad 
equipment that does not meet the standards for motor vehicle diesel 
fuel, must affix the following conspicuous and legible label, in block 
letters of no less than 36-point bold type, and printed in a color 
contrasting with the background, to each pump stand:

NONROAD DIESEL FUEL--WARNING

May damage or destroy highway engines and their emission controls.
Federal Law prohibits use in any highway vehicle.


[[Page 5146]]


    (d) The labels required by paragraphs (a) through (c) of this 
section must be placed on the vertical surface of each pump housing and 
on each side with gallonage and price meters. The labels shall be on 
the upper two-thirds of the pump, in a location where they are clearly 
readable by the public.


Secs. 80.571-80.579  [Reserved]

Sampling and Testing


Sec. 80.580  What are the sampling and testing methods for sulfur?

    (a) Diesel fuel and diesel fuel additives. For purposes of 
Secs. 80.520 and 80.521, the sulfur content of diesel and diesel fuel 
additives is to be determined in accordance with this section.
    (1) Sampling method. The applicable sampling methodology provided 
in Sec. 80.330(b).
    (2) Test method for sulfur. (i) For diesel fuel and diesel fuel 
additives subject to the 15 ppm sulfur standard of Sec. 80.520(a)(1), 
the American Society for Testing and Materials (ASTM) standard method D 
6428-99, entitled ``Test Method for Total Sulfur in Liquid Aromatic 
Hydrocarbons and Their Derivatives by Oxidative Combustion and 
Electrochemical Detection.''
    (ii) For diesel fuel and diesel fuel additives subject to the 500 
ppm sulfur standard of 80.520(c), ASTM standard method D 2622-98, 
``Standard Test Method for Sulfur in Petroleum Products by X-Ray 
Spectrometry.''
    (3) Alternative test methods for sulfur. (i) For diesel fuel and 
diesel fuel additives subject to the 15 ppm standard of 
Sec. 80.520(a)(1), sulfur content may be determined using ASTM D 5453-
99, entitled ``Standard Test Method for Determination of Total Sulfur 
in Light Hydrocarbons, Motor Fuels and Oils by Ultraviolet 
Fluorescence,'' or ASTM D 3120-96, entitled ``Standard Test Method for 
Trace Quantities of Sulfur in Light Liquid Petroleum Hydrocarbons by 
Oxidative Microcoulometry,'' provided that the refiner or importer test 
result is correlated with the appropriate method specified in paragraph 
(a)(2) of this section.
    (ii) For diesel fuel and diesel fuel additives subject to the 500 
ppm standard of Sec. 80.520(c), sulfur content may be determined using 
ASTM D 5453-99, ``Standard Test Method for Determination of Total 
Sulfur in Light Hydrocarbons, Motor Fuels and Oils by Ultraviolet 
Fluorescence,'' or ASTM D 6428-00, entitled ``Test Method for Total 
Sulfur in Liquid Aromatic Hydrocarbons and Their Derivatives by 
Oxidative Combustion and Electrochemical Detection,'' provided that the 
refiner or importer test result is correlated with the appropriate 
method specified in paragraph (a)(2) of this section.
    (4) Adjustment Factor for downstream test results. An adjustment 
factor of negative 2 ppm shall be applied to the test results, to 
account for test variability, but only for testing of motor vehicle 
diesel fuel identified as subject to the 15 ppm sulfur standard of 
Sec. 80.520(a)(1), at a downstream location as defined in 
Sec. 80.500(f).
    (b) Incorporation by reference. ASTM Standard Methods D 2622-98, 
``Standard Test Method for Sulfur in Petroleum Products by Wavelength 
Dispersive X-ray Fluorescence Spectrometry,'' D 3120-96, ``Standard 
Test Method for Trace Quantities of Sulfur in Light Liquid Petroleum 
Hydrocarbons by Oxidative Microcoulometry,'' D 6428-99, ``Test Method 
for Total Sulfur in Liquid Aromatic Hydrocarbons and Their Derivatives 
by Oxidative Combustion and Electrochemical Detection,'' and D 5453-00, 
``Standard Test Method for Determination of Total Sulfur in Light 
Hydrocarbons, Motor Fuels and Oils by Ultraviolet Fluorescence,'' are 
incorporated by reference. This incorporation by reference was approved 
by the Director of the Federal Register in accordance with 5 U.S.C. 
552(a) and 1 CFR part 51. Copies may be obtained from the American 
Society for Testing and Materials, 100 Barr Harbor Dr., West 
Conshohocken, PA 19428-2959. Copies may be inspected at the Air Docket 
Section (LE-131), Room M-1500, U.S. Environmental Protection Agency, 
Docket No. A-99-06, 401 M Street, SW, Washington, DC 20460, or at the 
Office of the Federal Register, 800 North Capitol Street, NW, Suite 
700, Washington, DC.


Secs. 80.581-80.589  [Reserved]

Recordkeeping and Reporting Requirements


Sec. 80.590  What are the product transfer document requirements for 
motor vehicle diesel fuel?

    On each occasion that any person transfers custody or title to 
motor vehicle diesel fuel, including distillates used or intended to be 
used as motor vehicle diesel fuel, except when such fuel is dispensed 
into motor vehicles at a retail outlet or wholesale purchaser-facility, 
the transferor must provide to the transferee documents identifying the 
fuel as motor vehicle diesel fuel, and which include the following 
information:
    (a) The name and address of the transferor and transferee.
    (b) The volume of motor vehicle diesel fuel which is being 
transferred.
    (c) The location of the motor vehicle diesel fuel at the time of 
the transfer.
    (d) The date of the transfer.
    (e) Except as provided in 40 CFR 69.51, an accurate statement, as 
applicable, that:
    (1) ``This fuel complies with the 15 ppm low sulfur standard for 
motor vehicle diesel fuel.'';
    (2) ``This fuel complies with the 500 ppm high sulfur standard for 
motor vehicle diesel fuel and is for use only in MY 2006 and older 
diesel motor vehicles.'';
    (3) ``This is high sulfur motor vehicle diesel fuel for use only in 
Guam, American Samoa, or the Northern Mariana Islands.'';
    (4) ``This diesel fuel is for export use only.'';
    (5) ``This diesel fuel is for research, development, or testing 
purposes only.'';
    (6) ``This diesel fuel is for use in diesel vehicles having an EPA-
approved national security exemption only.''.
    (f) For motor vehicle diesel fuel that contains visible evidence of 
the dye solvent red 164, and is intended to be used in a manner that is 
tax-exempt as defined under section 4082 of the Internal Revenue Code, 
the following statement:

    This fuel is motor vehicle diesel fuel for tax-exempt use only, 
in accordance with Section 4082 of the Internal Revenue Code.

    (g) Except for transfers to truck carriers, retailers or wholesale 
purchaser-consumers, product codes may be used to convey the 
information required under this section if such codes are clearly 
understood by each transferee. Codes used to convey the statement in 
paragraph (e)(1) of this section must contain the number ``15'', and 
codes used to convey the statement in paragraph (e)(2) of this section 
must contain the number ``500''.
    (h) Beginning June 1, 2001 and ending May 31, 2005, any transfer 
subject to this section, which is also subject to the early credit 
provisions of Sec. 80.531(b), must comply with all applicable 
requirements of this section except those in paragraph (e) of this 
section.
    (i) Beginning June 1, 2005 and ending May 31, 2006, any transfer 
subject to this section, which is also subject to the early credit 
requirements of Sec. 80.531(c), must comply with all applicable 
requirements of this section.


Sec. 80.591  What are the product transfer document requirements for 
additives to be used in diesel fuel?

    (a) Except as provided in paragraphs (b) and (d) of this section, 
on each

[[Page 5147]]

occasion that any person transfers custody or title to a motor vehicle 
diesel fuel additive to a party in the additive distribution system or 
in the motor vehicle diesel fuel distribution system for use downstream 
of the diesel fuel refiner, the transferor must provide to the 
transferee documents which identify the additive, and:
    (1) Identify the name and address of the transferor and transferee; 
the date of transfer; the location at which the transfer took place; 
the volume of additive transferred; and
    (2) Indicates compliance with the 15 ppm sulfur standard by 
inclusion of the following statement:

    The sulfur content of this diesel fuel additive does not exceed 
15 ppm.

    (b) On each occasion that any person transfers custody or title to 
a motor vehicle diesel fuel additive subject to the requirements of 
Sec. 80.521(b), to a party in the additive distribution system or in 
the motor vehicle diesel fuel distribution system for use in diesel 
fuel downstream of the diesel fuel refiner, the transferor must provide 
to the transferee documents which identify the additive, and:
    (1) Identify the name and address of the transferor and transferee; 
the date of transfer; the location at which the transfer took place; 
the volume of additive transferred.
    (2) Indicate the high sulfur potential of the additive by inclusion 
of the following statement:

    This motor vehicle diesel fuel additive may exceed the federal 
15 ppm sulfur standard. Improper use of this additive may result in 
non-complying diesel fuel.

    (3) Includes the following information:
    (i) The additive's maximum sulfur concentration;
    (ii) The maximum recommended concentration in volume percent for 
use of the additive in diesel fuel; and
    (iii) The contribution to the sulfur level of the fuel, in ppm, 
that would result if the additive is used at the maximum recommended 
concentration.
    (c) Except for transfers of motor vehicle diesel fuel additives to 
truck carriers, retailers or wholesale purchaser-consumers, product 
codes may be used to convey the information required under paragraphs 
(a) and (b) of this section, if such codes are clearly understood by 
each transferee. Codes used to convey the statement in paragraph (a)(2) 
of this section must contain the number ``15'' and codes used to convey 
the statement in paragraph (b)(2) of this section may not contain such 
number.
    (d) For those motor vehicle diesel fuel additives which are sold in 
containers for use by the ultimate consumer of diesel fuel, each 
transferor must have displayed on the additive container, in a legible 
and conspicuous manner, either of the following statements, as 
applicable:
    (1) ``This diesel fuel additive complies with the federal low 
sulfur content requirements for use in diesel motor vehicles.''; or
    (2) For those additives sold in containers for use by the ultimate 
consumer, with a sulfur content in excess of 15 ppm: ``This diesel fuel 
additive does not comply with federal low sulfur content requirements 
for use in model year 2007 and newer diesel motor vehicles.''.


Sec. 80.592  What records must be kept?

    (a) Records that must be kept by parties in the motor vehicle 
diesel fuel and motor vehicle diesel fuel additive distribution 
systems. Beginning June 1, 2006, or for a refiner the first compliance 
period in which the refiner is generating early credits under 
Sec. 80.531(b) or (c), whichever is earlier, any person who produces, 
imports, sells, offers for sale, dispenses, distributes, supplies, 
offers for supply, stores, or transports motor vehicle diesel fuel 
subject to the provisions of this subpart, must keep the following 
records:
    (1) The applicable product transfer documents required under 
Secs. 80.590 and 80.591;
    (2) For any sampling and testing for sulfur content, cetane index 
or aromatics content of motor vehicle diesel fuel or motor vehicle 
diesel fuel additives, conducted as part of a quality assurance program 
or otherwise:
    (i) The location, date, time and storage tank or truck 
identification for each sample collected;
    (ii) The name and title of the person who collected the sample and 
the person who performed the testing; and
    (iii) The results of the tests for sulfur content (including where 
applicable the test results with and without application of the 
adjustment factor under Sec. 80.580(a)(4)) or other standard content, 
and the volume of product in the storage tank or container from which 
the sample was taken;
    (3) The actions the party has taken, if any, to stop the sale or 
distribution of any motor vehicle diesel fuel found not to be in 
compliance with the sulfur standards specified in this subpart, and the 
actions the party has taken, if any, to identify the cause of any 
noncompliance and prevent future instances of noncompliance.
    (b) Additional records to be kept by refiners and importers of 
motor vehicle diesel fuel subject to temporary refiner relief 
standards, small refiner standards, and early credit provisions. 
Beginning June 1, 2006, or for a refiner the first compliance period in 
which the refiner is generating early credits under Sec. 80.531(b) or 
(c), whichever is earlier, any refiner producing motor vehicle diesel 
fuel subject to the sulfur standard under Sec. 80.520(a)(1), for each 
of its refineries, and any importer importing such motor vehicle diesel 
fuel, shall keep records that include the following information for 
each batch of motor vehicle diesel fuel produced or imported:
    (1) The batch volume.
    (2) The batch number, assigned under the batch numbering procedures 
under Sec. 80.65(d)(3).
    (3) The date of production or import.
    (4) A record designating the batch as meeting the 500 ppm sulfur 
standard or the 15 ppm sulfur standard.
    (5) For foreign refiners, the designations and other records 
required to be kept under Sec. 80.620.
    (6) In the case of importers, the designations and other records 
required under Sec. 80.620(o).
    (7) Information regarding credits, kept separately for each 
calendar year compliance period, kept separately for each refinery and 
in the case of importers, kept separately for imports into each CTA, as 
follows:
    (i) The number of credits in the refiner's or importer's possession 
at the beginning of the calendar year;
    (ii) The number of credits generated;
    (iii) The number of credits used;
    (iv) If any were obtained from or transferred to other parties, for 
each such other party, its name, its EPA refiner or importer 
registration number consistent with Sec. 80.593(d), in the case of 
credits generated by an importer the port and CTA of import of the 
diesel fuel that generated the credits, and the number obtained from, 
or transferred to, the other party;
    (v) The number in the refiner's or importer's possession that will 
carry over into the subsequent calendar year compliance period; and
    (vi) Commercial documents that establish each transfer of credits 
from the transferor to the transferee.
    (8) The calculations used to determine compliance with the volume 
requirements of this subpart.
    (9) The calculations used to determine the number of credits 
generated.
    (10) A copy of reports submitted to EPA under Sec. 80.593.
    (c) Additional records importers must keep. Any importer shall keep 
records

[[Page 5148]]

that identify and verify the source of each batch of certified diesel 
fuel program foreign refiner (DFR)-Diesel and non-certified DFR-Diesel 
imported and demonstrate compliance with the requirements under 
Sec. 80.620.
    (d) Length of time records must be kept. The records required in 
this section shall be kept for five years from the date they were 
created, except that records relating to credit transfers shall be kept 
by the transferor for 5 years from the date the credits were 
transferred, and shall be kept by the transferee for 5 years from the 
date the credits were transferred, used or terminated, whichever is 
later.
    (e) Make records available to EPA. On request by EPA the records 
required in paragraphs (a), (b) and (c) of this section must be made 
available to the Administrator or the Administrator's authorized 
representative. For records that are electronically generated or 
maintained the equipment and software necessary to read the records 
shall be made available, or if requested by EPA, electronic records 
shall be converted to paper documents which shall be provided to the 
Administrator's authorized representative.


Sec. 80.593  What are the reporting and registration requirements for 
refiners and importers of motor vehicle diesel fuel subject to 
temporary refiner relief standards?

    Beginning with 2006, or the first compliance period during which 
credits are generated under Sec. 80.531(b) or (c), whichever is 
earlier, any refiner or importer who produces or importes motor vehicle 
diesel fuel subject to the 500 ppm sulfur standard under 
Sec. 80.520(c), or any refiner or importer who generates, uses, obtains 
or transfers credits under Secs. 80.530 through 80.532, and continuing 
for each year thereafter, must submit to EPA annual reports that 
contain the information required in this section, and such other 
information as EPA may require:
    (a) Refiners and importers. Refiners and importers must report the 
following information separately for each refinery or CTA, in the case 
of importers, subject to a phase-in sulfur standard, small refiner 
standard or temporary refiner relief sulfur standard, or who generates, 
uses or transfers credits under Secs. 80.530 through 80.532:
    (1) The refiner's name and the EPA refinery registration number.
    (2) For all motor vehicle diesel fuel produced for use in the 
United States during the compliance period:
    (i) The total volume of motor vehicle diesel fuel produced;
    (ii) The volume, in gallons, that complied with a sulfur content 
standard of 500 ppm; and
    (iii) The volume, in gallons, that complied with the 15 ppm sulfur 
content standard.
    (3) The percentage of the volume motor vehicle diesel fuel produced 
during the calendar year that met the 15 ppm sulfur standard and the 
percentage that met the 500 ppm sulfur standard prior to the 
application of any volume credits.
    (4) The percentage of volume of motor vehicle diesel fuel produced 
meeting the 15 ppm sulfur standard after the inclusion of any credits.
    (5) Information regarding credits, separately for each refinery and 
for credits or debits related to imported motor diesel fuel, separately 
by importer and separately by CTA of import as follows:
    (i) The CTA of the refiner's refinery or the importer's or the 
foreign refiner's CTA and port of importation;
    (ii) The number of credits at the beginning of the compliance 
period;
    (iii) The number of credits generated;
    (iv) The number of credits used;
    (v) If any credits were obtained from or transferred to other 
refineries or import ports, for each other refinery or importer, its 
name, address (or Port) and CTA, EPA refinery or importer registration 
number, and the number of credits obtained from or transferred to the 
other refinery or importer (by import CTA);
    (vi) The number of credits, if any, that will carry over to the 
subsequent compliance period; and
    (vii) The number of credits in deficit that must be made up for the 
following year;
    (6) The reporting requirements under Sec. 80.620, if applicable.
    (7) For each batch of motor vehicle diesel fuel produced or 
imported during the compliance period:
    (i) The batch number assigned using the batch numbering conventions 
under Sec. 80.65(d)(3) and the appropriate designation under 
Sec. 80.523;
    (ii) The date the batch was produced; and
    (iii) The volume of the batch, in gallons.
    (8) When submitting reports under this paragraph (a), any importer 
shall exclude certified DFR-Diesel.
    (b) Additional reporting requirements for importers. Importers of 
motor vehicle diesel fuel subject to the 500 ppm sulfur standard must 
report the following information:
    (1) The importer's name and EPA registration number.
    (2) For each foreign refinery from which motor vehicle diesel fuel 
is imported that is subject to a sulfur standard under Sec. 80.520(c), 
the importer must report, for each batch of diesel fuel imported, the 
information required to be reported under Sec. 80.620(o).
    (c) Report submission. Any annual report required by this section 
shall be:
    (1) Signed and certified as meeting all the applicable requirements 
of this subpart by the owner or a responsible corporate officer of the 
refiner or importer; and
    (2) Submitted to EPA no later than the last day of February for the 
prior calendar year period.


Sec. 80.594  What are the pre-compliance reporting requirements?

    (a) Beginning on June 1, 2003, and on June 1, 2004 and June 1, 
2005, all refiners and importers planning to produce or import motor 
vehicle diesel fuel subject to the provisions of this subpart, shall 
submit the following information to EPA:
    (1) Any changes to the information submitted for the company 
registration;
    (2) Any changes to the information submitted for any refinery or 
import facility registration;
    (3) An estimate of the annual production or importation, in 
gallons, after June 1, 2006, for each refinery and import facility, of 
15 ppm motor vehicle diesel fuel produced from crude oil and, if 
applicable, 500 ppm motor vehicle diesel fuel produced from crude oil, 
and the volumes of each grade of motor vehicle diesel fuel produced 
from other sources;
    (4) If expecting to participate in the temporary compliance options 
provisions and the credit trading program, estimates of the number of 
credits to be generated and/or used each year the program is 
applicable;
    (5) Information regarding engineering plans (e.g., design and 
construction), the status of obtaining any necessary permits, and 
capital commitments for making the necessary modifications to produce 
low sulfur motor vehicle fuel, and actual construction progress. The 
pre-compliance reports due 2004 and 2005 must provide an update of the 
progress in each of these areas.
    (b) Beginning on June 1, 2003, all approved small refiners shall 
submit the following additional information to EPA, as applicable:
    (1) In the case of a refinery with an approved application under 
Sec. 80.552(a):
    (i) A showing that sufficient sources of 15 ppm motor vehicle 
diesel fuel will likely be available in its marketing area after June 
1, 2006 and through 2010;
    (ii) If after 2003 the sources of 15 ppm motor vehicle diesel fuel 
decrease, the pre-compliance reports for 2004 and/or

[[Page 5149]]

2005 must identify this change and must include a supplementary showing 
that the sources of 15 ppm motor vehicle diesel fuel are still 
sufficient.
    (2) In case of a refinery with an approved application under 
Sec. 80.552(c), a demonstration that by June 1, 2006 its motor vehicle 
diesel fuel will be at 15 ppm sulfur at a volume at least 85% of its 
baseline motor vehicle diesel fuel volume.
    (c) For each refiner and importer approved under Sec. 80.540, a 
demonstration that by June 1, 2006 all of its motor vehicle diesel fuel 
will be at 15 ppm sulfur at a volume of at least 85% of its baseline 
motor vehicle diesel fuel volume.
    (d) By July 1, 2006, each refiner and importer of motor vehicle 
diesel fuel shall submit a report to EPA stating that the production or 
importation of 15 ppm sulfur motor vehicle diesel fuel commenced by 
June 1, 2006.


Sec. 80.595  How does a refiner apply for a motor vehicle diesel fuel 
volume baseline?

    (a) Any small refiner applying for extension of the duration of its 
small refiner gasoline sulfur standards of Sec. 80.240, under 
Secs. 80.552(c) and 80.553, or any refiner applying for an extension of 
the duration of the GPA standards under Sec. 80.540 must apply for a 
motor vehicle diesel fuel volume baseline by December 31, 2001. A 
separate volume baseline must be sought for each refinery for which 
application of the provisions of Sec. 80.553 or Sec. 80.540 is sought.
    (b) The volume baseline must be sent via certified mail with return 
receipt or express mail with return receipt to: U.S. EPA-Attn: Diesel 
Baseline (6406J), 1200 Pennsylvania Avenue, NW (6406J), Washington, DC 
20460 (certified mail/return receipt) or Attn: Diesel Baseline, 
Transportation and Regional Programs Division, 501 3rd Street, NW 
(6406J), Washington, DC 20001 (express mail/return receipt).
    (c) The motor vehicle diesel fuel volume baseline application must 
include the following information:
    (1) A listing of the names and addresses of all refineries owned by 
the refiner for which the refiner is applying for a motor vehicle 
diesel fuel volume baseline.
    (2) The average annual volume (in gallons) of motor vehicle diesel 
fuel produced for U.S. use in 1998 and 1999, for each refinery for 
which the refiner is applying for such baseline, calculated in 
accordance with Sec. 80.596. The refiner shall follow the procedures, 
applicable to volume baselines and using motor vehicle diesel fuel 
instead of gasoline, specified in Secs. 80.91 through 80.93 to 
establish the volume of motor vehicle diesel fuel that was produced for 
U.S. use in 1998 and 1999 for purposes of establishing a volume 
baseline under this section.
    (3) A letter signed by the president, chief operating, or chief 
executive officer of the company, or his/her delegate, stating that the 
information contained in the volume baseline determination is true to 
the best of his/her knowledge.
    (4) Name, address, phone number, facsimile number, and e-mail 
address (if availabale) of a corporate contact person.
    (5) The following information for each batch of motor vehicle 
diesel fuel produced for U.S. use in 1998 and 1999:
    (i) Batch number assigned to the batch under procedures such as 
those in Sec. 80.65(d) or Sec. 80.101(i), or, if unavailable, such 
other identifying information as is available; and
    (ii) Volume of the batch, in gallons.
    (6) For a refinery that was not in operation during part or all of 
the period 1998 and 1999, the information required under this paragraph 
(c) for the motor vehicle diesel fuel produced for U.S. use during the 
most recent calendar year that the refinery was in operation after the 
refinery was reactivated.
    (d) Within 120 days of receipt of an application under this 
section, EPA will notify the refiner of an approval of the refinery's 
baseline, or of any deficiencies in the application.
    (e) If at any time the baseline submitted in accordance with the 
requirements of this section is determined to be incorrect, EPA will 
notify the refiner of the corrected baseline. The corrected baseline 
shall apply to all applicable compliance calculations under this 
subpart.
    (f)(1) If insufficient information is available for the 
Administrator to establish a baseline under the provisions of paragraph 
(c) of this section and Sec. 80.596(a), the refiner shall submit 
additional information sufficient for the Administrator to establish a 
baseline.
    (2) To satisfy the requirements of paragraph (f)(1) of this 
section, the Administrator may require, and consider, any information 
pertinent to establish a baseline, including:
    (i) Motor vehicle diesel fuel production volumes for other years;
    (ii) Crude capacity of the refinery;
    (iii) The ratio, or the typical ratio, for other similarly sized or 
configured refineries, between motor vehicle diesel fuel production and 
gasoline production.


Sec. 80.596  How is a refinery motor vehicle diesel fuel volume 
baseline calculated?

    (a) For purposes of this subpart, a refinery's motor vehicle diesel 
fuel volume baseline is calculated using the following equation:
[GRAPHIC] [TIFF OMITTED] TR18JA01.007

Where:
VBase = Volume baseline value.
Vi = Volume of motor vehicle diesel fuel batch i.
n = Total number of batches of motor vehicle diesel fuel produced 
for U.S. use during January 1, 1998 through December 31, 1999 (or 
the total number of batches of motor vehicle diesel fuel produced 
during the most recent calendar year the refinery was in operation 
after being reactivated pursuant to Sec. 80.595(c)(6)); or, for a 
foreign refinery, the total number of batches of motor vehicle 
diesel fuel produced and imported into the U.S. during January 1, 
1998 through December 31, 1999 (or the total number of batches of 
motor vehicle diesel fuel produced and imported into the U.S. during 
the most recent calendar year the refinery was in operation after 
being reactivated pursuant to Sec. 80.595(c)(6)).
i = Individual batch of motor vehicle diesel fuel produced during 
January 1, 1998 through December 31, 1999 (or individual batch of 
motor vehicle diesel fuel produced during the most recent calendar 
year the refinery was in operation after being reactivated pursuant 
to Sec. 80.595(c)(6)); or, for a foreign refinery, individual batch 
of motor vehicle diesel fuel produced and imported into the U.S. 
during January 1, 1998 through December 31, 1999 (or individual 
batch of motor vehicle diesel fuel produced and imported into the 
U.S. during the most recent calendar year the refinery was in 
operation after being reactivated pursuant to Sec. 80.595(c)(6)).
m = Number of months in the baseline period (24 except in the case 
of a startup or reactivation).

    (b) If insufficient information is available for the Administrator 
to establish a baseline under paragraph (a) of this section, the 
baseline may be determined under the provisions of Sec. 80.595(f).


Sec. 80.597  What are the registration requirements?

    Refiners having any refinery that is subject to a sulfur standard 
under Sec. 80.520(c), and importers importing such diesel fuel, must 
provide EPA the information under Sec. 80.76 no later than December 31, 
2001, if such information has not been provided under the provisions of 
this part. In addition, for each import facility, the same identifying 
information as required for each refinery under Sec. 80.76(c) must be 
provided.

[[Page 5150]]

Secs. 80.598-80.599  [Reserved]

Exemptions


Sec. 80.600  What are the requirements for obtaining an exemption for 
motor vehicle diesel fuel used for research, development or testing 
purposes?

    (a) Written request for R&D exemption. Any person may receive an 
exemption from the provisions of this subpart for motor vehicle diesel 
fuel used for research, development, or testing (``R&D'') purposes by 
submitting the information listed in paragraph (c) of this section to:
    (1) Director (6406J), Transportation and Regional Programs 
Division, U.S. Environmental Protection Agency, Ariel Rios Building, 
1200 Pennsylvania Avenue, NW., Washington, DC 20460 (postal mail); or
    (2) Director (6406J), Transportation and Regional Programs 
Division, U.S. Environmental Protection Agency, 501 3rd Street, NW., 
Washington, DC 20001 (express mail/courier); and
    (3) Director (2242A), Air Enforcement Division, U.S. Environmental 
Protection Agency, Ariel Rios Building, 1200 Pennsylvania Avenue, NW., 
Washington, DC 20460.
    (b) Criteria for an R&D exemption. For an R&D exemption to be 
granted, the person requesting an exemption must:
    (1) Demonstrate a purpose that constitutes an appropriate basis for 
exemption;
    (2) Demonstrate that an exemption is necessary;
    (3) Design an R&D program to be reasonable in scope; and
    (4) Exercise a degree of control consistent with the purpose of the 
program and EPA's monitoring requirements.
    (c) Information required to be submitted. To demonstrate each of 
the elements in paragraphs (b)(1) through (4) of this section, the 
person requesting an exemption must include the following information 
in the written request required under paragraph (a) of this section:
    (1) A concise statement of the purpose of the program demonstrating 
that the program has an appropriate R&D purpose.
    (2) An explanation of why the stated purpose of the program cannot 
be achieved in a practicable manner without performing one or more of 
the prohibited acts under this subpart.
    (3) To demonstrate the reasonableness of the scope of the program:
    (i) An estimate of the program's duration in time and, if 
appropriate, mileage;
    (ii) An estimate of the maximum number of vehicles or engines 
involved in the program;
    (iii) The manner in which the information on vehicles and engines 
used in the program will be recorded and made available to the 
Administrator upon request; and
    (iv) The quantity of diesel fuel which does not comply with the 
requirements of Secs. 80.520 through 80.525.
    (4) With regard to control, a demonstration that the program 
affords EPA a monitoring capability, including:
    (i) The site(s) of the program (including facility name, street 
address, city, county, state, and zip code);
    (ii) The manner in which information on vehicles and engines used 
in the program will be recorded and made available to the Administrator 
upon request;
    (iii) The manner in which information on the diesel fuel used in 
the program (including quantity, fuel properties, name, address, 
telephone number and contact person of the supplier, and the date 
received from the supplier), will be recorded and made available to the 
Administrator upon request;
    (iv) The manner in which the party will ensure that the R&D fuel 
will be segregated from motor vehicle diesel fuel and fuel pumps will 
be labeled to ensure proper use of the R&D diesel fuel;
    (v) The name, address, telephone number and title of the person(s) 
in the organization requesting an exemption from whom further 
information on the application may be obtained; and
    (vi) The name, address, telephone number and title of the person(s) 
in the organization requesting an exemption who is responsible for 
recording and making available the information specified in this 
paragraph (c), and the location where such information will be 
maintained.
    (d) Additional requirements. (1) The product transfer documents 
associated with R&D motor vehicle diesel fuel must comply with 
requirements of Sec. 80.590(b)(5).
    (2) The R&D diesel fuel must be designated by the refiner or 
supplier, as applicable, as R&D diesel fuel.
    (3) The R&D diesel fuel must be kept segregated from non-exempt 
motor vehicle diesel fuel at all points in the distribution system.
    (4) The R&D diesel fuel must not be sold, distributed, offered for 
sale or distribution, dispensed, supplied, offered for supply, 
transported to or from, or stored by a diesel fuel retail outlet, or by 
a wholesale purchaser-consumer facility, unless the wholesale 
purchaser-consumer facility is associated with the R&D program that 
uses the diesel fuel.
    (5) At the completion of the program, any emission control systems 
or elements of design which are damaged or rendered inoperative shall 
be replaced on vehicles remaining in service, or the responsible person 
will be liable for a violation of the Clean Air Act Section 203(a)(3) 
unless sufficient evidence is supplied that the emission controls or 
elements of design were not damaged.
    (e) Mechanism for granting of an exemption. A request for an R&D 
exemption will be deemed approved by the earlier of sixty (60) days 
from the date on which EPA receives the request for exemption, 
(provided that EPA has not notified the applicant of potential 
disapproval by that time), or the date on which the applicant receives 
a written approval letter from EPA.
    (1) The volume of diesel fuel subject to the approval shall not 
exceed the estimated amount in paragraph (c)(3)(iv) of this section, 
unless EPA grants a greater amount in writing.
    (2) Any exemption granted under this section will expire at the 
completion of the test program or three years from the date of 
approval, whichever occurs first, and may only be extended upon re-
application consistent will all requirements of this section.
    (3) The passage of sixty (60) days will not signify the acceptance 
by EPA of the validity of the information in the request for an 
exemption. EPA may elect at any time to review the information 
contained in the request, and where appropriate may notify the 
responsible person of disapproval of the exemption.
    (4) In granting an exemption the Administrator may include terms 
and conditions, including replacement of emission control devices or 
elements of design, that the Administrator determines are necessary for 
monitoring the exemption and for assuring that the purposes of this 
subpart are met.
    (5) Any violation of a term or condition of the exemption, or of 
any requirement of this section, will cause the exemption to be void ab 
initio.
    (6) If any information required under paragraph (c) of this section 
should change after approval of the exemption, the responsible person 
must notify EPA in writing immediately. Failure to do so may result in 
disapproval of the exemption or may make it void ab initio, and may 
make the party liable for a violation of this subpart.
    (f) Effects of exemption. Motor vehicle diesel fuel that is subject 
to an R&D exemption under this section is exempt from other provisions 
of this subpart provided that the fuel is used in a manner that 
complies with the purpose of the program under paragraph (c) of

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this section and the requirements of this section.
    (g) Notification of Completion. The party shall notify EPA in 
writing within thirty (30) days of completion of the R&D program.


Sec. 80.601  What requirements apply to motor vehicle diesel fuel for 
use in the Territories?

    The sulfur standards of Sec. 80.520(a)(1) and (c) do not apply to 
diesel fuel that is produced, imported, sold, offered for sale, 
supplied, offered for supply, stored, dispensed, or transported for use 
in the Territories of Guam, American Samoa or the Commonwealth of the 
Northern Mariana Islands provided that such diesel fuel is:
    (a) Designated by the refiner or importer as high sulfur diesel 
fuel only for use in Guam, American Samoa, or the Commonwealth of the 
Northern Mariana Islands;
    (b) Used only in Guam, American Samoa, or the Commonwealth of the 
Northern Mariana Islands;
    (c) Accompanied by documentation that complies with the product 
transfer document requirements of Sec. 80.590(e)(3); and
    (d) Segregated from non-exempt motor vehicle diesel fuel at all 
points in the distribution system from the point the diesel fuel is 
designated as exempt fuel only for use in Guam, American Samoa, or the 
Commonwealth of the Northern Mariana Islands, while the exempt fuel is 
in the United States but outside these Territories.


Sec. 80.602  What exemption applies to diesel fuel used in vehicles 
having a national security exemption from motor vehicle emissions 
standards?

    The motor vehicle diesel fuel standards of Sec. 80.520(a)(1), 
(a)(2), and (c) do not apply to diesel fuel that is produced, imported, 
sold, offered for sale, supplied, offered for supply, stored, 
dispensed, or transported for use in:
    (a) Vehicles for which EPA has granted a national security 
exemption under 40 CFR 85.1708 from motor vehicle emissions standards 
under 40 CFR Part 86; or
    (b) Tactical military motor vehicles that are not subject to a 
national security exemption from motor vehicle emissions standards but 
for national security purposes (for purposes of readiness for 
deployment oversees) need to be fueled on the same fuel as motor 
vehicles for which EPA has granted a national security exemption, 
provided that such fuel is:
    (1) Used only in vehicles identified in paragraph (a) of this 
section or this paragraph (b);
    (2) Accompanied by product transfer documents as required under 
Sec. 80.590;
    (3) Segregated from non-exempt motor vehicle diesel fuel at all 
points in the distribution system; and
    (4) Dispensed from a fuel pump stand, fueling truck or tank that is 
labeled under the provisions of Sec. 80.570(c). Any such fuel pump 
stand, fueling truck or tank may also be labeled with the appropriate 
designation of the fuel, such as ``JP-8''.


Sec. 80.603-80.609  [Reserved]

Violation Provisions


Sec. 80.610  What acts are prohibited under the diesel fuel sulfur 
program?

    No person shall:
    (a) Standard or dye violation. Produce, import, sell, offer for 
sale, dispense, supply, offer for supply, store or transport motor 
vehicle diesel fuel that does not comply with the applicable standards 
and dye requirements under Sec. 80.520.
    (b) Additive violation. (1) Produce, import, sell, offer for sale, 
dispense, supply, offer for supply, store or transport any motor 
vehicle diesel fuel additive for use at a downstream location that does 
not comply with the requirements under Sec. 80.521(a) or (b), as 
applicable.
    (2) Blend or permit the blending into motor vehicle diesel fuel at 
a downstream location, or use, or permit the use, as motor vehicle 
diesel fuel, of any additive which does not comply with the 
requirements of Sec. 80.521(a) or (b), as applicable.
    (c) Used motor oil violation. Introduce into the fuel system of 
model year 2007 or later diesel motor vehicles, or permit the 
introduction into the fuel system of such vehicles of used motor oil, 
or used motor oil blended with diesel fuel, which does not comply with 
the requirements of Sec. 80.522.
    (d) Improper fuel usage violation. (1) Introduce, or permit the 
introduction of, diesel fuel into model year 2007 or later diesel motor 
vehicles, and beginning December 1, 2010 into any diesel motor vehicle, 
which does not comply with the standards and dye requirements of 
Sec. 80.520(a) and (b).
    (2) Produce, import, sell, offer for sale, dispense, offer for 
supply, store, or transport for use in model year 2007 or later diesel 
motor vehicles, or introduce or permit the introduction into such motor 
vehicles, motor vehicle diesel fuel that is identified as other than 
diesel fuel complying with the 15 ppm sulfur standard; and beginning 
December 1, 2010, diesel fuel for use in or introduced into any diesel 
motor vehicle.
    (e) Cause another party to violate. Cause another person to commit 
an act in violation of paragraphs (a) through (d) of this section.
    (f) Cause violating fuel or additive to be in the distribution 
system. Cause motor vehicle diesel fuel to be in the motor vehicle 
diesel fuel distribution system which does not comply with the 
applicable standard and dye requirements of Sec. 80.520(a) and (b), or 
cause any motor vehicle diesel fuel additive to be in the motor vehicle 
diesel fuel additive distribution system which does not comply with the 
applicable sulfur, cetane, and/or aromatics standards of Sec. 80.521.


Sec. 80.611  What evidence may be used to determine compliance with the 
prohibitions and requirements of this subpart and liability for 
violations of this subpart?

    (a) Compliance with sulfur, cetane, and aromatics standards. 
Compliance with the standards in Secs. 80.520, 80.521, and 80.522 shall 
be determined based on the level of the applicable component or 
parameter, using the sampling methodologies specified in 
Sec. 80.330(b), as applicable, and the appropriate testing 
methodologies specified in Sec. 80.580(a)(2) for sulfur, or one of the 
alternative methodologies for sulfur as approved under 
Sec. 80.580(a)(3); Sec. 80.2(w) for cetane index; and Sec. 80.2(z) for 
aromatic content. Any evidence or information, including the exclusive 
use of such evidence or information, may be used to establish the level 
of the applicable component or parameter in the diesel fuel or 
additive, or motor oil to be used in diesel fuel, if the evidence or 
information is relevant to whether that level would have been in 
compliance with the standard if the regulatory sampling and testing 
methodology had been correctly performed. Such evidence may be obtained 
from any source or location and may include, but is not limited to, 
test results using methods other than the compliance methods in this 
paragraph (a), business records, and commercial documents.
    (b) Compliance with other requirements. Determination of compliance 
with the requirements of this subpart other than the standards 
described in paragraph (a) of this section and in Secs. 80.520, 80.521, 
and 80.522, and determination of liability for any violation of this 
subpart, may be based on information obtained from any source or 
location. Such information may include, but is not limited to, business 
records and commercial documents.

[[Page 5152]]

Sec. 80.612  Who is liable for violations of this subpart?

    (a) Persons liable for violations of prohibited acts.--(1) 
Standard, dye, additives, motor oil, and introduction violations. (i) 
Any refiner, importer, distributor, reseller, carrier, retailer, or 
wholesale purchaser-consumer who owned, leased, operated, controlled or 
supervised a facility where a violation of Sec. 80.610(a) through (d) 
occurred, or any other person who violates Sec. 80.610(a) through (d), 
is deemed liable for the applicable violation.
    (ii) Any person who causes another person to violate Sec. 80.610(a) 
through (d) is liable for a violation of Sec. 80.610(e).
    (iii) Any refiner, importer, distributor, reseller, carrier, 
retailer, or wholesale purchaser-consumer who produced, imported, sold, 
offered for sale, dispensed, supplied, offered to supply, stored, 
transported, or caused the transportation or storage of, motor vehicle 
diesel fuel that violates Sec. 80.610(a), is deemed in violation of 
Sec. 80.610(e).
    (iv) Any person who produced, imported, sold, offered for sale, 
dispensed, supplied, offered to supply, stored, transported, or caused 
the transportation or storage of a motor vehicle diesel fuel additive 
which is used in motor vehicle diesel fuel that is found to violate 
Sec. 80.610(a), is deemed in violation of Sec. 80.610(e).
    (2) Cause violating motor vehicle diesel fuel or additive to be in 
the distribution system. Any refiner, importer, distributor, reseller, 
carrier, retailer, or wholesale purchaser-consumer or any other person 
who owned, leased, operated, controlled or supervised a facility from 
which motor vehicle diesel fuel or additive was released into the motor 
vehicle diesel fuel or additive distribution system which does not 
comply with the applicable standards or dye requirements of Sec. 80.520 
or Sec. 80.521, is deemed in violation of Sec. 80.610(f).
    (3) Branded refiner/importer liability. Any refiner or importer 
whose corporate, trade, or brand name, or whose marketing subsidiary's 
corporate, trade, or brand name appeared at a facility where a 
violation of Sec. 80.610(a) occurred, is deemed in violation of 
Sec. 80.610(a).
    (4) Carrier causation. In order for a motor vehicle diesel fuel or 
motor vehicle diesel fuel additive carrier to be liable under paragraph 
(a)(1)(ii), (iii) or (iv) of this section, as applicable, EPA must 
demonstrate, by reasonably specific showing by direct or circumstantial 
evidence, that the carrier caused the violation.
    (5) Parent corporation. Any parent corporation is liable for any 
violations of this subpart that are committed by any subsidiary.
    (6) Joint venture. Each partner to a joint venture is jointly and 
severally liable for any violation of this subpart that occurs at the 
joint venture facility or is committed by the joint venture operation.
    (b) Persons liable for failure to comply with other provisions 
ofthis subpart. Any person who:
    (1) Fails to comply with the requirements of a provision of this 
subpart not addressed in paragraph (a) of this section is liable for a 
violation of that provision; or
    (2) Causes another person to fail to comply with the requirements 
of a provision of this subpart not addressed in paragraph (a) of this 
section, is liable for causing a violation of that provision.


Sec. 80.613  What defenses apply to persons deemed liable for a 
violation of a prohibited act?

    (a) Presumptive liability defenses. (1) Any person deemed liable 
for a violation of a prohibition under Sec. 80.612(a)(1)(i) or (iii), 
(a)(2), or (a)(3), will not be deemed in violation if the person 
demonstrates:
    (i) The violation was not caused by the person or the person's 
employee or agent;
    (ii) Product transfer documents account for fuel or additive found 
to be in violation and indicate that the violating product was in 
compliance with the applicable requirements when it was under the 
party's control;
    (iii) The person conducted a quality assurance sampling and testing 
program, as described in paragraph (d) of this section, except for 
those parties subject to the provisions of paragraph (a)(1)(iv) or (v) 
of this section. A carrier may rely on the quality assurance program 
carried out by another party, including the party who owns the diesel 
fuel in question, provided that the quality assurance program is 
carried out properly. Retailers, wholesale purchaser-consumers, and 
ultimate consumers of diesel fuel are not required to conduct quality 
assurance programs;
    (iv) For refiners and importers of motor vehicle diesel fuel 
subject to the 15 ppm standard under Sec. 80.520(a)(1), test results 
which:
    (A) Were conducted according to the test methodology required under 
Sec. 80.580 (a)(2) or an approved alternative test method under 
Sec. 80.580(a)(3); and
    (B) Establish that, when it left the party's control, the sulfur 
content of motor vehicle diesel fuel subject to the 15 ppm standard did 
not exceed 15 ppm; and
    (v) For any person who, at a downstream location, blends a diesel 
fuel additive subject to the requirements of Sec. 80.521(b) into motor 
vehicle diesel fuel subject to the sulfur standard under 
Sec. 80.520(a)(1), except a blender who blends additives into fuel 
trucks at a truck loading rack subject to the provisions of (d)(1) of 
this section, test results which are conducted subsequent to the 
blending of the additive into the fuel, and which comply with the 
requirements of paragraphs (a)(4)(iv)(A) and (B) of this section.
    (2) Any party deemed liable for a violation under 
Sec. 80.612(a)(1)(iv), in regard to a diesel fuel additive subject to 
the requirements of Sec. 80.521(a), will not be deemed in violation if 
the person demonstrates that:
    (i) Product transfer document(s) account for the additive in the 
fuel found to be in violation, which comply with the requirements under 
Sec. 80.591(a), and indicate that the additive was in compliance with 
the applicable requirements while it was under the party's control; and
    (ii) For the additive's manufacturer or importer, test results 
which accurately establish that, when it left the party's control, the 
additive in the diesel fuel determined to be in violation did not have 
a sulfur content in excess of 15 ppm.
    (A) Analysis of the additive sulfur content pursuant to this 
paragraph (a)(2) may be conducted at the time the batch was 
manufactured or imported, or on a sample of that batch which the 
manufacturer or importer retains for such purpose for a minimum of two 
years from the date the batch was manufactured or imported.
    (B) After two years from the date the additive batch was 
manufactured or imported, the additive manufacturer or importer is no 
longer required to retain samples for the purpose of complying with the 
testing requirements of this paragraph (a)(2) of this section.
    (C) The analysis of the sulfur content of the additive must be 
conducted pursuant to the requirements of Sec. 80.580(a).
    (3) Any person who is deemed liable for a violation under 
Sec. 80.612 (a)(1)(iv) with regard to a diesel fuel additive subject to 
the requirements of Sec. 80.521(b), will not be deemed in violation if 
the person demonstrates that:
    (i) The violation was not caused by the party or the party's 
employee or agent;

[[Page 5153]]

    (ii) Product transfer document(s) which comply with the additive 
information requirements under Sec. 80.591 (b), account for the 
additive in the fuel found to be in violation, and indicate that the 
additive was in compliance with the applicable requirements while it 
was under the party's control; and
    (iii) For the additive's manufacturer or importer, test results 
which accurately establish that, when it left the party's control, the 
additive in the diesel fuel determined to be in violation was in 
conformity with the information on the additive product transfer 
document pursuant to the requirements of Sec. 80.591(b). The testing 
procedures applicable under paragraph (a)(2) of this section, also 
apply under this paragraph (a)(3).
    (b) Branded refiner defenses. In the case of a violation found at a 
facility operating under the corporate, trade or brand name of a 
refiner or importer, or a refiner's or importer's marketing subsidiary, 
the refiner or importer must show, in addition to the defense elements 
required under paragraph (a)(1) of this section, that the violation was 
caused by:
    (1) An act in violation of law (other than the Clean Air Act or 
this Part 80), or an act of sabotage or vandalism;
    (2) The action of any refiner, importer, retailer, distributor, 
reseller, oxygenate blender, carrier, retailer or wholesale purchaser-
consumer in violation of a contractual agreement between the branded 
refiner or importer and the person designed to prevent such action, and 
despite periodic sampling and testing by the branded refiner or 
importer to ensure compliance with such contractual obligation; or
    (3) The action of any carrier or other distributor not subject to a 
contract with the refiner or importer, but engaged for transportation 
of diesel fuel, despite specifications or inspections of procedures and 
equipment which are reasonably calculated to prevent such action.
    (c) Causation demonstration. Under paragraph (a)(1) of this section 
for any person to show that a violation was not caused by that person, 
or under paragraph (b) of this section to show that a violation was 
caused by any of the specified actions, the person must demonstrate by 
reasonably specific showing, by direct or circumstantial evidence, that 
the violation was caused or must have been caused by another person and 
that the person asserting the defense did not contribute to that other 
person's causation.
    (d) Quality assurance and testing program. To demonstrate an 
acceptable quality assurance program under paragraph (a)(1)(iii) of 
this section, a person must present evidence of the following:
    (1) A periodic sampling and testing program to ensure the motor 
vehicle diesel fuel or additive the person sold, dispensed, supplied, 
stored, or transported, meets the applicable standards.
    (2) For those parties who, at a downstream location, blend diesel 
fuel additives subject to the requirements of Sec. 80.521(b) into fuel 
trucks at a truck loading rack, the periodic sampling and testing 
program required under this paragraph (d) must ensure, by taking into 
account the greater risk of noncompliance created through use of a high 
sulfur additive, that the diesel fuel into which the additive was 
blended meets the applicable standards subsequent to the blending.
    (3) On each occasion when motor vehicle diesel fuel or additive is 
found not in compliance with the applicable standard:
    (i) The person immediately ceases selling, offering for sale, 
dispensing, supplying, offering for supply, storing or transporting the 
non-complying product; and
    (ii) The person promptly remedies the violation and the factors 
that caused the violation (for example, by removing the non-complying 
product from the distribution system until the applicable standard is 
achieved and taking steps to prevent future violations of a similar 
nature from occurring).
    (4) For any carrier who transports motor vehicle diesel fuel or 
additive in a tank truck, the quality assurance program required under 
this paragraph (d) need not include its own periodic sampling and 
testing of the motor vehicle diesel fuel or additive in the tank truck, 
but in lieu of such tank truck sampling and testing, the carrier shall 
demonstrate evidence of an oversight program for monitoring compliance 
with the requirements of this subpart relating to the transport or 
storage of such product by tank truck, such as appropriate guidance to 
drivers regarding compliance with the applicable sulfur standard and 
product transfer document requirements, and the periodic review of 
records received in the ordinary course of business concerning motor 
vehicle diesel fuel or additive quality and delivery.


Sec. 80.614  What penalties apply under this subpart?

    (a) Any person liable for a violation under Sec. 80.612 is subject 
to civil penalties as specified in section 205 of the Clean Air Act for 
every day of each such violation and the amount of economic benefit or 
savings resulting from each violation.
    (b)(1) Any person liable under Sec. 80.612(a)(1) for a violation of 
an applicable standard or requirement under Sec. 80.520, or of causing 
another party to violate such standard or requirement, is subject to a 
separate day of violation for each and every day the non-complying 
motor vehicle diesel fuel remains any place in the distribution system.
    (2) Any person liable under Sec. 80.612(a)(2) for causing motor 
vehicle diesel fuel to be in the distribution system which does not 
comply with an applicable standard or requirement of Sec. 80.520, is 
subject to a separate day of violation for each and every day that the 
non-complying motor vehicle diesel fuel remains any place in the motor 
vehicle diesel fuel distribution system.
    (3) Any person liable under Sec. 80.612(a)(1) for blending into 
motor vehicle diesel fuel an additive violating the applicable sulfur 
standard pursuant to the requirements of Sec. 80.521(a) or (b), as 
appropriate, or of causing another party to so blend or add such an 
additive, is subject to a separate day of violation for each and every 
day the motor vehicle diesel fuel into which the noncomplying additive 
was blended, remains any place in the fuel distribution system.
    (4) For purposes of this paragraph (b), the length of time the 
motor vehicle diesel fuel in question remained in the motor vehicle 
diesel fuel distribution system is deemed to be twenty-five days, 
unless a person subject to liability or EPA demonstrates by reasonably 
specific showings, by direct or circumstantial evidence, that the non-
complying motor vehicle diesel fuel remained in the distribution system 
for fewer than or more than twenty-five days.
    (c) Any person liable under Sec. 80.612(b) for failure to meet, or 
causing a failure to meet, a provision of this subpart is liable for a 
separate day of violation for each and every day such provision remains 
unfulfilled.


Secs. 80.615-80.619  [Reserved]

Provisions for Foreign Refiners and Importers for Motor Vehicle 
Diesel Fuel Subject to a Temporary Compliance Option or Hardship 
Provision


Sec. 80.620  What are the additional requirements for motor vehicle 
diesel fuel produced by foreign refineries subject to a temporary 
refiner compliance option or hardship provisions?

    (a) Definitions. (1) A foreign refinery is a refinery that is 
located outside the

[[Page 5154]]

United States, the Commonwealth of Puerto Rico, the Virgin Islands, 
Guam, American Samoa, and the Commonwealth of the Northern Mariana 
Islands (collectively referred to in this section as ``the United 
States'').
    (2) A foreign refiner is a person who meets the definition of 
refiner under Sec. 80.2(i) for a foreign refinery.
    (3) A diesel fuel program foreign refiner (``DFR'') is a foreign 
refiner that has been approved by EPA for participation in any motor 
vehicle diesel fuel credits program, motor vehicle diesel fuel 
temporary compliance option, hardship or GPA provisions of Secs. 80.530 
through 80.532, Sec. 80.540, Sec. 80.552, Sec. 80.553, Sec. 80.560 or 
Sec. 80.561 (collectively referred to as ``diesel foreign refiner 
program'').
    (4) ``DFR-Diesel'' means motor vehicle diesel fuel produced at a 
DFR refinery that is imported into the United States.
    (5) ``Non-DFR-Diesel'' means motor vehicle diesel fuel that is 
produced at a foreign refinery that has not been approved as a DFR 
foreign refiner, motor vehicle diesel fuel produced at a DFR foreign 
refinery that is not imported into the United States, and motor vehicle 
diesel fuel produced at a DFR foreign refinery during a period when the 
foreign refiner has opted to not participate in the DFR-Diesel diesel 
foreign refiner program under paragraph (c)(3) of this section.
    (6) ``Certified DFR-Diesel'' means DFR-Diesel the foreign refiner 
intends to include in the foreign refinery's compliance calculations 
under Secs. 80.530 through 80.532, Sec. 80.540, Sec. 80.552, 
Sec. 80.553, Sec. 80.560 or Sec. 80.561 and does include in these 
compliance calculations when reported to EPA.
    (7) ``Non-Certified DFR-Diesel'' means DFR-Diesel fuel that a DFR 
foreign refiner imports to the United States that is not Certified DFR-
Diesel.
    (b) Baseline. For any foreign refiner to obtain approval under the 
diesel foreign refiner program of this subpart for any refinery, it 
must apply for approval under the applicable provisions of this 
subpart. To obtain approval the refiner is required, as applicable, to 
demonstrate a volume baseline for calendar years 1998 and 1999 for 
motor vehicle diesel fuel produced for use in the United States under 
Secs. 80.595 and 80.596.
    (1) The refiner shall follow the procedures, applicable to volume 
baselines and using motor vehicle diesel fuel instead of gasoline, in 
Secs. 80.91 through 80.93 to establish the volume of motor vehicle 
diesel fuel that was produced at the refinery and imported into the 
United States during 1998 and 1999 for purposes of establishing a 
baseline under Secs. 80.595 and 80.596.
    (2) In making determinations for foreign refinery baselines EPA 
will consider all information supplied by a foreign refiner, and in 
addition may rely on any and all appropriate assumptions necessary to 
make such determinations.
    (3) Where a foreign refiner submits a petition that is incomplete 
or inadequate to establish an accurate baseline, and the refiner fails 
to correct this deficiency after a request for more information, EPA 
will not assign an individual refinery motor vehicle diesel fuel volume 
baseline.
    (c) General requirements for DFR foreign refiners. A foreign 
refiner of a refinery that is approved under the diesel foreign refiner 
program of this subpart must designate each batch of motor vehicle 
diesel fuel produced at the foreign refinery that is exported to the 
United States as either Certified DFR-Diesel or as Non-Certified DFR-
Diesel, except as provided in paragraph (c)(3) of this section. It must 
further designate all Certified DFR-Diesel as complying with either the 
15 ppm sulfur standard under Sec. 80.520(a)(1) or the 500 ppm sulfur 
standard under Sec. 80.520(c).
    (1) In the case of Certified DFR-Diesel, the foreign refiner must 
meet all requirements that apply to refiners under this subpart, except 
that:
    (i) For purposes of complying with the compliance option 
requirements of Sec. 80.530, motor vehicle diesel fuel produced by a 
foreign refinery must comply separately for each Credit Trading Area of 
import, as defined in Sec. 80.531(a)(5).
    (ii) For purposes of complying with the compliance option 
requirements of Sec. 80.530, credits obtained from any other refinery 
or from any importer must have been generated in the same Credit 
Trading Area as the Credit Trading Area of import of the fuel for which 
credits are needed to achieve compliance.
    (iii) For purposes of generating credits under this subpart, 
credits shall be generated separately by Credit Trading Area of import 
and shall be designated by Credit Trading Area of importation and by 
port of importation.
    (2) In the case of Non-Certified DFR-Diesel, the foreign refiner 
shall meet all the following requirements:
    (i) The designation requirements in this section.
    (ii) The reporting requirements in this section and Sec. 80.593.
    (iii) The product transfer document requirements in this section.
    (iv) The prohibitions in this section and Sec. 80.610.
    (3)(i) Any foreign refiner that has been approved to produce motor 
vehicle diesel fuel subject to the diesel foreign refiner program for a 
foreign refinery under this subpart may elect to classify no diesel 
fuel imported into the United States as DFR-Diesel provided the foreign 
refiner notifies EPA of the election no later than November 1 of the 
prior calendar year.
    (ii) An election under paragraph (c)(3)(i) of this section shall be 
for an entire calendar year and apply to all motor vehicle diesel fuel 
that is produced by the foreign refinery that is imported into the 
United States, and shall remain in effect for each succeeding year 
unless and until the foreign refiner notifies EPA of the termination of 
the election. The change in election shall take effect at the beginning 
of the next calendar year.
    (d) Designation, product transfer documents, and foreign refiner 
certification. (1) Any foreign refiner of a foreign refinery that has 
been approved by EPA to produce motor vehicle diesel fuel subject to 
the diesel foreign refiner program must designate each batch of DFR-
Diesel as such at the time the diesel fuel is produced, unless the 
refiner has elected to classify no diesel fuel exported to the United 
States as DFR-Diesel under paragraph (c)(3) of this section.
    (2) On each occasion when any person transfers custody or title to 
any DFR-Diesel prior to its being imported into the United States, it 
must include the following information as part of the product transfer 
document information in this section:
    (i) Identification of the diesel fuel as Certified DFR-Diesel or as 
Non-Certified DFR-Diesel, and if it is Certified DFR-Diesel, further 
designation as meeting the 500 ppm sulfur standard under Sec. 80.520(c) 
or the 15 ppm sulfur standard under Sec. 80.520(a)(1) pursuant to 
Sec. 80.523; and
    (ii) The name and EPA refinery registration number (under 
Sec. 80.593) of the refinery where the DFR-Diesel was produced.
    (3) On each occasion when DFR-Diesel is loaded onto a vessel or 
other transportation mode for transport to the United States, the 
foreign refiner shall prepare a certification for each batch of the 
DFR-Diesel that meets the following requirements.
    (i) The certification shall include the report of the independent 
third party under paragraph (f) of this section, and the following 
additional information:
    (A) The name and EPA registration number of the refinery that 
produced the DFR-Diesel;

[[Page 5155]]

    (B) The identification of the diesel fuel as Certified DFR-Diesel 
or Non-Certified DFR-Diesel;
    (C) The volume of DFR-Diesel being transported, in gallons;
    (D) In the case of Certified DFR-Diesel:
    (1) The sulfur content as determined under paragraph (f) of this 
section, and the designation of the fuel as complying with the 15 ppm 
sulfur content standard for motor vehicle diesel fuel under 
Sec. 80.520(a)(1) or the 500 ppm sulfur content standard for motor 
vehicle diesel fuel under Sec. 80.520(c); and
    (2) A declaration that the DFR-Diesel is being included in the 
applicable compliance calculations required by the EPA under this 
subpart.
    (ii) The certification shall be made part of the product transfer 
documents for the DFR-Diesel.
    (e) Transfers of DFR-Diesel to non-United States markets. The 
foreign refiner is responsible to ensure that all diesel fuel 
classified as DFR-Diesel is imported into the United States. A foreign 
refiner may remove the DFR-Diesel classification, and the diesel fuel 
need not be imported into the United States, but only if:
    (1)(i) The foreign refiner excludes:
    (A) The volume of diesel from the refinery's compliance report 
under Sec. 80.593; and
    (B) In the case of Certified DFR-Diesel, the volume of the diesel 
fuel from the compliance report under Sec. 80.593.
    (ii) The exclusions under paragraph (e)(1)(i) of this section shall 
be on the basis of the designations under Sec. 80.523 and volumes 
determined under paragraph (f) of this section.
    (2) The foreign refiner obtains sufficient evidence in the form of 
documentation that the diesel fuel was not imported into the United 
States.
    (f) Load port independent sampling, testing and refinery 
identification. (1) On each occasion that DFR-Diesel is loaded onto a 
vessel for transport to the United States a foreign refiner shall have 
an independent third party:
    (i) Inspect the vessel prior to loading and determine the volume of 
any tank bottoms;
    (ii) Determine the volume of DFR-Diesel loaded onto the vessel 
(exclusive of any tank bottoms before loading);
    (iii) Obtain the EPA-assigned registration number of the foreign 
refinery;
    (iv) Determine the name and country of registration of the vessel 
used to transport the DFR-Diesel to the United States; and
    (v) Determine the date and time the vessel departs the port serving 
the foreign refinery.
    (2) On each occasion that Certified DFR-Diesel is loaded onto a 
vessel for transport to the United States a foreign refiner shall have 
an independent third party:
    (i) Collect a representative sample of the Certified DFR-Diesel 
from each vessel compartment subsequent to loading on the vessel and 
prior to departure of the vessel from the port serving the foreign 
refinery;
    (ii) Determine the sulfur content value for each compartment using 
the methodology specified in Sec. 80.580 by:
    (A) The third party analyzing each sample; or
    (B) The third party observing the foreign refiner analyze the 
sample;
    (iii) Review original documents that reflect movement and storage 
of the certified DFR-Diesel from the refinery to the load port, and 
from this review determine:
    (A) The refinery at which the DFR-Diesel was produced; and
    (B) That the DFR-Diesel remained segregated from:
    (1) Non-DFR-Diesel and Non-Certified DFR-Diesel; and
    (2) Other Certified DFR-Diesel produced at a different refinery.
    (3) The independent third party shall submit a report:
    (i) To the foreign refiner containing the information required 
under paragraphs (f)(1) and (f)(2) of this section, to accompany the 
product transfer documents for the vessel; and
    (ii) To the Administrator containing the information required under 
paragraphs (f)(1) and (f)(2) of this section, within thirty days 
following the date of the independent third party's inspection. This 
report shall include a description of the method used to determine the 
identity of the refinery at which the diesel fuel was produced, 
assurance that the diesel fuel remained segregated as specified in 
paragraph (n)(1) of this section, and a description of the diesel 
fuel's movement and storage between production at the source refinery 
and vessel loading.
    (4) The independent third party must:
    (i) Be approved in advance by EPA, based on a demonstration of 
ability to perform the procedures required in this paragraph (f);
    (ii) Be independent under the criteria specified in 
Sec. 80.65(e)(2)(iii); and
    (iii) Sign a commitment that contains the provisions specified in 
paragraph (i) of this section with regard to activities, facilities and 
documents relevant to compliance with the requirements of this 
paragraph (f).
    (g) Comparison of load port and port of entry testing. (1) Load 
port and port of entry testing requirements, as follows:
    (i) Any foreign refiner and any United States importer of Certified 
DFR-Diesel shall compare the results from the load port testing under 
paragraph (f) of this section, with the port of entry testing as 
reported under paragraph (o) of this section, for the volume of diesel 
and the sulfur value; except that
    (ii) Where a vessel transporting Certified DFR-Diesel off loads 
this diesel fuel at more than one United States port of entry, and the 
conditions of paragraph (g)(2)(i) of this section are met at the first 
United States port of entry, the requirements of paragraph (g)(2) of 
this section do not apply at subsequent ports of entry if the United 
States importer obtains a certification from the vessel owner that 
meets the requirements of paragraph(s) of this section, that the vessel 
has not loaded any diesel fuel or blendstock between the first United 
States port of entry and the subsequent port of entry.
    (2)(i) The requirements of this paragraph (g)(2) apply if:
    (A) The temperature-corrected volumes determined at the port of 
entry and at the load port differ by more than one percent; or
    (B) The sulfur value determined at the port of entry is higher than 
the sulfur value determined at the load port, and the amount of this 
difference is greater than the reproducibility amount specified for the 
port of entry test result by the American Society of Testing and 
Materials (ASTM).
    (ii) The United States importer and the foreign refiner shall treat 
the diesel fuel as Non-Certified DFR-Diesel, and the foreign refiner 
shall exclude the diesel fuel volume from its motor vehicle diesel fuel 
volumes calculations and sulfur standard designations under 
Sec. 80.523.
    (h) Attest requirements. Refiners, for each calendar year, must 
arrange to have an attest engagement performed of the underlying 
documentation that forms the basis of any report required under this 
subpart. The attest engagement must comply with the procedures and 
requirements that apply to refiners under Secs. 80.125 through 80.130 
and must be submitted to the Administrator of EPA by May 30 of each 
year for the prior calendar year. The following additional procedures 
shall be carried out for any foreign refiner of DFR-Diesel:
    (1) The inventory reconciliation analysis under Sec. 80.128(b) and 
the tender analysis under Sec. 80.128(c) shall include Non-DFR-Diesel.
    (2) Obtain separate listings of all tenders of Certified DFR-Diesel 
and of Non-Certified DFR-Diesel, and obtain separate listings of 
Certified DFR-Diesel

[[Page 5156]]

based on whether it is 15 ppm sulfur content motor vehicle diesel fuel 
or 500 ppm sulfur content motor vehicle diesel fuel. Agree the total 
volume of tenders from the listings to the diesel fuel inventory 
reconciliation analysis in Sec. 80.128(b), and to the volumes 
determined by the third party under paragraph (f)(1) of this section.
    (3) For each tender under paragraph (h)(2) of this section, where 
the diesel fuel is loaded onto a marine vessel, report as a finding the 
name and country of registration of each vessel, and the volumes of 
DFR-Diesel loaded onto each vessel.
    (4) Select a sample from the list of vessels identified in 
paragraph (h)(3) of this section used to transport Certified DFR-
Diesel, in accordance with the guidelines in Sec. 80.127, and for each 
vessel selected perform the following:
    (i) Obtain the report of the independent third party, under 
paragraph (f) of this section, and of the United States importer under 
paragraph (o) of this section.
    (A) Agree the information in these reports with regard to vessel 
identification, diesel fuel volumes and sulfur content test results.
    (B) Identify, and report as a finding, each occasion the load port 
and port of entry sulfur content and volume results differ by more than 
the amounts allowed in paragraph (g) of this section, and determine 
whether the foreign refiner adjusted its refinery calculations as 
required in paragraph (g) of this section.
    (ii) Obtain the documents used by the independent third party to 
determine transportation and storage of the Certified DFR-Diesel from 
the refinery to the load port, under paragraph (f) of this section. 
Obtain tank activity records for any storage tank where the Certified 
DFR-Diesel is stored, and pipeline activity records for any pipeline 
used to transport the Certified DFR-Diesel, prior to being loaded onto 
the vessel. Use these records to determine whether the Certified DFR-
Diesel was produced at the refinery that is the subject of the attest 
engagement, and whether the Certified DFR-Diesel was mixed with any 
Non-Certified DFR-Diesel, Non-DFR-Diesel, or any Certified DFR-Diesel 
produced at a different refinery.
    (5) Select a sample from the list of vessels identified in 
paragraph (h)(3) of this section used to transport certified and Non-
Certified DFR-Diesel, in accordance with the guidelines in Sec. 80.127, 
and for each vessel selected perform the following:
    (i) Obtain a commercial document of general circulation that lists 
vessel arrivals and departures, and that includes the port and date of 
departure of the vessel, and the port of entry and date of arrival of 
the vessel.
    (ii) Agree the vessel's departure and arrival locations and dates 
from the independent third party and United States importer reports to 
the information contained in the commercial document.
    (6) Obtain separate listings of all tenders of Non-DFR-Diesel, and 
perform the following:
    (i) Agree the total volume and sulfur content of tenders from the 
listings to the diesel fuel inventory reconciliation analysis in 
Sec. 80.128(b).
    (ii) Obtain a separate listing of the tenders under this paragraph 
(h)(6) where the diesel fuel is loaded onto a marine vessel. Select a 
sample from this listing in accordance with the guidelines in 
Sec. 80.127, and obtain a commercial document of general circulation 
that lists vessel arrivals and departures, and that includes the port 
and date of departure and the ports and dates where the diesel fuel was 
off loaded for the selected vessels. Determine and report as a finding 
the country where the diesel fuel was off loaded for each vessel 
selected.
    (7) In order to complete the requirements of this paragraph (h) an 
auditor shall:
    (i) Be independent of the foreign refiner;
    (ii) Be licensed as a Certified Public Accountant in the United 
States and a citizen of the United States, or be approved in advance by 
EPA based on a demonstration of ability to perform the procedures 
required in Secs. 80.125 through 80.130 and this paragraph (h); and
    (iii) Sign a commitment that contains the provisions specified in 
paragraph (i) of this section with regard to activities and documents 
relevant to compliance with the requirements of Secs. 80.125 through 
80.130 and this paragraph (h).
    (i) Foreign refiner commitments. Any foreign refiner shall commit 
to and comply with the provisions contained in this paragraph (i) as a 
condition to being approved for a temporary refiner diesel fuel program 
option.
    (1) Any United States Environmental Protection Agency inspector or 
auditor must be given full, complete and immediate access to conduct 
inspections and audits of the foreign refinery.
    (i) Inspections and audits may be either announced in advance by 
EPA, or unannounced.
    (ii) Access will be provided to any location where:
    (A) Diesel fuel is produced;
    (B) Documents related to refinery operations are kept;
    (C) Diesel fuel or blendstock samples are tested or stored; and
    (D) DFR-Diesel is stored or transported between the foreign 
refinery and the United States, including storage tanks, vessels and 
pipelines.
    (iii) Inspections and audits may be by EPA employees or contractors 
to EPA.
    (iv) Any documents requested that are related to matters covered by 
inspections and audits must be provided to an EPA inspector or auditor 
on request.
    (v) Inspections and audits by EPA may include review and copying of 
any documents related to:
    (A) Refinery baseline establishment, if applicable, including the 
volume and sulfur content; transfers of title or custody of any diesel 
fuel or blendstocks whether DFR-Diesel or Non-DFR-Diesel, produced at 
the foreign refinery during the period January 1, 1998 through the date 
of the refinery baseline petition or through the date of the inspection 
or audit if a baseline petition has not been approved, and any work 
papers related to refinery baseline establishment;
    (B) The volume and sulfur content of DFR-Diesel;
    (C) The proper classification of diesel fuel as being DFR-Diesel or 
as not being DFR-Diesel, or as Certified DFR-Diesel or as Non-Certified 
DFR-Diesel, or as meeting the 15 ppm sulfur standard under 
Sec. 80.520(a)(1) or the 500 ppm sulfur standard under Sec. 80.520(c);
    (D) Transfers of title or custody to DFR-Diesel;
    (E) Sampling and testing of DFR-Diesel;
    (F) Work performed and reports prepared by independent third 
parties and by independent auditors under the requirements of this 
section, including work papers; and
    (G) Reports prepared for submission to EPA, and any work papers 
related to such reports.
    (vi) Inspections and audits by EPA may include taking samples of 
diesel fuel, diesel fuel additives or blendstock, and interviewing 
employees.
    (vii) Any employee of the foreign refiner must be made available 
for interview by the EPA inspector or auditor, on request, within a 
reasonable time period.
    (viii) English language translations of any documents must be 
provided to an EPA inspector or auditor, on request, within 10 working 
days.
    (ix) English language interpreters must be provided to accompany 
EPA inspectors and auditors, on request.
    (2) An agent for service of process located in the District of 
Columbia shall

[[Page 5157]]

be named, and service on this agent constitutes service on the foreign 
refiner or any employee of the foreign refiner for any action by EPA or 
otherwise by the United States related to the requirements of this 
subpart.
    (3) The forum for any civil or criminal enforcement action related 
to the provisions of this section for violations of the Clean Air Act 
or regulations promulgated thereunder shall be governed by the Clean 
Air Act, including the EPA administrative forum where allowed under the 
Clean Air Act.
    (4) United States substantive and procedural laws shall apply to 
any civil or criminal enforcement action against the foreign refiner or 
any employee of the foreign refiner related to the provisions of this 
section.
    (5) Submitting a petition for participation in the diesel foreign 
refiner program or producing and exporting diesel fuel under any such 
program, and all other actions to comply with the requirements of this 
subpart relating to participation in any diesel foreign refiner 
program, or to establish an individual refinery motor vehicle diesel 
fuel volume baseline (if applicable) constitute actions or activities 
that satisfy the provisions of 28 U.S.C. section 1605(a)(2), but solely 
with respect to actions instituted against the foreign refiner, its 
agents and employees in any court or other tribunal in the United 
States for conduct that violates the requirements applicable to the 
foreign refiner under this subpart, including conduct that violates 
Title 18 U.S.C. section 1001 and Clean Air Act section 113(c)(2).
    (6) The foreign refiner, or its agents or employees, will not seek 
to detain or to impose civil or criminal remedies against EPA 
inspectors or auditors, whether EPA employees or EPA contractors, for 
actions performed within the scope of EPA employment related to the 
provisions of this section.
    (7) The commitment required by this paragraph (i) shall be signed 
by the owner or president of the foreign refiner business.
    (8) In any case where DFR-Diesel produced at a foreign refinery is 
stored or transported by another company between the refinery and the 
vessel that transports the DFR-Diesel to the United States, the foreign 
refiner shall obtain from each such other company a commitment that 
meets the requirements specified in paragraphs (i)(1) through (7) of 
this section, and these commitments shall be included in the foreign 
refiner's petition to participate in any diesel foreign refiner program 
.
    (j) Sovereign immunity. By submitting a petition for participation 
in any diesel foreign refiner program under this subpart (and baseline, 
if applicable) under this section, or by producing and exporting diesel 
fuel to the United States under any such program, the foreign refiner, 
and its agents and employees, without exception, become subject to the 
full operation of the administrative and judicial enforcement powers 
and provisions of the United States without limitation based on 
sovereign immunity, with respect to actions instituted against the 
foreign refiner, its agents and employees in any court or other 
tribunal in the United States for conduct that violates the 
requirements applicable to the foreign refiner under this subpart 
including conduct that violates Title 18 U.S.C. section 1001 and Clean 
Air Act section 113(c)(2).
    (k) Bond posting. Any foreign refiner shall meet the requirements 
of this paragraph (k) as a condition to approval for any diesel foreign 
refiner program under this subpart.
    (1) The foreign refiner shall post a bond of the amount calculated 
using the following equation: Bond = G  x  $0.01

Where:
Bond = amount of the bond in U.S. dollars.
G = the volume baseline for motor vehicle diesel fuel produced at 
the foreign refinery and exported to the United States, in gallons.

    (2) Bonds shall be posted by:
    (i) Paying the amount of the bond to the Treasurer of the United 
States;
    (ii) Obtaining a bond in the proper amount from a third party 
surety agent that is payable to satisfy United States administrative or 
judicial judgments against the foreign refiner, provided EPA agrees in 
advance as to the third party and the nature of the surety agreement; 
or
    (iii) An alternative commitment that results in assets of an 
appropriate liquidity and value being readily available to the United 
States, provided EPA agrees in advance as to the alternative 
commitment.
    (3) Bonds posted under this paragraph (k) shall:
    (i) Be used to satisfy any judicial judgment that results from an 
administrative or judicial enforcement action for conduct in violation 
of this subpart, including where such conduct violates Title 18 U.S.C. 
1001 and Clean Air Act section 113(c)(2);
    (ii) Be provided by a corporate surety that is listed in the United 
States Department of Treasury Circular 570 ``Companies Holding 
Certificates of Authority as Acceptable Sureties on Federal Bonds'' 
(available from the Department of Treasury website at http://www.fms.treas.gov or from the Government Printing Office, phone (202) 
512-1800); and
    (iii) Include a commitment that the bond will remain in effect for 
at least five (5) years following the end of latest annual reporting 
period that the foreign refiner produces motor vehicle diesel fuel 
pursuant to the requirements of this subpart.
    (4) On any occasion a foreign refiner bond is used to satisfy any 
judgment, the foreign refiner shall increase the bond to cover the 
amount used within 90 days of the date the bond is used.
    (5) If the bond amount for a foreign refiner increases, the foreign 
refiner shall increase the bond to cover the shortfall within 90 days 
of the date the bond amount changes. If the bond amount decreases, the 
foreign refiner may reduce the amount of the bond beginning 90 days 
after the date the bond amount changes.
    (l) [Reserved]
    (m) English language reports. Any report or other document 
submitted to EPA by a foreign refiner shall be in English language, or 
shall include an English language translation.
    (n) Prohibitions. (1) No person may combine Certified DFR-Diesel 
with any Non-Certified DFR-Diesel or Non-DFR-Diesel, and no person may 
combine Certified DFR-Diesel with any Certified DFR-Diesel produced at 
a different refinery, until the importer has met all the requirements 
of paragraph (o) of this section, except as provided in paragraph (e) 
of this section.
    (2) No foreign refiner or other person may cause another person to 
commit an action prohibited in paragraph (n)(1) of this section, or 
that otherwise violates the requirements of this section.
    (o) United States importer requirements. Any United States importer 
shall meet the following requirements:
    (1) Each batch of imported motor vehicle diesel fuel shall be 
classified by the importer as being DFR-Diesel or as Non-DFR-Diesel, 
and each batch classified as DFR-Diesel shall be further classified as 
Certified DFR-Diesel or as Non-certified DFR-Diesel, and each batch of 
Certified DFR-Diesel shall be further classified as complying with the 
500 ppm motor vehicle diesel fuel sulfur standard under Sec. 80.520(c) 
or the 15 ppm motor vehicle diesel fuel sulfur standard under 
Sec. 80.520(a)(1).
    (2) Motor vehicle diesel fuel shall be classified as Certified DFR-
Diesel or as Non-Certified DFR-Diesel according to the designation by 
the foreign refiner if this designation is supported by product

[[Page 5158]]

transfer documents prepared by the foreign refiner as required in 
paragraph (d) of this section, unless the diesel fuel is classified as 
Non-Certified DFR-Diesel under paragraph (g) of this section. 
Additionally, the importer shall comply with all requirements of this 
subpart applicable to domestic refiners subject to any diesel foreign 
refiner program under this subpart.
    (3) For each diesel fuel batch classified as DFR-Diesel, any United 
States importer shall perform the following procedures:
    (i) In the case of both Certified and Non-Certified DFR-Diesel, 
have an independent third party:
    (A) Determine the volume of diesel fuel in the vessel;
    (B) Use the foreign refiner's DFR-Diesel certification to determine 
the name and EPA-assigned registration number of the foreign refinery 
that produced the DFR-Diesel;
    (C) Determine the name and country of registration of the vessel 
used to transport the DFR-Diesel to the United States; and
    (D) Determine the date and time the vessel arrives at the United 
States port of entry.
    (ii) In the case of Certified DFR-Diesel, have an independent third 
party:
    (A) Collect a representative sample from each vessel compartment 
subsequent to the vessel's arrival at the United States port of entry 
and prior to off loading any diesel fuel from the vessel;
    (B) Obtain the compartment samples; and
    (C) Determine the sulfur value of each compartment sample using the 
methodologies specified in Sec. 80.580, by:
    (1) The third party analyzing the sample; or
    (2) The third party observing the importer analyze the sample.
    (4) Any importer shall submit reports within thirty days following 
the date any vessel transporting DFR-Diesel arrives at the United 
States port of entry:
    (i) To the Administrator containing the information determined 
under paragraph (o)(3) of this section; and
    (ii) To the foreign refiner containing the information determined 
under paragraph (o)(3)(ii) of this section, and including 
identification of the port and Credit Trading Area at which the product 
was offloaded.
    (5) Any United States importer shall meet the requirements 
specified in Sec. 80.520, for any imported motor vehicle diesel fuel 
that is not classified as Certified DFR-Diesel under paragraph (o)(2) 
of this section.
    (p) Truck Imports of Certified DFR-Diesel produced at a Foreign 
Refinery. (1) Any refiner whose Certified DFR-Diesel is transported 
into the United States by truck may petition EPA to use alternative 
procedures to meet the following requirements:
    (i) Certification under paragraph (d)(5) of this section;
    (ii) Load port and port of entry sampling and testing under 
paragraphs (f) and (g) of this section;
    (iii) Attest under paragraph (h) of this section; and
    (iv) Importer testing under paragraph (o)(3) of this section.
    (2) These alternative procedures must ensure Certified DFR-Diesel 
remains segregated from Non-Certified DFR-Diesel and from Non-DFR-
Diesel until it is imported into the United States. The petition will 
be evaluated based on whether it adequately addresses the following:
    (i) Provisions for monitoring pipeline shipments, if applicable, 
from the refinery, that ensure segregation of Certified DFR-Diesel from 
that refinery from all other diesel fuel;
    (ii) Contracts with any terminals and/or pipelines that receive 
and/or transport Certified DFR-Diesel, that prohibit the commingling of 
Certified DFR-Diesel with any of the following:
    (A) Other Certified DFR-Diesel from other refineries.
    (B) All Non-Certified DFR-Diesel.
    (C) All Non-DFR-Diesel;
    (iii) Procedures for obtaining and reviewing truck loading records 
and United States import documents for Certified DFR-Diesel to ensure 
that such diesel fuel is only loaded into trucks making deliveries to 
the United States;
    (iv) Attest procedures to be conducted annually by an independent 
third party that review loading records and import documents based on 
volume reconciliation, or other criteria, to confirm that all Certified 
DFR-Diesel remains segregated throughout the distribution system and is 
only loaded into trucks for import into the United States.
    (3) The petition required by this section must be submitted to EPA 
along with the application for temporary refiner relief individual 
refinery highway diesel sulfur standard under this subpart I and this 
section.
    (q) Withdrawal or suspension of a foreign refinery's temporary 
refinery flexibility program approval. EPA may withdraw or suspend a 
diesel refiner temporary compliance option diesel fuel sulfur program 
approval for a foreign refinery where:
    (1) A foreign refiner fails to meet any requirement of this 
section;
    (2) A foreign government fails to allow EPA inspections as provided 
in paragraph (i)(1) of this section;
    (3) A foreign refiner asserts a claim of, or a right to claim, 
sovereign immunity in an action to enforce the requirements in this 
subpart; or
    (4) A foreign refiner fails to pay a civil or criminal penalty that 
is not satisfied using the foreign refiner bond specified in paragraph 
(k) of this section.
    (r) Early use of a foreign refiner baseline. (1) A foreign refiner 
may begin using an individual refinery baseline before EPA has approved 
the baseline, provided that:
    (i) A baseline petition has been submitted as required in paragraph 
(b) of this section;
    (ii) EPA has made a provisional finding that the baseline petition 
is complete;
    (iii) The foreign refiner has made the commitments required in 
paragraph (i) of this section;
    (iv) The persons who will meet the independent third party and 
independent attest requirements for the foreign refinery have made the 
commitments required in paragraphs (f)(3)(iii) and (h)(7)(iii) of this 
section; and
    (v) The foreign refiner has met the bond requirements of paragraph 
(k) of this section.
    (2) In any case where a foreign refiner uses an individual refinery 
baseline before final approval under paragraph (r)(1) of this section, 
and the foreign refinery baseline values that ultimately are approved 
by EPA are more stringent than the early baseline values used by the 
foreign refiner, the foreign refiner shall recalculate its compliance, 
ab initio, using the baseline values approved by the EPA, and the 
foreign refiner shall be liable for any resulting violation of the 
motor vehicle highway diesel fuel requirements.
    (s) Additional requirements for petitions, reports and 
certificates. Any petition for approval to produce motor vehicle diesel 
fuel subject to the diesel foreign refiner program, any alternative 
procedures under paragraph (p) of this section, any report or other 
submission required by paragraph (c), (f)(2), or (i) of this section, 
and any certification under paragraph (d)(3) of this section shall be:
    (1) Submitted in accordance with procedures specified by the 
Administrator, including use of any forms that may be specified by the 
Administrator.
    (2) Be signed by the president or owner of the foreign refiner 
company, or by that person's immediate designee, and shall contain the 
following declaration:

    I hereby certify: (1) that I have actual authority to sign on 
behalf of and to bind

[[Page 5159]]

[insert name of foreign refiner] with regard to all statements 
contained herein; (2) that I am aware that the information contained 
herein is being certified, or submitted to the United States 
Environmental Protection Agency, under the requirements of 40 CFR 
Part 80, subpart I, and that the information is material for 
determining compliance under these regulations; and (3) that I have 
read and understand the information being certified or submitted, 
and this information is true, complete and correct to the best of my 
knowledge and belief after I have taken reasonable and appropriate 
steps to verify the accuracy thereof.
    I affirm that I have read and understand the provisions of 40 
CFR Part 80, subpart I, including 40 CFR 80.620 apply to [insert 
name of foreign refiner]. Pursuant to Clean Air Act section 113(c) 
and Title 18, United States Code, section 1001, the penalty for 
furnishing false, incomplete or misleading information in this 
certification or submission is a fine of up to $10,000 U.S., and/or 
imprisonment for up to five years.

PART 86--CONTROL OF EMISSIONS FROM NEW AND IN-USE HIGHWAY VEHICLES 
AND ENGINES

    11. The authority citation for part 86 continues to read as 
follows:

    Authority: 42 U.S.C. 7401-7671q.


    12. Section 86.1 is amended by revising paragraph (b)(1) to read as 
follows:


Sec. 86.1  Reference materials.

* * * * *
    (b) * * *
    (1) ASTM material. The following table sets forth material from the 
American Society for Testing and Materials that has been incorporated 
by reference. The first column lists the number and name of the 
material. The second column lists the section(s) of this part, other 
than this section, in which the matter is referenced. Copies of these 
materials may be obtained from American Society for Testing and 
Materials, 100 Barr Harbor Drive, West Conshohocken, PA 19428-2959.

------------------------------------------------------------------------
           Document number and name             40 CFR part 86 reference
------------------------------------------------------------------------
ASTM E29-67 (Reapproved 1980), Standard        86.1105-87.
 Recommended Practice for Indicating Which
 Places of Figures Are To Be Considered
 Significant in Specified Limiting Values.
ASTM E29-90, Standard Practice for Using       86.609-84; 86.609-96;
 Significant Digits in Test Data to Determine   86.609-97; 86.609-98;
 Conformance with Specifications.               86.1009-84; 86.1009-96;
                                                86.1442; 86.1708-99;
                                                86.1709-99; 86.1710-99;
                                                86.1728-99.
ASTM D5186-91, Standard Test Method for        86.113-07; 86.1313-91;
 Determination of Aromatic Content of Diesel    86.1313-94; 86.1313-98;
 Fuels by Supercritical Fluid Chromatography.   1313-2007.
ASTM D2163-91, Standard Test Method for        86.113-94; 86.1213-94;
 Analysis of Liquefied Petroleum (LP) Gases     86.1313-94.
 and Propane Concentrates by Gas
 Chromatography.
ASTM D1945-91, Standard Test Method for        86.113-94; 86.513-94;
 Analysis of Natural Gas By Gas                 86.1213-94; 86.1313-94.
 Chromatography.
ASTM E29-93a, Standard Practice for Using      86.098-15; 86.004-15;
 Significant Digits in Test Data to Determine   86.007-11; 86.007-15;
 Conformance with Specifications.               86.1803-01; 86.1823-01;
                                                86.1824-01; 86.1825-01;
                                                86.1837-01.
ASTM D2986-95a, (Reapproved 1999) Standard     86.1310-2007.
 Practice for Evaluation of Air Assay Media
 by the Monodisperse DOP (Dioctyl Phthalate)
 Smoke Test.
ASTM F1471-93, Standard Test Method for Air    86.1310-2007.
 Cleaning Performance of a High-Efficiency
 Particulate Air-Filter System.
------------------------------------------------------------------------

* * * * *

    13. Section 86.004-2 is amended by adding in alphabetical order a 
definition of ``U.S.-directed production'' to read as follows:


Sec. 86.004-2  Definitions.

* * * * *
    U.S.-directed production means the engines and/or vehicles (as 
applicable) produced by a manufacturer for which the manufacturer has 
reasonable assurance that sale was or will be made to ultimate 
purchasers in the United States, excluding engines and/or vehicles that 
are certified to state emission standards different than the emission 
standards in this part.
* * * * *

    14. Section 86.004-28 is amended by adding paragraph (i) to read as 
follows:


Sec. 86.004-28  Compliance with emission standards.

* * * * *
    (i) Emission results from heavy-duty engines equipped with exhaust 
aftertreatment may need to be adjusted to account for regeneration 
events. This provision only applies for engines equipped with emission 
controls that are regenerated on an infrequent basis. For the purpose 
of this paragraph (i), the term ``regeneration'' means an event during 
which emissions levels change while the aftertreatment performance is 
being restored by design. Examples of regenerations are increasing 
exhaust gas temperature to remove sulfur from an adsorber or increasing 
exhaust gas temperature to oxidize PM in a trap. For the purpose of 
this paragraph (i), the term ``infrequent'' means having an expected 
frequency of less than once per transient test cycle. Calculation and 
use of adjustment factors are described in paragraphs (i)(1) through 
(i)(5) of this section.
    (1) Development of adjustment factors. Manufacturers must develop 
separate pairs of adjustment factors (an upward adjustment factor and a 
downward adjustment factor) for each pollutant based on measured 
emission data and observed regeneration frequency. Adjustment factors 
may be carried-over to subsequent model years or carried-across to 
other engine families only where the Administrator determines that such 
carry-over or carry-across is consistent with good engineering 
judgment. Adjustment factors should generally apply to an entire engine 
family, but manufacturers may develop separate adjustment factors for 
different engine configurations within an engine family. All adjustment 
factors for regeneration are additive.
    (2) Calculation of adjustment factors. The adjustment factors are 
calculated from the following parameters: the measured emissions from a 
test in which the regeneration occurs (EFH), the measured 
emissions from a test in which the regeneration does not occur 
(EFL), and the frequency of the regeneration event in terms 
of fraction of tests during which the regeneration occurs (F). The 
average emission rate (EFA) is calculated as:


EFA = (F)(EFH) + (1 - F)(EFL)

    (i) The upward adjustment factor (UAF) is calculated as: UAF = 
EFA - EFL.
    (ii) The downward adjustment factor (DAF) is calculated as: DAF = 
EFA - EFH.
    (3) Use of adjustment factors. Upward adjustment factors are added 
to

[[Page 5160]]

measured emission rates for all tests in which the regeneration does 
not occur. Downward adjustment factors are added to measured emission 
rates for all tests in which the regeneration occurs. The occurrence of 
the regeneration must be identified in a manner that is readily 
apparent during all testing. Where no regeneration is identified, the 
upward adjustment factor shall be applied.
    (4) Sample calculation. If EFL is 0.10 g/bhp-hr, 
EFH is 0.50 g/bhp-hr, and F is 0.1 (i.e., the regeneration 
occurs once for each ten tests), then:

EFA = (0.1)(0.5 g/bhp-hr) + (1.0 - 0.1)(0.1 g/bhp-hr) = 0.14 
g/bhp-hr
UAF = 0.14 g/bhp-hr - 0.10 g/bhp-hr = 0.04 g/bhp-hr
DAF = 0.14 g/bhp-hr - 0.50 g/bhp-hr = -0.36 g/bhp-hr

    (5) Options. (i) A manufacturer may elect to omit adjustment 
factors for one or more of its engine families (or configurations) 
because the effect of the regeneration is small, or because it is not 
practical to identify when regenerations occur. In these cases, no 
upward or downward adjustment factor shall be added, and the 
manufacturer is liable for compliance with the emission standards for 
all tests, without regard to whether a regeneration occurs.
    (ii) Upon request by the manufacturer, the Administrator may 
account for regeneration events differently than is provided in this 
paragraph (i). However, this option only applies for events that occur 
extremely infrequently, and which cannot be practically addressed using 
the adjustment factors described in this paragraph (i).

    15. Section 86.004-40 is amended by revising the introductory text 
to read as follows:


Sec. 86.004-40  Heavy-duty engine rebuilding practices.

    The provisions of this section are applicable to heavy-duty engines 
subject to model year 2004 or later standards and are applicable to the 
process of engine rebuilding (or rebuilding a portion of an engine or 
engine system). The process of engine rebuilding generally includes 
disassembly, replacement of multiple parts due to wear, and reassembly, 
and also may include the removal of the engine from the vehicle and 
other acts associated with rebuilding an engine. Any deviation from the 
provisions contained in this section is a prohibited act under section 
203(a)(3) of the Clean Air Act (42 U.S.C. 7522(a)(3)).
* * * * *

    16. Section 86.005-10 is amended by revising paragraph 
(a)(1)(ii)(C) to read as follows:


Sec. 86.005-10  Emission standards for 2005 and later model year Otto-
cycle heavy-duty engines and vehicles.

* * * * *
    (a) * * *
    (1) * * *
    (ii) * * *
    (C) Idle carbon monoxide. For all Otto-cycle HDEs utilizing 
aftertreatment technology, and not certified to the onboard diagnostics 
requirements of Sec. 86.005-17: 0.50 percent of exhaust gas flow at 
curb idle.
* * * * *

    17. Section 86.005-17 is amended by revising paragraphs (b) 
introductory text, (b)(1), (b)(2), (b)(3), (b)(4), (b)(5), and (k) to 
read as follows:


Sec. 86.005-17  On-board diagnostics.

* * * * *
    (b) Malfunction descriptions. The OBD system must detect and 
identify malfunctions in all monitored emission-related engine systems 
or components according to the following malfunction definitions as 
measured and calculated in accordance with test procedures set forth in 
subpart N of this part (engine-based test procedures) excluding the 
test procedure referred to as the ``Supplemental emission test; test 
cycle and procedures'' contained in Sec. 86.1360, and excluding the 
test procedure referred to as the ``Not-To-Exceed Test Procedure'' 
contained in Sec. 86.1370, and excluding the test procedure referred to 
as the ``Load Response Test'' contained in Sec. 86.1380.
    (1) Catalysts and particulate traps. (i) Otto-cycle. Catalyst 
deterioration or malfunction before it results in an increase in NMHC 
(or NOX+NMHC, as applicable) emissions 1.5 times the NMHC 
(or NOX+NMHC, as applicable) standard or FEL, as compared to 
the NMHC (or NOX+NMHC, as applicable) emission level 
measured using a representative 4000 mile catalyst system.
    (ii) Diesel. (A) If equipped, catalyst deterioration or malfunction 
before it results in exhaust emissions exceeding 1.5 times the 
applicable standard or FEL for NOX (or NOX+NMHC, 
as applicable) or PM. This requirement applies only to reduction 
catalysts; monitoring of oxidation catalysts is not required. This 
monitoring need not be done if the manufacturer can demonstrate that 
deterioration or malfunction of the system will not result in 
exceedance of the threshold.
    (B) If equipped with a particulate trap, catastrophic failure of 
the device must be detected. Any particulate trap whose complete 
failure results in exhaust emissions exceeding 1.5 times the applicable 
standard or FEL for NMHC (or NOX+NMHC, as applicable) or PM 
must be monitored for such catastrophic failure. This monitoring need 
not be done if the manufacturer can demonstrate that a catastrophic 
failure of the system will not result in exceedance of the threshold.
    (2) Engine Misfire. (i) Otto-cycle. Engine misfire resulting in 
exhaust emissions exceeding 1.5 times the applicable standard or FEL 
for NMHC, NOX (or NOX+NMHC, as applicable) or CO; 
and any misfire capable of damaging the catalytic converter.
    (ii) Diesel. Lack of cylinder combustion must be detected.
    (3) Oxygen sensors. If equipped, oxygen sensor deterioration or 
malfunction resulting in exhaust emissions exceeding 1.5 times the 
applicable standard or FEL for NMHC, NOX (or 
NOX+NMHC, as applicable) or CO.
    (4) Evaporative leaks. If equipped, any vapor leak in the 
evaporative and/or refueling system (excluding the tubing and 
connections between the purge valve and the intake manifold) greater 
than or equal in magnitude to a leak caused by a 0.040 inch diameter 
orifice; an absence of evaporative purge air flow from the complete 
evaporative emission control system. Where fuel tank capacity is 
greater than 25 gallons, the Administrator may, following a request 
from the manufacturer, revise the size of the orifice to the smallest 
orifice feasible, based on test data, if the most reliable monitoring 
method available cannot reliably detect a system leak equal to a 0.040 
inch diameter orifice.
    (5) Other emission control systems. Any deterioration or 
malfunction occurring in an engine system or component directly 
intended to control emissions, including but not necessarily limited 
to, the exhaust gas recirculation (EGR) system, if equipped, the 
secondary air system, if equipped, and the fuel control system, 
singularly resulting in exhaust emissions exceeding 1.5 times the 
applicable emission standard or FEL for NMHC, NOX (or 
NOX+NMHC, as applicable), CO or diesel PM. For engines 
equipped with a secondary air system, a functional check, as described 
in paragraph (b)(6) of this section, may satisfy the requirements of 
this paragraph (b)(5) provided the manufacturer can demonstrate that 
deterioration of the flow distribution system is unlikely. This 
demonstration is subject to Administrator approval and, if the 
demonstration and associated functional check are approved, the 
diagnostic system must indicate a malfunction when some degree of 
secondary airflow is not detectable in

[[Page 5161]]

the exhaust system during the check. For engines equipped with positive 
crankcase ventilation (PCV), monitoring of the PCV system is not 
necessary provided the manufacturer can demonstrate to the 
Administrator's satisfaction that the PCV system is unlikely to fail.
* * * * *
    (k) Phase-in for heavy-duty engines. Manufacturers of heavy-duty 
engines must comply with the OBD requirements in this section according 
to the following phase-in schedule, based on the percentage of 
projected engine sales within each category. The 2004 model year 
requirements in the following phase-in schedule are applicable only to 
heavy-duty Otto-cycle engines where the manufacturer has selected Otto-
cycle Option 1 or Option 2 for alternative 2004 compliance according to 
Sec. 86.005-01(c)(1) or (2). The 2005 through 2007 requirements in the 
following phase-in schedule apply to all heavy-duty engines intended 
for use in a heavy-duty vehicle weighing 14,000 pounds GVWR or less. 
Manufacturers may exempt 2005 model year diesel heavy-duty engines from 
the requirements of this section if the 2005 model year commences 
before July 31, 2004 from the requirements of this section. 
Manufacturers may exempt 2005 model year Otto-cycle heavy-duty engines 
and vehicles from the requirements of this section if the manufacturer 
has selected Otto-cycle Option 3 and if the 2005 model year commences 
before July 31, 2004. For the purposes of calculating compliance with 
the phase-in provisions of this paragraph (k), heavy-duty engines may 
be combined with heavy-duty vehicles subject to the phase-in 
requirements of paragraph Sec. 86.1806-05(l). The OBD Compliance phase-
in table follows:

  OBD Compliance Phase-in for Heavy-Duty Engines Intended for Use in a
         Heavy-Duty Vehicle Weighing 14,000 Pounds GVWR or Less
------------------------------------------------------------------------
                               Otto-cycle phase-in     Diesel Phase-in
         Model year            based on projected    based on projected
                                      sales                 sales
------------------------------------------------------------------------
2004 MY.....................  Applicable only to    ....................
                               Otto-cycle engines
                               complying with
                               Options 1 or 2; 40%
                               compliance;
                               alternative fuel
                               waivers available.
2005 MY.....................  60% compliance;       50% compliance;
                               alternative fuel      alternative fuel
                               waivers available.    waivers available.
2006 MY.....................  80% compliance;       50% compliance;
                               alternative fuel      alternative fuel
                               waivers available.    waivers available.
2007 MY.....................  80% compliance;       100% compliance.
                               alternative fuel
                               waivers available.
2008+ MY....................  100% compliance.....  100% compliance.
------------------------------------------------------------------------

    18. Section 86.007-11 is amended by revising the introductory text, 
paragraphs (a) through (a)(2), (a)(3), (a)(4)(i), (b)(3) through (d), 
and adding paragraphs (a)(4)(iv)(C), (a)(4)(v), (e), (f), (g) and (h) 
to read as follows:


Sec. 86.007-11  Emission standards and supplemental requirements for 
2007 and later model year diesel heavy-duty engines and vehicles.

    This section applies to new 2007 and later model year diesel HDEs. 
Section 86.007-11 includes text that specifies requirements that differ 
from Sec. 86.004-11. Where a paragraph in Sec. 86.004-11 is identical 
and applicable to Sec. 86.007-11, this may be indicated by specifying 
the corresponding paragraph and the statement ``[Reserved]. For 
guidance see Sec. 86.004-11.''.
    (a)(1) Exhaust emissions from new 2007 and later model year diesel 
HDEs shall not exceed the following:
    (i) Oxides of Nitrogen (NOX). (A) 0.20 grams per brake 
horsepower-hour (0.075 grams per megajoule).
    (B) A manufacturer may elect to include any or all of its diesel 
HDE families in any or all of the NOX and NOX 
plus NMHC emissions ABT programs for HDEs, within the restrictions 
described in Sec. 86.007-15 or Sec. 86.004-15. If the manufacturer 
elects to include engine families in any of these programs, the 
NOX FELs may not exceed the following FEL caps: 2.00 grams 
per brake horsepower-hour (0.75 grams per megajoule) for model years 
before 2010; 0.50 grams per brake horsepower-hour (0.19 grams per 
megajoule) for model years 2010 and later. This ceiling value applies 
whether credits for the family are derived from averaging, banking, or 
trading programs.
    (ii)(A) Non-Methane Hydrocarbons (NMHC) for engines fueled with 
either diesel fuel, natural gas, or liquefied petroleum gas. 0.14 grams 
per brake horsepower-hour (0.052 grams per megajoule).
    (B) Non-Methane Hydrocarbon Equivalent (NMHCE) for engines fueled 
with methanol. 0.14 grams per brake horsepower-hour (0.052 grams per 
megajoule).
    (iii) Carbon monoxide. (A) 15.5 grams per brake horsepower-hour 
(5.77 grams per megajoule).
    (B) 0.50 percent of exhaust gas flow at curb idle (methanol-, 
natural gas-, and liquefied petroleum gas-fueled diesel HDEs only). 
This does not apply for vehicles certified to the requirements of 
Sec. 86.005-17
    (iv) Particulate. (A) 0.01 grams per brake horsepower-hour (0.0037 
grams per megajoule).
    (B) A manufacturer may elect to include any or all of its diesel 
HDE families in any or all of the particulate ABT programs for HDEs, 
within the restrictions described in Sec. 86.007-15 or other applicable 
sections. If the manufacturer elects to include engine families in any 
of these programs, the particulate FEL may not exceed 0.02 grams per 
brake horsepower-hour (0.0075 grams per megajoule).
    (2) The standards set forth in paragraph (a)(1) of this section 
refer to the exhaust emitted over the operating schedule set forth in 
paragraph (f)(2) of appendix I to this part, and measured and 
calculated in accordance with the procedures set forth in subpart N or 
P of this part, except as noted in Sec. 86.007-23(c)(2).
    (3) SET (i) The weighted average exhaust emissions, as determined 
under Sec. 86.1360-2007(e)(5) pertaining to the supplemental emission 
test cycle, for each regulated pollutant shall not exceed 1.0 times the 
applicable emission standards or FELs specified in paragraph (a)(1) of 
this section.
    (ii) For engines not having a NOX FEL less than1.5 g/
bhp-hr, gaseous exhaust emissions shall not exceed the steady-state 
interpolated values determined by the Maximum Allowable Emission Limits 
(for the corresponding speed and load), as determined under 
Sec. 86.1360-2007(f), when the engine is operated in the steady-state 
control area defined under Sec. 86.1360-2007(d).
    (4) NTE (i)(A) The brake-specific exhaust NMHC or NOX 
emissions in g/bhp-hr, as determined under Sec. 86.1370-2007 pertaining 
to the not-to-exceed test procedures, shall not exceed 1.5 times the 
applicable NMHC or NOX emission standards or FELs specified 
in paragraph (a)(1) of this section, during engine and vehicle 
operation specified

[[Page 5162]]

in paragraph (a)(4)(ii) of this section except as noted in paragraph 
(a)(4)(iii) of this section.
    (B) For engines not having a NOX FEL less than1.50 g/
bhp-hr, the brake-specific NOX and NMHC exhaust emissions in 
g/bhp-hr, as determined under Sec. 86.1370-2007 pertaining to the not-
to-exceed test procedures, shall not exceed 1.25 times the applicable 
emission standards or FELs specified in paragraph (a)(1) of this 
section (or of Sec. 86.004-11, as allowed by paragraph (g) of this 
section), during engine and vehicle operation specified in paragraph 
(a)(4)(ii) of this section except as noted in paragraph (a)(4)(iii) of 
this section.
    (C) The brake-specific exhaust PM emissions in g/bhp-hr, as 
determined under Sec. 86.1370-2007 pertaining to the not-to-exceed test 
procedures, shall not exceed 1.5 times the applicable PM emission 
standards or FEL (for FELs above the standard only) specified in 
paragraph (a)(1) of this section, during engine and vehicle operation 
specified in paragraph (a)(4)(ii) of this section except as noted in 
paragraph (a)(4)(iii) of this section.
    (D) The brake-specific exhaust CO emissions in g/bhp-hr, as 
determined under Sec. 86.1370-2007 pertaining to the not-to-exceed test 
procedures, shall not exceed 1.25 times the applicable CO emission 
standards or FEL specified in paragraph (a)(1) of this section, during 
engine and vehicle operation specified in paragraph (a)(4)(ii) of this 
section except as noted in paragraph (a)(4)(iii) of this section.
* * * * *
    (iv) * * *
    (C) For model years 2010 through 2013, the Administrator may allow 
up to three deficiencies per engine family. The provisions of 
paragraphs (a)(4)(iv)(A) and (B) of this section apply for deficiencies 
allowed by this paragraph (a)(4)(iv)(C). In determining whether to 
allow the additional deficiencies, the Administrator may consider any 
relevant factors, including the factors identified in paragraph 
(a)(4)(iv)(A) of this section. If additional deficiencies are approved, 
the Administrator may set any additional conditions that he/she 
determines to be appropriate.
    (v) The emission limits specified in paragraphs (a)(3) and (a)(4) 
of this section shall be rounded to the same number of significant 
figures as the applicable standards in paragraph (a)(1) of this section 
using ASTM E29-93a (Incorporated by reference at Sec. 86.1).
* * * * *
    (b)(3) and (b)(4) [Reserved]. For guidance see Sec. 86.004-11.
    (c) No crankcase emissions shall be discharged directly into the 
ambient atmosphere from any new 2007 or later model year diesel HDE, 
with the following exception: HDEs equipped with turbochargers, pumps, 
blowers, or superchargers for air induction may discharge crankcase 
emissions to the ambient atmosphere if the emissions are added to the 
exhaust emissions (either physically or mathematically) during all 
emission testing. Manufacturers taking advantage of this exception must 
manufacture the engines so that all crankcase emission can be routed 
into a dilution tunnel (or other sampling system approved in advance by 
the Administrator), and must account for deterioration in crankcase 
emissions when determining exhaust deterioration factors. For the 
purpose of this paragraph (c), crankcase emissions that are routed to 
the exhaust upstream of exhaust aftertreatment during all operation are 
not considered to be ``discharged directly into the ambient 
atmosphere.''
    (d) Every manufacturer of new motor vehicle engines subject to the 
standards prescribed in this section shall, prior to taking any of the 
actions specified in section 203(a)(1) of the Act, test or cause to be 
tested motor vehicle engines in accordance with applicable procedures 
in subpart I or N of this part to ascertain that such test engines meet 
the requirements of paragraphs (a), (b), (c), and (d) of this section.
    (e) [Reserved]. For guidance see Sec. 86.004-11.
    (f) (1) Model year 2007 and later diesel-fueled heavy-duty engines 
and vehicles for sale in Guam, American Samoa, or the Commonwealth of 
the Northern Mariana Islands shall be subject to the same standards and 
requirements as apply to 2006 model year diesel heavy-duty engines and 
vehicles, but only if the vehicle or engine bears a permanently affixed 
label stating:

    THIS ENGINE (or VEHICLE, as applicable) CONFORMS TO US EPA 
EMISSION STANDARDS APPLICABLE TO MODEL YEAR 2006. THIS ENGINE (or 
VEHICLE, as applicable) DOES NOT CONFORM TO US EPA EMISSION 
REQUIREMENTS IN EFFECT AT TIME OF PRODUCTION AND MAY NOT BE IMPORTED 
INTO THE UNITED STATES OR ANY TERRITORY OF THE UNITED STATES EXCEPT 
GUAM, AMERICAN SAMOA, OR THE COMMONWEALTH OF THE NORTHERN MARIANA 
ISLANDS.

    (2) The importation or sale of such a vehicle or engine for use at 
any location U.S. other than Guam, American Samoa, or the Commonwealth 
of the Northern Mariana Islands shall be considered a violation of 
section 203(a)(1) of the Clean Air Act. In addition, vehicles or 
vehicle engines subject to this exemption may not subsequently be 
imported or sold into any state or territory of the United States other 
than Guam, American Samoa, or Commonwealth of the Northern Mariana 
Islands.
    (g) Phase-in options. (1) For model years 2007, 2008, and 2009, 
manufacturers may certify some of their engine families to the combined 
NOX plus NMHC standard applicable to model year 2006 engines 
under Sec. 86.004-11, in lieu of the separate NOX and NMHC 
standards specified in paragraph (a)(1) of this section. These engines 
must comply with all other requirements applicable to model year 2007 
engines. The combined number of engines in the engine families 
certified to the 2006 combined NOX plus NMHC standard may 
not exceed 50 percent of the manufacturer's U.S.-directed production of 
heavy-duty diesel motor vehicle engines for model year 2007, 2008, or 
2009, except as explicitly allowed by this paragraph (g).
    (2)(i) Manufacturers certifying engines to all of the applicable 
standards listed in paragraph (a) and (c) of this section (without 
using credits) prior to model year 2007 may reduce the number of 
engines that are required to meet the standards listed in paragraph (a) 
of this section in model year 2007, 2008 and/or 2009, taking into 
account the phase-in option provided in paragraph (g)(1) of this 
section. For every two engines that are certified early, the 
manufacturer may reduce the number of engines that are required by 
paragraph (g)(1) of this section to meet standards listed in paragraph 
(a)(1) of this section by three engines. For example, if a manufacturer 
produces 100 heavy-duty diesel engines in 2006 that meet all of the 
applicable standards listed in paragraph (a) of this section, and it 
produced 10,000 heavy-duty diesel engines in 2007, then only 4,850 
((10,000)(0.50) - (100)(1.5)) of the engines would need to comply with 
the standards listed in paragraph (a) of this section.
    (ii) Manufacturers certifying engines to the PM standards listed in 
paragraph (a), and to all of the applicable standards in paragraph (c) 
of this section (without using credits) prior to model year 2007 may 
reduce the number of engines that are required to meet the PM standard 
listed in paragraph (a) of this section in model year 2007, 2008 and/or 
2009. For every two engines that are certified to the PM standard 
early, the manufacturer may reduce the number of engines that are 
otherwise required to meet the PM

[[Page 5163]]

standard listed in paragraph (a)(1) of this section by three engines.
    (3) Manufacturers may initially base compliance with the phase-in 
requirements of paragraph (g)(1) or (g)(2) of this section on projected 
U.S.-directed production estimates. This is allowed for model year 2007 
and/or 2008. However, if a manufacturer's actual U.S. directed 
production volume of engines that comply with the model year 2007 
NOX and NMHC standards is less than the required amount, the 
shortfall (in terms of number of engines) must be made up prior to 
2010. For example, if a manufacturer plans in good faith to produce 50 
percent of its projected 10,000 2007 engines (i.e., 5,000 engines) in 
compliance with the 2007 NOX and NMHC standard, but is only 
able to produce 4,500 such engines of an actual 10,000 2007 engines, 
the manufacturer would need to produce an extra 500 engines in 2008 or 
2009 in compliance with the 2007 NOX and NMHC standard. The 
deficit allowed by this paragraph (g)(3) may not exceed 25 percent of 
the U.S. directed production volume.
    (4) Manufacturers certifying engines to a voluntary NOX 
standard of 0.10 g/bhp-hr (without using credits) in addition to all of 
the other applicable standards listed in paragraphs (a) and (c) of this 
section prior to model year 2007 may reduce the number of engines that 
are required to meet the standards listed in paragraph (a)(1) of this 
section in model year 2007, 2008 and/or 2009, taking into account the 
phase-in option provided in paragraph (g)(1) of this section. For every 
engine that is certified early under this provision, the manufacturer 
may reduce the number of engines that are required by paragraph (g)(1) 
of this section to meet the standards listed in paragraph (a)(1) of 
this section by two engines.
    (5) For engines certified under paragraph (g)(1) of this section to 
the NOX+NMHC standard in Sec. 86.004-11, the standards or 
FELs to which they are certified shall be used for the purposes of 
paragraphs (a)(3) and (a)(4) of this section.
    (h)(1) For model years prior to 2012, for purposes of determining 
compliance after title or custody has transferred to the ultimate 
purchaser, for engines having a NOX FEL no higher than 1.30 
g/bhp-hr, the applicable compliance limit shall be determined by adding 
the applicable adjustment from paragraph (h)(2) of this section to the 
otherwise applicable standard or FEL for NOX.
    (2)(i) For engines with 110,000 or fewer miles, the adjustment is 
0.10 g/bhp-hr.
    (ii) For engines with 110,001 to 185,000 miles, the adjustment is 
0.15 g/bhp-hr.
    (iii) For engines with 185,001 or more miles, the adjustment is 
0.20 g/bhp-hr.
    (3) For model years prior to 2012, for purposes of determining 
compliance after title or custody has transferred to the ultimate 
purchaser, the applicable compliance limit shall be determined by 
adding 0.01 g/bhp-hr to the otherwise applicable standard or FEL for 
PM.
    19. A new Sec. 86.007-is added to Subpart A to read as follows:


Sec. 86.007-15  NOX and particulate averaging, trading, and 
banking for heavy-duty engines.

    Section 86.007-15 includes text that specifies requirements that 
differ from Sec. 86.004-15. Where a paragraph in Sec. 86.004-15 is 
identical and applicable to Sec. 86.007-15, this may be indicated by 
specifying the corresponding paragraph and the statement ``[Reserved]. 
For guidance see Sec. 86.004-15.''
    (a) through (l) [Reserved]. For guidance see Sec. 86.004-15.
    (m) The following provisions apply for model year 2007 and later 
engines (including engines certified during years 2007-2009 under the 
phase-in provisions of Sec. 86.007-11(g)(1), Sec. 86.005-10(a), or 
Sec. 86.008-10(f)(1)). These provisions apply instead of the provisions 
of paragraphs Sec. 86.004-15 (a) through (k) to the extent that they 
are in conflict.
    (1) Manufacturers of Otto-cycle engines may participate in an NMHC 
averaging, banking and trading program to show compliance with the 
standards specified in Sec. 86.008-10. The generation and use of NMHC 
credits are subject to the same provisions in paragraphs Sec. 86.004-15 
(a) through (k) that apply for NOX plus NMHC credits, except 
as otherwise specified in this section.
    (2) Credits are calculated as NOX or NMHC credits for 
engines certified to separate NOX and NMHC standards. 
NOX plus NMHC credits (including banked credits and credits 
that are generated during years 2007-2009 under the phase-in provisions 
of Sec. 86.007-11(g)(1), Sec. 86.005-10(a), or Sec. 86.008-10(f)(1)) 
may be used to show compliance with 2007 or later NOX 
standards ( NOX or NMHC standards for Otto-cycle engines), 
subject to an 0.8 discount factor (e.g., 100 grams of NOX 
plus NMHC credits is equivalent to 80 grams of NOX credits).
    (3) NOX or NMHC (or NOX plus NMHC) credits 
may be exchanged between heavy-duty Otto-cycle engine families 
certified to the engine standards of this subpart and heavy-duty Otto-
cycle engine families certified to the chassis standards of subpart S 
of this part, subject to an 0.8 discount factor (e.g., 100 grams of 
NOX (or NOX plus NMHC) credits generated from 
engines would be equivalent to 80 grams of NOX credits if 
they are used in the vehicle program of subpart S, and vice versa).
    (4) Credits that were previously discounted when they were banked 
according to paragraph (c) of Sec. 86.004-15, are subject to an 
additional discount factor of 0.888 instead of the 0.8 discount factor 
otherwise required by paragraph (m)(2) or (m)(3) of this section. This 
results in a total discount factor of 0.8 (0.9  x  0.888 = 0.8).
    (5) For diesel engine families, the combined number of engines 
certified to FELs higher than 0.50 g/bhp-hr using banked NOX 
(and/or NOX plus NMHC) credits in any given model year may 
not exceed 10 percent of the manufacturer's U.S.-directed production of 
engines in all heavy-duty diesel engine families for that model year.
    (6) The FEL must be expressed to the same number of decimal places 
as the standard (generally, one-hundredth of a gram per brake 
horsepower-hour). For engines certified to standards expressed only 
one-tenth of a gram per brake horsepower-hour, if the FEL is below 1.0, 
then add a zero to the standard in the second decimal place and express 
the FEL to nearest one-hundredth of a gram per brake horsepower-hour.
    (7) Credits are to be rounded to the nearest one-hundredth of a 
Megagram using ASTM E29-93a (Incorporated by reference at Sec. 86.1).
    (8) Credits generated for 2007 and later model year diesel engine 
families, or generated for 2008 and later model year Otto-cycle engine 
families are not discounted (except as specified in paragraph (m)(2) or 
(m)(3) of this section), and do not expire.
    (9) For the purpose of using or generating credits during a phase-
in of new standards, a manufacturer may elect to split an engine family 
into two subfamilies (e.g., one which uses credits and one which 
generates credits). The manufacturer must indicate in the application 
for certification that the engine family is to be split, and may assign 
the numbers and configurations of engines within the respective 
subfamilies at any time prior to the submission of the end-of-year 
report required by Sec. 86.001-23.
    (i) Manufacturers certifying a split diesel engine family to both 
the Phase 1 and Phase 2 standards with equally sized subfamilies may 
exclude the engines within that split family from end-of-year 
NOX (or NOX+NMHC) ABT calculations, provided that 
neither

[[Page 5164]]

subfamily generates credits for use by other engine families, or uses 
banked credits, or uses averaging credits from other engine families. 
All of the engines in that split family must be excluded from the 
phase-in calculations of Sec. 86.007-11(g)(1) (both from the number of 
engines complying with the standards being phased-in and from the total 
number of U.S.-directed production engines.)
    (ii) Manufacturers certifying a split Otto-cycle engine family to 
both the Phase 1 and Phase 2 standards with equally sized subfamilies 
may exclude the engines within that split family from end-of-year 
NOX (or NOX+NMHC) ABT calculations, provided that 
neither subfamily generates credits for use by other engine families, 
or uses banked credits, or uses averaging credits from other engine 
families. All of the engines in that split family must be excluded from 
the phase-in calculations of Sec. 86.008-10(f)(1) (both from the number 
of engines complying with the standards being phased-in and from the 
total number of U.S.-directed production engines.)
    (iii) Manufacturers certifying a split engine family may label all 
of the engines within that family with a single NOX or 
NOX+NMHC FEL. The FEL on the label will apply for all SEA or 
other compliance testing.
    (iv) Notwithstanding the provisions of paragraph (m)(9)(iii) of 
this section, for split families, the NOX FEL shall be used 
to determine applicability of the provisions of Sec. 86.007-
11(a)(3)(ii), (a)(4)(i)(B), and (h)(1), and Sec. 86.008-10(g).
    (10) For model years 2007 through 2009, to be consistent with the 
phase-in provisions of Sec. 86.007-11(g)(1), credits generated from 
engines in one diesel engine service class (e.g., light-heavy duty 
diesel engines) may be used for averaging by engines in a different 
diesel engine service class, provided the credits are calculated for 
both engine families using the conversion factor and useful life of the 
engine family using the credits, and the engine family using the 
credits is certified to the standards listed in Sec. 86.007-11(a)(1). 
Banked or traded credits may not be used by any engine family in a 
different service class than the service class of the engine family 
generating the credits.
    20. A new Sec. 86.007-23 is added to Subpart A to read as follows:


Sec. 86.007-23  Required data.

    Section 86.007-23 includes text that specifies requirements that 
differ from Sec. 86.095-23, Sec. 86.098-23, or Sec. 86.001-23. Where a 
paragraph in Sec. 86.095-23, Sec. 86.098-23, or Sec. 86.001-23 is 
identical and applicable to Sec. 86.007-23, this may be indicated by 
specifying the corresponding paragraph and the statement ``[Reserved]. 
For guidance see Sec. 86.095-23.'', ``[Reserved]. For guidance see 
Sec. 86.098-23.'', or ``[Reserved]. For guidance see Sec. 86.001-23.''.
    (a) through (b)(1) [Reserved]. For guidance see Sec. 86.098-23.
    (b)(2) [Reserved]. For guidance see Sec. 86.001-23.
    (b)(3) and (b)(4) [Reserved]. For guidance see Sec. 86.098-23.
    (c) Emission data.--(1) Certification vehicles. The manufacturer 
shall submit emission data (including, methane, methanol, formaldehyde, 
and hydrocarbon equivalent, as applicable) on such vehicles tested in 
accordance with applicable test procedures and in such numbers as 
specified. These data shall include zero-mile data, if generated, and 
emission data generated for certification as required under 
Sec. 86.000-26(a)(3). In lieu of providing emission data the 
Administrator may, on request of the manufacturer, allow the 
manufacturer to demonstrate (on the basis of previous emission tests, 
development tests, or other information) that the engine will conform 
with certain applicable emission standards of this part. Standards 
eligible for such manufacturer requests are those for idle CO 
emissions, smoke emissions, or particulate emissions from methanol-
fueled or gaseous-fueled diesel-cycle certification vehicles, those for 
particulate emissions from Otto-cycle certification vehicles or 
gaseous-fueled vehicles, and those for formaldehyde emissions from 
petroleum-fueled vehicles. Also eligible for such requests are 
standards for total hydrocarbon emissions from model year 1994 and 
later certification vehicles. By separate request, including 
appropriate supporting test data, the manufacturer may request that the 
Administrator also waive the requirement to measure particulate or 
formaldehyde emissions when conducting Selective Enforcement Audit 
testing of Otto-cycle vehicles.
    (2) Certification engines. The manufacturer shall submit emission 
data on such engines tested in accordance with applicable emission test 
procedures of this subpart and in such numbers as specified. These data 
shall include zero-hour data, if generated, and emission data generated 
for certification as required under Sec. 86.000-26(c)(4). In lieu of 
providing emission data on idle CO emissions or particulate emissions 
from methanol-fueled or gaseous-fueled diesel-cycle certification 
engines, on particulate emissions from Otto-cycle engines, or on CO 
emissions from diesel-cycle certification engines, the Administrator 
may, on request of the manufacturer, allow the manufacturer to 
demonstrate (on the basis of previous emission tests, development 
tests, or other information) that the engine will conform with the 
applicable emission standards of this part. In lieu of providing 
emission data on smoke emissions from methanol-fueled or petroleum-
fueled diesel certification engines, the Administrator may, on the 
request of the manufacturer, allow the manufacturer to demonstrate (on 
the basis of previous emission tests, development tests, or other 
information) that the engine will conform with the applicable emissions 
standards of this part. In lieu of providing emissions data on smoke 
emissions from diesel-cycle engines when conducting Selective 
Enforcement Audit testing under subpart K of this part, the 
Administrator may, on separate request of the manufacturer, allow the 
manufacturer to demonstrate (on the basis of previous emission tests, 
development tests, or other information) that the engine will conform 
with the applicable smoke emissions standards of this part .
    (d) through (e)(1) [Reserved]. For guidance see Sec. 86.098-23.
    (e)(2) and (e)(3) [Reserved]. For guidance see Sec. 86.001-23.
    (f) through (g) [Reserved]. For guidance see Sec. 86.095-23.
    (h) through (k) [Reserved]. For guidance see Sec. 86.098-23.
    (l) [Reserved]. For guidance see Sec. 86.095-23.
    (m) [Reserved]. For guidance see Sec. 86.098-23.
    21. A new Sec. 86.007-25 is added to Subpart A to read as follows:


Sec. 86.007-25  Maintenance.

    Section 86.007-25 includes text that specifies requirements that 
differ from Sec. 86.094-25, Sec. 86.098-25, or Sec. 86.004-25. Where a 
paragraph in Sec. 86.094-25, Sec. 86.098-25, or Sec. 86.004-25 is 
identical and applicable to Sec. 86.007-25, this may be indicated by 
specifying the corresponding paragraph and the statement ``[Reserved]. 
For guidance see Sec. 86.094-25.'', ``[Reserved]. For guidance see 
Sec. 86.098-25.'', or ``[Reserved]. For guidance see Sec. 86.004-25.''.
    (a) through (a)(2) [Reserved]. For guidance see Sec. 86.004-25.
    (b) introductory text through (b)(3)(ii) [Reserved]. For guidance 
see Sec. 86.094-25.
    (b)(3)(iii) through (b)(3)(v)(H) [Reserved]. For guidance see 
Sec. 86.004-25.

[[Page 5165]]

    (b)(3)(vi)(A) through (b)(3)(vi)(D) [Reserved]. For guidance see 
Sec. 86.094-25.
    (b)(3)(vi)(E) through (b)(3)(vi)(J) [Reserved]. For guidance see 
Sec. 86.098-25.
    (b)(4) introductory text through (b)(4)(iii)(C) [Reserved]. For 
guidance see Sec. 86.004-25.
    (b)(4)(iii)(D) Particulate trap or trap oxidizer systems including 
related components (adjustment and cleaning only for filter element, 
replacement of the filter element is not allowed during the useful 
life).
    (b)(4)(iii)(E) [Reserved]. For guidance see Sec. 86.004-25.
    (F) Catalytic converter (adjustment and cleaning only for catalyst 
beds, replacement of the bed is not allowed during the useful life).
    (b)(4)(iii)(G) through (b)(6) [Reserved]. For guidance see 
Sec. 86.004-25.
    (b)(7) through (h) [Reserved]. For guidance see Sec. 86.094-25.
    (i) Notwithstanding the provisions of Sec. 86.004-25(b)(4)(iii) 
introductory text through (b)(4)(iii)(C), paragraph (b)(4)(iii)(D) of 
this section, Sec. 86.004-25(b)(4)(iii)(E), paragraph (b)(4)(iii)(F) of 
this section, Sec. 86.004-25(b)(4)(iii)(G), and Sec. 86.004-25(b)(6), 
manufacturers of heavy-duty engines may schedule replacement or repair 
of particulate trap (or trap oxidizer) systems or catalytic converters 
(including NOX adsorbers), provided:
    (1) The manufacturer demonstrates to the Administrator's 
satisfaction that the repair or replacement will be performed according 
to the schedule; and
    (2) The manufacturer pays for the repair or replacement.
    22. A new Sec. 86.007-35 is added to Subpart A to read as follows:


Sec. 86.007-35  Labeling.

    Section 86.007-35 includes text that specifies requirements that 
differ from Sec. 86.095-35. Where a paragraph in Sec. 86.095-35 is 
identical and applicable to Sec. 86.007-35, this may be indicated by 
specifying the corresponding paragraph and the statement ``[Reserved]. 
For guidance see Sec. 86.095-35.''.
    (a) Introductory text through (a)(1)(iii)(L) [Reserved]. For 
guidance see Sec. 86.095-35.
    (a)(1)(iii)(M) [Reserved.]
    (a)(1)(iii)(N)(1) For vehicles exempted from compliance with 
certain revised performance warranty procedures, as specified in 
Sec. 86.096-21(j), a statement indicating the specific performance 
warranty test(s) of 40 CFR part 85, subpart W, not to be performed.
    (2) For vehicles exempted from compliance with all revised 
performance warranty procedures, as specified in Sec. 86.096-21(k), a 
statement indicating:
    (i) That none of the performance warranty tests of 40 CFR part 85, 
subpart W, is to be performed; and
    (ii) The name of the Administrator-approved alternative test 
procedure to be performed.
    (2) Light-duty truck and heavy-duty vehicles optionally certified 
in accordance with the light-duty truck provisions.
    (i) A legible, permanent label shall be affixed in a readily 
visible position in the engine compartment.
    (ii) The label shall be affixed by the vehicle manufacturer who has 
been issued the certificate of conformity for such vehicle, in such a 
manner that it cannot be removed without destroying or defacing the 
label. The label shall not be affixed to any equipment which is easily 
detached from such vehicle.
    (iii) The label shall contain the following information lettered in 
the English language in block letters and numerals, which shall be of a 
color that contrasts with the background of the label:
    (A) The label heading: Important Vehicle Information;
    (B) Full corporate name and trademark of the manufacturer;
    (C) Engine displacement (in cubic inches or liters), engine family 
identification, and evaporative/refueling family;
    (a)(2)(iii)(D) through (a)(2)(iii)(E) [Reserved]. For guidance see 
Sec. 86.095-35.
    (a)(2)(iii)(F) [Reserved]
    (a)(2)(iii)(G) through (a)(2)(iii)(K) [Reserved]. For guidance see 
Sec. 86.095-35.
    (a)(2)(iii)(L) [Reserved]
    (a)(2)(iii)(M) through (a)(2)(iii)(N) [Reserved]. For guidance see 
Sec. 86.095-35.
    (a)(2)(iii)(O)(l) For vehicles exempted from compliance with 
certain revised performance warranty procedures, as specified in 
Sec. 86.096-21(j), a statement indicating the specific performance 
warranty test(s) of 40 CFR part 85, subpart W, not to be performed.
    (2) For vehicles exempted from compliance with all revised 
performance warranty procedures, as specified in Sec. 86.096-21(k), a 
statement indicating:
    (i) That none of the performance warranty tests of 40 CFR part 85, 
subpart W, is to be performed, and
    (ii) The name of the Administrator-approved alternative test 
procedure to be performed.
    (a)(3) heading through (b) [Reserved]. For guidance see 
Sec. 86.095-35.
    (c) Model year 2007 and later diesel-fueled vehicles must include 
permanent readily visible labels on the dashboard (or instrument panel) 
and near all fuel inlets that state ``Use Low-Sulfur Diesel Fuel Only'' 
or ``Low-Sulfur Diesel Fuel Only''.
    (d) through (i) [Reserved]. For guidance see Sec. 86.095-35.
    23. A new Sec. 86.007-38 is added to Subpart A to read as follows:


Sec. 86.007-38  Maintenance instructions.

    Section 86.007-38 includes text that specifies requirements that 
differ from those specified in Sec. 86.094-38 or Sec. 86.004-38. Where 
a paragraph in Sec. 86.094-38 or Sec. 86.004-38 is identical and 
applicable to Sec. 86.007-38, this may be indicated by specifying the 
corresponding paragraph and the statement ``[Reserved]. For guidance 
see Sec. 86.094-38.'', or ``[Reserved]. For guidance see Sec. 86.004-
38.''.
    (a) through (f) [Reserved]. For guidance see Sec. 86.004-38.
    (g) [Reserved]. For guidance see Sec. 86.094-38.
    (h) [Reserved]. For guidance see Sec. 86.004-38.
    (i) For each new diesel-fueled engine subject to the standards 
prescribed in Sec. 86.007-11, as applicable, the manufacturer shall 
furnish or cause to be furnished to the ultimate purchaser a statement 
that ``This engine must be operated only with low sulfur diesel fuel 
(that is, diesel fuel meeting EPA specifications for highway diesel 
fuel, including a 15 ppm sulfur cap).''
    24. A new Sec. 86.008-10 is added to subpart A to read as follows:


Sec. 86.008-10  Emission standards for 2008 and later model year Otto-
cycle heavy-duty engines and vehicles.

    Section 86.008-10 includes text that specifies requirements that 
differ from Sec. 86.099-10. Where a paragraph in Sec. 86.099-10 is 
identical and applicable to Sec. 86.008-10, this may be indicated by 
specifying the corresponding paragraph and the statement ``[Reserved]. 
For guidance see Sec. 86.099-10.''.
    (a)(1) Exhaust emissions from new 2008 and later model year Otto-
cycle HDEs shall not exceed:
    (i)(A) Oxides of Nitrogen (NOX). 0.20 grams per brake 
horsepower-hour (0.075 grams per megajoule).
    (B) A manufacturer may elect to include any or all of its Otto-
cycle HDE families in any or all of the NOX and 
NOX plus NMHC emissions ABT programs for HDEs, within the 
restrictions described in Sec. 86.008-15 or Sec. 86.004-15. If the 
manufacturer elects to include engine families in any of these 
programs, the NOX FEL may not exceed 0.50 grams per brake 
horsepower-hour (0.26 grams per

[[Page 5166]]

megajoule). This ceiling value applies whether credits for the family 
are derived from averaging, banking, or trading programs. The 
NOX FEL cap is 0.80 for model years before 2011 for 
manufacturers choosing to certify to the 1.5 g/bhp-hr 
NOX+NMHC standard in 2003 or 2004, in accordance with 
Sec. 86.005-10(f).
    (ii)(A) Non-methane Hydrocarbons (NMHC) for engines fueled with 
either gasoline, natural gas, or liquefied petroleum gas. 0.14 grams 
per brake horsepower-hour (0.052grams per megajoule).
    (B) Non-methane Hydrocarbon Equivalent (NMHCE) for engines fueled 
with methanol. 0.14 grams per brake horsepower-hour (0.052grams per 
megajoule).
    (C) A manufacturer may elect to include any or all of its Otto-
cycle HDE families in any or all of the NMHC emissions ABT programs for 
HDEs, within the restrictions described in Sec. 86.008-15 or 
Sec. 86.004-15. If the manufacturer elects to include engine families 
in any of these programs, the NMHC FEL may not exceed 0.30 grams per 
brake horsepower-hour. This ceiling value applies whether credits for 
the family are derived from averaging, banking, or trading programs. 
The NMHC FEL cap is 0.40 for model years before 2011 for manufacturers 
choosing to certify to the 1.5 g/bhp-hr NOX+NMHC in 2004, as 
allowed in Sec. 86.005-10.
    (iii)(A) Carbon monoxide. 14.4 grams per brake horsepower-hour 
(5.36 grams per megajoule).
    (B) Idle Carbon Monoxide. For all Otto-cycle HDEs utilizing 
aftertreatment technology, and not certified to the onboard diagnostics 
requirements of Sec. 86.005-17: 0.50 percent of exhaust gas flow at 
curb idle.
    (iv) Particulate. 0.01grams per brake horsepower-hour (0.0037grams 
per megajoule).
    (2) The standards set forth in paragraph (a)(1) of this section 
refer to the exhaust emitted over the operating schedule set forth in 
paragraph (f)(1) of appendix I to this part, and measured and 
calculated in accordance with the procedures set forth in subpart N or 
P of this part.
    (3) [Reserved]
    (4) [Reserved]
    (b) Evaporative emissions from heavy-duty vehicles shall not exceed 
the following standards. The standards apply equally to certification 
and in-use vehicles. The spitback standard also applies to newly 
assembled vehicles. For certification vehicles only, manufacturers may 
conduct testing to quantify a level of nonfuel background emissions for 
an individual test vehicle. Such a demonstration must include a 
description of the source(s) of emissions and an estimated decay rate. 
The demonstrated level of nonfuel background emissions may be 
subtracted from emission test results from certification vehicles if 
approved in advance by the Administrator.
    (1) Hydrocarbons (for vehicles equipped with gasoline-fueled, 
natural gas-fueled or liquefied petroleum gas-fueled engines).
    (i) For vehicles with a Gross Vehicle Weight Rating of up to 14,000 
lbs:
    (A)(1) For the full three-diurnal test sequence described in 
Sec. 86.1230-96, diurnal plus hot soak measurements: 1.4 grams per 
test.
    (2) For the supplemental two-diurnal test sequence described in 
Sec. 86.1230-96, diurnal plus hot soak measurements (gasoline-fueled 
vehicles only): 1.75 grams per test.
    (B) Running loss test (gasoline-fueled vehicles only): 0.05 grams 
per mile.
    (C) Fuel dispensing spitback test (gasoline-fueled vehicles only): 
1.0 grams per test.
    (ii) For vehicles with a Gross Vehicle Weight Rating of greater 
than 14,000 lbs:
    (A)(1) For the full three-diurnal test sequence described in 
Sec. 86.1230-96, diurnal plus hot soak measurements: 1.9 grams per 
test.
    (2) For the supplemental two-diurnal test sequence described in 
Sec. 86.1230-96, diurnal plus hot soak measurements (gasoline-fueled 
vehicles only): 2.3 grams per test.
    (B) Running loss test (gasoline-fueled vehicles only): 0.05 grams 
per mile.
    (2) Total Hydrocarbon Equivalent (for vehicles equipped with 
methanol-fueled engines).
    (i) For vehicles with a Gross Vehicle Weight Rating of up to 14,000 
lbs:
    (A)(1) For the full three-diurnal test sequence described in 
Sec. 86.1230-96, diurnal plus hot soak measurements: 1.4 grams carbon 
per test.
    (2) For the supplemental two-diurnal test sequence described in 
Sec. 86.1230-96, diurnal plus hot soak measurements: 1.75 grams carbon 
per test.
    (B) Running loss test: 0.05 grams carbon per mile.
    (C) Fuel dispensing spitback test: 1.0 grams carbon per test.
    (ii) For vehicles with a Gross Vehicle Weight Rating of greater 
than 14,000 lbs:
    (A)(1) For the full three-diurnal test sequence described in 
Sec. 86.1230-96, diurnal plus hot soak measurements: 1.9 grams carbon 
per test.
    (2) For the supplemental two-diurnal test sequence described in 
Sec. 86.1230-96, diurnal plus hot soak measurements: 2.3 grams carbon 
per test.
    (B) Running loss test: 0.05 grams carbon per mile.
    (3)(i) For vehicles with a Gross Vehicle Weight Rating of up to 
26,000 lbs, the standards set forth in paragraphs (b)(1) and (b)(2) of 
this section refer to a composite sample of evaporative emissions 
collected under the conditions and measured in accordance with the 
procedures set forth in subpart M of this part.
    (ii) For vehicles with a Gross Vehicle Weight Rating of greater 
than 26,000 lbs., the standards set forth in paragraphs (b)(1)(ii) and 
(b)(2)(ii) of this section refer to the manufacturer's engineering 
design evaluation using good engineering practice (a statement of which 
is required in Sec. 86.098-23(b)(4)(ii)).
    (4) All fuel vapor generated in a gasoline- or methanol-fueled 
heavy-duty vehicle during in-use operations shall be routed exclusively 
to the evaporative control system (e.g., either canister or engine 
purge). The only exception to this requirement shall be for 
emergencies.
    (c) No crankcase emissions shall be discharged into the ambient 
atmosphere from any new 2008 or later model year Otto-cycle HDE.
    (d) Every manufacturer of new motor vehicle engines subject to the 
standards prescribed in this section shall, prior to taking any of the 
actions specified in section 203(a)(1) of the Act, test or cause to be 
tested motor vehicle engines in accordance with applicable procedures 
in subpart N or P of this part to ascertain that such test engines meet 
the requirements of this section.
    (e) [Reserved]. For guidance see Sec. 86.099-10.
    (f) Phase-in options. (1)(i) For model year 2008, manufacturers may 
certify some of their engine families to the exhaust standards 
applicable to model year 2007 engines under Sec. 86.005-10, in lieu of 
the exhaust standards specified in this section. These engines must 
comply with all other requirements applicable to model year 2008 
engines, except as allowed by paragraph (f)(1)(ii) of this section. The 
combined number of engines in the engine families certified to the 2007 
combined NOX plus NMHC standard may not exceed 50 percent of 
the manufacturer's U.S.-directed production of heavy-duty Otto-cycle 
motor vehicle engines for model year 2008, except as explicitly allowed 
by paragraph (f)(2) of this section.
    (ii) For model year 2008, manufacturers may certify some of their 
engine families to the evaporative standards applicable to model year 
2007 engines under Sec. 86.005-10, in lieu of the standards specified 
in this section.

[[Page 5167]]

These engines must comply with all other requirements applicable to 
model year 2008 engines, except as allowed by paragraph (f)(1)(i) of 
this section. The combined number of engines in the engine families 
certified to the 2007 standards may not exceed 50 percent of the 
manufacturer's U.S.-directed production of heavy-duty Otto-cycle motor 
vehicle engines for model year 2008.
    (2)(i) Manufacturers certifying engines to all of the applicable 
exhaust standards listed in paragraph (a) of this section prior to 
model year 2008 (without using credits) may reduce the number of 
engines that are required to meet the NOX and NMHC exhaust 
standards listed in paragraph (a) of this section in model year 2008 
and/or 2009, taking into account the phase-in option provided in 
paragraph (f)(1) of this section. For every engine that is certified 
early, the manufacturer may reduce the number of engines that are 
required by paragraph (f)(1) of this section to meet the NOX 
and NMHC standards listed in paragraph (a) of this section by one 
engine. For example, if a manufacturer produces 100 heavy-duty Otto-
cycle engines in 2007 that meet all of the applicable standards listed 
in paragraph (a) of this section, and it produced 10,000 heavy-duty 
Otto-cycle engines in 2009, then only 9,900 of the engines would need 
to comply with the NOX and NMHC standards listed in 
paragraph (a) of this section.
    (ii) Manufacturers certifying engines to all of the applicable 
evaporative standards listed in paragraph (b) of this section prior to 
model year 2008 may reduce the number of engines that are required to 
meet the evaporative standards listed in paragraph (a) of this section 
in model year 2008 and/or 2009, taking into account the phase-in option 
provided in paragraph (f)(1) of this section. For every engine that is 
certified early, the manufacturer may reduce the number of engines that 
are required by paragraph (f)(1) of this section to meet evaporative 
standards listed in paragraph (b) of this section by one engine.
    (3) Manufacturers certifying engines to a voluntary NOX 
standard of 0.10 g/bhp-hr (without using credits) in addition to all of 
the applicable standards listed in paragraphs (a) and (b) of this 
section prior to model year 2008 may reduce the number of engines that 
are required to meet the NOX and NMHC standards listed in 
paragraph (a) of this section in model year 2008 and/or 2009, taking 
into account the phase-in option provided in paragraph (f)(1) of this 
section. For such every engine that is certified early, the 
manufacturer may reduce the number of engines that are required by 
paragraph (f)(1) of this section to meet the NOX and NMHC 
standards listed in paragraph (a) of this section by two engines.
    (g) For model years prior to 2012, for purposes of determining 
compliance after title or custody has transferred to the ultimate 
purchaser, for engines having a NOX FEL no higher than 0.50 
g/bhp-hr, the applicable compliance limits for NOX and NMHC 
shall be determined by adding 0.10 g/bhp-hr to the otherwise applicable 
standards or FELs for NOX and NMHC.
    25. A new Sec. 86.113-07 is added to subpart B to read as follows:


Sec. 86.113-07  Fuel specifications.

    Section 86.113-07 includes text that specifies requirements that 
differ from Sec. 86.113-94 or Sec. 86.113-04. Where a paragraph in 
Sec. 86.113-94 or Sec. 86.113-04 is identical and applicable to 
Sec. 86.113-07, this may be indicated by specifying the corresponding 
paragraph and the statement ``[Reserved]. For guidance see Sec. 86.113-
94.'' or ``[Reserved]. For guidance see Sec. 86.113-04.''.
    (a) [Reserved]. For guidance see Sec. 86.113-04.
    (b)(1) [Reserved]. For guidance see Sec. 86.113-94.
    (b)(2) Petroleum fuel for diesel vehicles meeting the following 
specifications, or substantially equivalent specifications approved by 
the Administrator, must be used in exhaust emissions testing. The grade 
of petroleum diesel fuel recommended by the engine manufacturer, 
commercially designated as ``Type 2-D'' grade diesel, must be used:

----------------------------------------------------------------------------------------------------------------
                 Item                                                  ASTM test method No.         Type 2-D
----------------------------------------------------------------------------------------------------------------
(i) Cetane Number.................................................  D613......................            40-50
(ii) Cetane Index.................................................  D976......................           40-50
(iii) Distillation range:
    (A) IBP..........................   deg.F.....................  D86.......................          340-400
                                       ( deg.C)...................  ..........................     (171.1-204.4)
    (B) 10 pct. point................   deg.F.....................  D86.......................          400-460
                                       ( deg.C)...................  ..........................     (204.4-237.8)
    (C) 50 pct. point................   deg.F.....................  D86.......................          470-540
                                       ( deg.C)...................  ..........................     (243.3-282.2)
    (D) 90 pct. point................   deg.F.....................  D86.......................          560-630
                                       ( deg.C)...................  ..........................     (293.3-332.2)
    (E) EP...........................   deg.F.....................  D86.......................          610-690
                                       ( deg.C)...................  ..........................     (321.1-365.6)
(iv) Gravity.........................   deg.API...................  D287......................            32-37
(v) Total sulfur.....................  ppm........................  D2622.....................             7-15
(vi) Hydrocarbon composition:
    (A) Aromatics, minimum (Remainder  pct........................  D5186.....................               27
     shall be paraffins, naphthenes,
     and olefins).
(vii) Flashpoint, min................   deg.F.....................  D93.......................              130
                                       ( deg.C)...................  ..........................            (54.4)
(viii) Viscosity.....................  centistokes................  D445......................          2.0-3.2
----------------------------------------------------------------------------------------------------------------

    (3) Petroleum fuel for diesel vehicles meeting the following 
specifications, or substantially equivalent specifications approved by 
the Administrator, shall be used in service accumulation. The grade of 
petroleum diesel fuel recommended by the engine manufacturer, 
commercially designated as ``Type 2-D'' grade diesel fuel, shall be 
used: (b)(4) through (g) [Reserved]. For guidance see Sec. 86.113-94.

----------------------------------------------------------------------------------------------------------------
                 Item                                                  ASTM test method No.         Type 2-D
----------------------------------------------------------------------------------------------------------------
(i) Cetane Number.................................................  D613......................            38-58

[[Page 5168]]

 
(ii) Cetane Index.................................................  D976......................         min. 40
(iii) Distillation range:
    90 pct. point....................   deg.F.....................  D86.......................          540-630
(iv) Gravity.........................   deg.API...................  D287......................            30-39
(v) Total sulfur.....................  ppm........................  D2622.....................             7-15
(vi) Flashpoint, min.................   deg.F.....................  D93.......................              130
                                       ( deg.C)...................  ..........................            (54.4)
(vii) Viscosity......................  centistokes................  D445......................          1.5-4.5
----------------------------------------------------------------------------------------------------------------

    (h)(1) For model year 2004 through 2006 Tier 2 diesel-fueled 
vehicles that incorporate sulfur-sensitive technologies, the 
manufacturer may test the vehicle using a test fuel meeting the 
specifications listed in paragraphs (b)(2) and (b)(3) of this section, 
provided the manufacturer clearly recommends to the ultimate purchaser 
in the owner's manual that the vehicle should use fuel with no higher 
than 15 ppm sulfur.
    (2) For model year 2004 through 2006 Tier 2 diesel-fueled vehicles 
that incorporate sulfur-sensitive technologies and that are certified 
for 50-state sale (i.e., certified to California and EPA standards), 
the manufacturer may test the vehicle using a test fuel whose 
qualities, on a specification by specification basis, meet the 
requirements of either the specifications listed in paragraph (b)(2) of 
this section or the California test fuel specifications, provided the 
manufacturer clearly recommends to the ultimate purchaser in the 
owner's manual that the vehicle should use fuel with no higher than 15 
ppm sulfur.
    (3) Where a manufacturer uses a test fuel under paragraph (h)(1) or 
(h)(2) of this section, EPA shall use the same fuel for its compliance 
testing.

    26. A new Sec. 86.1213-04 is added to Subpart M to read as follows:


Sec. 86.1213-04  Fuel specifications.

    The test fuels listed in Sec. 86.1313-04 shall be used for 
evaporative emission testing.

    27. A new Sec. 86.1306-07 is added to subpart N to read as follows:


Sec. 86.1306-07  Equipment required and specifications; overview.

    Section 86.1306-07 includes text that specifies requirements that 
differ from Sec. 86.1306-96. Where a paragraph in Sec. 86.1306-96 is 
identical and applicable to Sec. 86.1306-07, this may be indicated by 
specifying the corresponding paragraph and the statement ``[Reserved]. 
For guidance see Sec. 86.1306-96.''.
    (a) and (b) [Reserved]. For guidance see Sec. 86.1306-96.
    (c)(1) Upon request, the Administrator may allow a manufacturer to 
use some of the test equipment allowed for model year 2006 and earlier 
engines instead of the test equipment required for model year 2007 and 
later engines, provided that good engineering judgment indicates that 
it would not adversely affect determination of compliance with the 
applicable emission standards of this part.
    (2) A manufacturer may use the test equipment required for model 
year 2007 and later engines for earlier model year engines, provided 
that good engineering judgment indicates that it would not adversely 
affect determination of compliance with the applicable emission 
standards of this part.
    (d) Approval of alternate test system. (1) If on the basis of the 
information described in paragraph (d)(5) of this section, the 
Administrator determines that an alternate test system would 
consistently and reliably produce emission test results that are at 
least equivalent to the results produced using the test systems 
described in this subpart, he/she shall approve the alternate system 
for optional use instead of the test systems described in this subpart.
    (2) Any person may submit an application for approval of an 
alternate test system.
    (3) In approving an alternate test system, the Administrator may 
approve it for general use, or may approve it conditionally.
    (4) The Administrator may revoke the approval on the basis of new 
information that indicates that the alternate test system is not 
equivalent. However, revocation of approval must allow manufacturers 
sufficient lead-time to change the test system to an approved system. 
In determining the amount of lead-time that is required, the 
Administrator will consider relevant factors such as:
    (i) The ease with which the test system can be converted to an 
approved system.
    (ii) The degree to which the alternate system affects the measured 
emission rates.
    (iii) Any relevant conditions included in the approval.
    (5) The application for approval must include:
    (i) An explanation of the theoretical basis of the alternate 
system. This technical description should explain why the detection 
principle of the alternate system would provide equivalent results to 
the detection principle of the prescribed system for the full range of 
emission properties being measured. This description may include 
equations, figures, and references. For example, a NOX 
measurement application should theoretically relate the alternate 
detection principle to the chemiluminescent detection principle of 
detecting nitric oxide for a typical range of NO to NO2 
ratios. A PM measurement application should explain the principle(s) by 
which the alternate system quantifies PM mass independent of PM 
composition, and how it is impacted by semi-volatile and volatile 
species= phase distributions. For any proportioning or integrating 
system, the application should compare the alternate system's 
theoretical response to the prescribed system's response.
    (ii) A technical description of the alternate system. This section 
shall detail all of the hardware and software included in the alternate 
system. Dimensioned drawings, flow-charts, schematics, and component 
specifications shall be included. Any data manipulation (i.e. 
calculations) that the system performs shall be presented in this 
section.
    (iii) A description of the procedures used to operate the system 
including the level of training that an operator must have to achieve 
acceptable results. This section of the application shall describe all 
of the installation, calibration, operation, and maintenance procedures 
in a step-by-step format. Note that empirical calibration with respect 
to another prescribed or approved measurement system is not acceptable. 
Calibration should be performed with NIST traceable standards, or 
equivalent national standards. Diagrams, schematics, and other graphics 
may be used to enhance the description.

[[Page 5169]]

    (iv) A comparison of results from the alternate system and from the 
prescribed system (or other system approved by the Administrator). The 
two systems must be calibrated independently to NIST traceable 
standards or equivalent national standards for this comparison. While 
other statistical analyses may be acceptable, it is recommended that 
the comparison be based on a minimum of 7 collocated and simultaneous 
tests. This comparison shall be performed over the ``hot-start'' 
portion of the FTP test cycle. If the comparison is paired, it must 
demonstrate that the alternate system passes a two-sided, paired t-test 
described in this paragraph. If the test is unpaired, it must 
demonstrate that the alternate system passes a two-sided, unpaired t-
test described in this paragraph. Other statistical criteria may be set 
by the Administrator. The average of these tests for the reference 
system must return results less than or equal to the applicable 
emissions standard. The t-test is performed as follows, where ``n'' 
equals the number of tests:
    (A) Calculate the average of the alternate system results; this is 
Aavg.
    (B) Calculate the average of the results of the system to which the 
alternate system was referenced; this is Ravg.
    (C) For an unpaired comparison, calculate the ``n-1'' standard 
deviation for the alternate and reference averages; these are 
Asd and Rsd respectively. Asd must be 
less than or equal to Rsd. If Asd is greater than 
Rsd, the Administrator will not approve the application.
    (D) For an unpaired comparison, calculate the t-value:

tunpaired = (Aavg-Ravg)/
((Asd\2\+Rsd\2\)/n)\1/2\
    (E) For a paired comparison, calculate the ``n-1'' standard 
deviation (squared) of the differences, di, between the 
paired results, where ``i'' represents the i\th\ test of n number of 
tests:
    SD\2\ = (Sdi\2\- ((Sdi)\2\/n))/
(n-1)
    (F)(1) For a paired comparison, calculate the t-value:

tpaired = (Aavg-Ravg)/
(SD\2\/n)\1/2\
    (2) The absolute value of t must be less than the critical t value, 
tcrit at a 90% confidence interval for ``n-1'' degrees of 
freedom. The following table lists 90% confidence interval 
tcrit values for n-1 degrees of freedom:

------------------------------------------------------------------------
90% Confidence interval critical t values vs. n-1 degrees of freedom for
                       a two-sided, paired t-test
-------------------------------------------------------------------------
                            n -1                                tcrit
------------------------------------------------------------------------
6..........................................................         1.94
7..........................................................         1.89
8..........................................................         1.86
9..........................................................         1.83
10.........................................................         1.81
11.........................................................         1.80
12.........................................................         1.78
13.........................................................         1.77
14.........................................................         1.76
15.........................................................         1.75
16.........................................................         1.75
17.........................................................         1.74
18.........................................................         1.73
19.........................................................         1.73
20.........................................................         1.72
------------------------------------------------------------------------


    28. Section 86.1309-90 is amended by revising the section heading 
and paragraph (a)(1) to read as follows:


Sec. 86.1309-90  Exhaust gas sampling system; Otto-cycle and non-
petroleum-fueled engines.

    (a)(1) General. The exhaust gas sampling system described in this 
paragraph is designed to measure the true mass of gaseous emissions in 
the exhaust of either gasoline-fueled, natural gas-fueled, liquefied 
petroleum gas-fueled or methanol-fueled engines. In the CVS concept of 
measuring mass emissions, two conditions must be satisfied; the total 
volume of the mixture of exhaust and dilution air must be measured, and 
a continuously proportioned volume of sample must be collected for 
analysis. Mass emissions are determined from the sample concentration 
and total flow over the test period.
* * * * *

    29. A new section 86.1310-07 is added to Subpart N to read as 
follows:


Sec. 86.1310-2007  Exhaust gas sampling and analytical system for 
gaseous emissions from heavy-duty diesel-fueled engines and particulate 
emissions from all engines.

    (a) General. The exhaust gas sampling system described in this 
paragraph is designed to measure the true mass of both gaseous and 
particulate emissions in the exhaust of heavy-duty diesel engines, and 
particulate emissions in the exhaust of all heavy-duty engines. 
(Gaseous emissions from non-petroleum-fueled diesel engines are 
measured using the system described in Sec. 86.1309.) This system 
utilizes the CVS concept (described in Sec. 86.1309) of measuring the 
combined mass emissions of THC, NOX, CH4 (if 
applicable) CO, CO2 and particulate matter. For all emission 
measurement systems described in this section, multiple or redundant 
systems may be used during a single test. Statistical averages of data 
from multiple systems may be used to calculate test results, consistent 
with good engineering judgment. Weighted averages are allowed, where 
appropriate Statistical outliers may be discarded, but all results must 
be reported. If the Administrator determines that the statistical 
analysis is not consistent with good engineering judgment, he/she may 
determine compliance from the arithmetic mean of the results. A 
continuously integrated system may be used for THC, NOX , CO 
and CO2 measurement. The use of proportional bag sampling 
for sample integration is allowed for THC, NOX, CO, and 
CO2 measurement, but requirements specific to bag sampling 
from diesel exhaust must be met for the THC and NOX 
emissions measurements. CH4 measurement for calculation of 
NMHC (if applicable) is measured using GC-FID analysis of a 
proportional bag sample. The mass of gaseous emissions is determined 
from the sample concentration and total flow over the test period. The 
mass of particulate emissions is determined from a proportional mass 
sample collected on a filter and from the sample flow and total flow 
over the test period. As an option, the measurement of total fuel mass 
consumed over a cycle may be substituted for the exhaust measurement of 
CO2. General requirements are as follows:
    (1) This sampling system requires the use of a CVS The CVS system 
may use a PDP or a CFV. PDP systems must use a heat exchanger. CFV 
systems may use either a heat exchanger or electronic flow 
compensation. When electronic flow compensation is used, the CFV may be 
replaced by a subsonic venturi (SSV) as long as the CVS concept as 
defined in Sec. 86.1309 is maintained (i.e., a constant volumetric 
flow-rate through the CVS is maintained for the duration of the test). 
Figure N07-1 is a schematic drawing of the CVS system.
    (2) The THC analytical system for diesel engines requires a heated 
flame ionization detector (HFID) and heated sample system (191 
 11  deg.C) using either:
    (i) Continuously integrated measurement of diluted THC meeting the 
minimum requirements and technical specifications contained in 
paragraph (b)(3) of this section. Unless compensation for varying mass 
flow is made, a constant mass flow system must be used to ensure a 
proportional sample; or
    (ii) Heated (191  11  deg.C) proportional bag sampling 
systems for hydrocarbon measurement will be allowed if the bag sampling 
system meets the performance specifications for outgassing and 
permeability as defined in paragraph (b)(2) of this section.

[[Page 5170]]

    (3) CH4 measurement, if applicable, shall be conducted 
using a proportional bag sampling system with subsequent analysis using 
a gas chromatograph and FID. The CH4 measurement shall be 
done in accordance with SAE Recommended Practice J1151, ``Methane 
Measurement Using Gas Chromatography'' (1994 SAE Handbook, Volume 1: 
Materials, Fuels, Emissions, and Noise, Section 13, Page 13.170), which 
is incorporated by reference pursuant to Sec. 86.1(b)(2). As an 
alternative, the manufacturer may choose one of the options set forth 
in Sec. 86.004-28(c)(8).
    (4) [Reserved]
    (5) [Reserved]
    (6) The CO and CO2 analytical system requires:
    (i) Bag sampling (Sec. 86.1309) and analytical (Sec. 86.1311) 
capabilities, as shown in Figure N07-1; or
    (ii) Continuously integrated measurement of diluted CO and 
CO2 meeting the minimum requirements and technical 
specifications contained in paragraph (b)(5) of this section. Unless 
compensation for varying flow is made, a constant flow system must be 
used to ensure a proportional sample; and
    (7) The NOX analytical system requires:
    (i) Continuously integrated measurement of diluted NOX 
meeting the minimum requirements and technical specifications contained 
in paragraph (b)(5) of this section. Unless compensation for varying 
flow is made, a constant flow system must be used to ensure a 
proportional sample.
    (ii) Bag sampling (Sec. 86.1309) and analytical (Sec. 86.1311) 
capabilities, as shown in Figure N07-1 (or Figure 07-2) will be allowed 
provided that sample gas temperature is maintained above the sample's 
aqueous dewpoint at all times during collection and analysis.
    (8) The mass of particulate in the exhaust is determined via 
filtration. The particulate sampling system requires dilution of the 
exhaust to a temperature of 47  deg.C  5  deg.C, measured 
upstream of a single high-efficiency sample filter (as close to the 
filter as practical).
    (9) Since various configurations can produce equivalent results, 
exact conformance with these drawings is not required. Additional 
components such as instruments, valves, solenoids, pumps, and switches 
may be used to provide additional information and coordinate the 
functions of the components of the system. Other components, such as 
snubbers, which are not needed to maintain accuracy on some systems, 
may be excluded if their exclusion is based upon good engineering 
judgment.
    (10) Other sampling and/or analytical systems may be used if shown 
to yield equivalent results and if approved in advance by the 
Administrator (see Sec. 86.1306-07).
    (b) Component description. The components necessary for exhaust 
sampling shall meet the following requirements:
    (1) Exhaust dilution system. The CVS shall conform to all of the 
requirements listed for the exhaust gas CVS systems in Sec. 86.1309(b), 
(c), and (d). With respect to PM measurement, the intent of this 
measurement procedure is to perform the sample cooling primarily via 
dilution and mixing with air rather than via heat transfer to the 
surfaces of the sampling system. In addition the CVS must conform to 
the following requirements:
    (i) The flow capacity of the CVS must be sufficient to maintain the 
diluted exhaust stream at the temperatures required for the measurement 
of particulate and hydrocarbon emission noted below and at, or above, 
the temperatures where aqueous condensation in the exhaust gases could 
occur. This is achieved by the following method. The flow capacity of 
the CVS must be sufficient to maintain the diluted exhaust stream in 
the primary dilution tunnel at a temperature of 191  deg.C or less at 
the sampling zone and as required to prevent condensation at any point 
in the dilution tunnel. Gaseous emission samples may be taken directly 
from this sampling point. An exhaust sample must then be taken at this 
point to be diluted a second time for use in determining particulate 
emissions. The secondary dilution system must provide sufficient 
secondary dilution air to maintain the double-diluted exhaust stream at 
a temperature of 47 C  5 C, measured at a point located 
between the filter face and 16 cm upstream of the filter face.
    (ii) For the CVS , either a heat exchanger (i.e. CFV-CVS) or 
electronic flow compensation (i.e. EFC-CFV-CVS), which also includes 
the particulate sample flows is required Refer to Figure N07-1.
    (iii) When a heat exchanger is used, the gas mixture temperature, 
measured at a point immediately ahead of the critical flow venturi, 
shall be within 11  deg.C of the average operating 
temperature observed during the test with the simultaneous requirement 
that aqueous condensation does not occur. The temperature measuring 
system (sensors and readout) shall have an accuracy and precision of 
1.9  deg.C. For systems utilizing a flow compensator to 
maintain proportional sampling, the requirement for maintaining 
constant temperature is not necessary.
    (iv) The primary dilution air and secondary dilution air:
    (A) Shall have a primary and secondary dilution air temperature 
equal to or greater than 15  deg.C.
    (B) Primary dilution air shall be filtered at the dilution air 
inlet. The manufacturer of the primary dilution air filter shall state 
that the filter design has successfully achieved a minimum particle 
removal efficiency of 98% (less than 0.02 penetration) as determined 
using ASTM test method F 1471-93 (incorporated by reference at section 
86.1). Secondary dilution air shall be filtered at the dilution air 
inlet using a high-efficiency particulate air filter (HEPA). The HEPA 
filter manufacturer shall state the HEPA filter design has successfully 
achieved a minimum particle removal efficiency of 99.97% (less than 
0.0003 penetration) as determined using ASTM test method F 1471-93. It 
is recommended that the primary dilution air be filtered using a HEPA 
filter. EPA intends to utilize HEPA filters to condition primary 
dilution air in its test facilities. It is acceptable to use of a 
booster blower upstream or downstream of a HEPA filter in the primary 
dilution tunnel (and upstream of the introduction of engine exhaust 
into the CVS) to compensate for the additional pressure loss associated 
with the filter. The design of any booster blower located downstream of 
the filter should minimize the introduction of additional particulate 
matter into the CVS.
    (C) Primary dilution air may be sampled to determine background 
particulate levels, which can then be subtracted from the values 
measured in the diluted exhaust stream. In the case of primary dilution 
air, the background particulate filter sample shall be taken 
immediately downstream of the dilution air filter and upstream of the 
engine exhaust flow (Figure N07-1). The provisions of paragraphs (b)(7) 
of this section, and of Sec. 86.1312-2007 also apply to the measurement 
of background particulate matter, except that the filter temperature 
must be maintained below 52  deg.C.
    (2) Heated proportional bag sampling systems. If a heated (191 
 11  deg.C) proportional bag sampling system is used for 
THC measurement, sample bags must demonstrate minimal outgassing and 
permeability by passing the following performance test:
    (i) Performance test for sample bag HC outgassing and 
CO2 permeability. Bring the bag system to its operational 
temperature. Fill the heated sample bag with a nominal mixture of 1% 
CO2 in

[[Page 5171]]

N2. Perform an initial measurement of CO2 and THC 
from the sample bag, and repeat the measurement after one hour. 
Acceptable performance criteria are 
2% decrease of the initial CO2 reading and 1 ppmC THC.
    (ii) [Reserved]
    (3) Continuous HC measurement system. (i) The continuous HC sample 
system (as shown in Figure N07-1) uses an ``overflow'' zero and span 
system. In this type of system, excess zero or span gas spills out of 
the probe when zero and span checks of the analyzer are made. The 
``overflow'' system may also be used to calibrate the HC analyzer per 
Sec. 86.1321(b), although this is not required.
    (ii) No other analyzers may draw a sample from the continuous HC 
sample probe, line or system, unless a common sample pump is used for 
all analyzers and the sample line system design reflects good 
engineering practice.
    (iii) The overflow gas flow rates into the sample line shall be at 
least 105% of the sample system flow rate.
    (iv) The overflow gases shall enter the heated sample line as close 
as practicable to the outside surface of the CVS duct or dilution 
tunnel.
    (v) The continuous HC sampling system shall consist of a probe 
(which must raise the sample to the specified temperature) and, where 
used, a sample transfer system (which must maintain the specified 
temperature). The continuous hydrocarbon sampling system (exclusive of 
the probe) shall:
    (A) Maintain a wall temperature of 191 deg.C  11 deg.C 
as measured at every separately controlled heated component (i.e., 
filters, heated line sections), using permanent thermocouples located 
at each of the separate components.
    (B) Have a wall temperature of 191 deg.C  11 deg.C over 
its entire length. The temperature of the system shall be demonstrated 
by profiling the thermal characteristics of the system at initial 
installation and after any major maintenance performed on the system. 
The temperature profile of the HC sampling system shall be demonstrated 
by inserting thermocouple wires (typically Teflon\TM\ coated for ease 
of insertion) into the sampling system assembled in-situ where 
possible, using good engineering judgment. The wire should be inserted 
up to the HFID inlet. Stabilize the sampling system heaters at normal 
operating temperatures. Withdraw the wires in increments of 5 cm to 10 
cm (2 inches to 4 inches) including all fittings. Record the stabilized 
temperature at each position. The system temperature will be monitored 
during testing at the locations and temperature described in 
Sec. 86.1310-90(b)(3)(v)(A).

    Note: It is understood that profiling of the sample line can be 
done under flowing conditions also as required with the probe. This 
test may be cumbersome if test facilities utilize long transfer 
lines and many fittings; therefore it is recommended that transfer 
lines be kept as short as possible and the use of fittings should be 
kept minimal.

    (C) Maintain a gas temperature of 191 deg.C 11 deg.C 
immediately before the heated filter and HFID. These gas temperatures 
will be determined by a temperature sensor located immediately upstream 
of each component.
    (vi) The continuous hydrocarbon sampling probe shall:
    (A) Be defined as the first 25.4 cm (10 in) to 76.2 cm (30 in) of 
the continuous hydrocarbon sampling system;
    (B) Have a 0.483 cm (0.19 in) minimum inside diameter;
    (C) Be installed in the primary dilution tunnel at a point where 
the dilution air and exhaust are well mixed (i.e., approximately 10 
tunnel diameters downstream of the point where the exhaust enters the 
dilution tunnel);
    (D) Be sufficiently distant (radially) from other probes and the 
tunnel wall so as to be free from the influence of any wakes or eddies; 
and
    (E) Increase the gas stream temperature to 191 deg.C  
11 deg.C by the exit of the probe. The ability of the probe to 
accomplish this shall be demonstrated at typical sample flow rates 
using the insertion thermocouple technique at initial installation and 
after any major maintenance. Compliance with the temperature 
specification shall be demonstrated by monitoring during each test the 
temperature of either the gas stream or the wall of the sample probe at 
its terminus.
    (vii) The response time of the continuous measurement system shall 
be no greater than:
    (A) 1.5 seconds from an instantaneous step change at the port 
entrance to the analyzer to within 90 percent of the step change;
    (B) 10 seconds from an instantaneous step change at the entrance to 
the sample probe or overflow span gas port to within 90 percent of the 
step change. Analysis system response time shall be coordinated with 
CVS flow fluctuations and sampling time/test cycle offsets if 
necessary; and
    (C) For the purpose of verification of response times, the step 
change shall be at least 60 percent of full-scale chart deflection.
    (4) Primary-dilution tunnel. (i) The primary dilution tunnel shall 
be:
    (A) Small enough in diameter to cause turbulent flow (Reynolds 
Number greater than 4000) and of sufficient length to cause complete 
mixing of the exhaust and dilution air. Good engineering judgment shall 
dictate the use of mixing plates and mixing orifices to ensure a well-
mixed sample. To verify mixing, EPA recommends flowing a tracer gas 
(i.e. propane or CO2) from the raw exhaust inlet of the 
dilution tunnel and measuring its concentration at several points along 
the axial plane at the sample probe. Tracer gas concentrations should 
remain nearly constant (i.e. within 2%) between all of these points.
    (B) At least 8 inches (20 cm) in diameter.
    (C) Constructed of electrically conductive material which does not 
react with the exhaust components.
    (D) Electrically grounded.
    (E) EPA recommends that the tunnel should have minimal thermal 
capacitance such that the temperature of the walls tracks with the 
temperature of the diluted exhaust.
    (ii) The temperature of the diluted exhaust stream inside of the 
primary dilution tunnel shall be sufficient to prevent water 
condensation.
    (iii) The engine exhaust shall be directed downstream at the point 
where it is introduced into the primary dilution tunnel.
    (5) Continuously integrated NOX, CO, and CO2 measurement 
systems. (i) The sample probe shall:
    (A) Be in the same plane as the continuous HC probe, but shall be 
sufficiently distant (radially) from other probes and the tunnel wall 
so as to be free from the influences of any wakes or eddies; and
    (B) Heated and insulated over the entire length, to prevent water 
condensation, to a minimum temperature of 131 deg.F (55 deg. C). Sample 
gas temperature immediately before the first filter in the system shall 
be at least 131 deg. F (55 deg. C).
    (ii) The continuous NOX, CO, or CO2 sampling and 
analysis system shall conform to the specifications of subpart D of 
this part, with the following exceptions:
    (A) The system components required to be heated by subpart D need 
only be heated to prevent water condensation, the minimum component 
temperature shall be 131 deg. F (55 deg. C);
    (B) The system response defined in Sec. 86.329-79 shall be no 
greater than 10 seconds. Analysis system response time shall be 
coordinated with CVS flow fluctuations and sampling time/test cycle 
offsets, if necessary;
    (C) Alternative NOX measurement techniques outlined in 
Sec. 86.346-79 are

[[Page 5172]]

not permitted for NOX measurement in this subpart;
    (D) All analytical gases shall conform to the specifications of 
Sec. 86.1314;
    (E) Any range on a linear analyzer below 100 ppm shall have and use 
a calibration curve conforming to Sec. 86. 1323-07; and
    (F) The measurement accuracy requirements are specified in Sec. 86. 
1338-07 .
    (iii) The signal output of analyzers with non-linear calibration 
curves shall be converted to concentration values by the calibration 
curve(s) specified in subpart D of this part (Sec. 86.330-79) before 
flow correction (if used) and subsequent integration takes place.
    (6) Particulate sampling system. This method collects a 
proportional sample from the primary tunnel, and then transfers this 
sample to a secondary dilution tunnel where the sample is further 
diluted. The double-diluted sample is then passed through the 
collection filter. Proportionality (i.e., mass flow ratio) between the 
primary tunnel flow rate and the sample flow rate must be maintained 
within 5%, excluding the first 10 seconds of the test at 
start-up. The requirements for this system are:
    (i) The particulate sample transfer tube shall be configured and 
installed so that:
    (A) The inlet faces upstream in the primary dilution tunnel at a 
point where the primary dilution air and exhaust are well mixed.
    (B) The particulate sample exits on the centerline of the secondary 
tunnel.
    (ii) The entire particulate sample transfer tube shall be:
    (A) Sufficiently distant (radially) from other sampling probes (in 
the primary dilution tunnel) so as to be free from the influence of any 
wakes or eddies produced by the other probes.
    (B) 0.85 cm minimum inside diameter.
    (C) No longer than 36 in (91 cm) from inlet plane to exit plane.
    (D) Designed to minimize the diffusional and thermophoretic 
deposition of particulate matter during transfer (i.e., sample 
residence time in the transfer tube should be as short as possible, 
temperature gradients between the flow stream and the transfer tube 
wall should be minimized). Double-wall, thin-wall, air-gap insulated, 
or a controlled heated construction for the transfer tube is 
recommended.
    (E) Constructed such that the surfaces exposed to the sample shall 
be an electrically conductive material, which does not react with the 
exhaust components, and this surface shall be electrically grounded so 
as to minimize electrostatic particulate matter deposition.
    (iii) The secondary dilution air shall be at a temperature equal to 
or greater than 15 deg. C.
    (iv) The secondary-dilution tunnel shall be constructed such that 
the surfaces exposed to the sample shall be an electrically conductive 
material, which does not react with the exhaust components, and this 
surface shall be electrically grounded so as to minimize electrostatic 
particulate deposition.
    (v) Additional dilution air must be provided so as to maintain a 
sample temperature of 47 deg. C  5 deg. C upstream of the 
sample filter. Temperature shall be measured with a thermocouple with a 
\3/16\" shank, having thermocouple wires with a gage diameter 24 AWG or 
smaller, a bare-wire butt-welded junction; or other suitable 
temperature measurement with an equivalent or faster time constant and 
an accuracy and precision of  1.9 deg. C.
    (vi) The filter holder assembly shall be located within 12.0 in 
(30.5 cm) of the exit of the secondary dilution tunnel.
    (vii) The face velocity through the sample filter shall not exceed 
100 cm/s (face velocity is defined as the standard volumetric sample 
flow rate (i.e., scm3/sec) divided by the sample filter stain area 
(i.e., cm2)).
    (7) Particulate sampling. (i) Filter specifications. (A) 
Polytetrafluoroethylene (PTFE or Teflon\TM\) coated borosilicate glass 
fiber high-efficiency filters or polytetrafluoroethylene (PTFE or 
Teflon\TM\) high-efficiency membrane filters with an integral support 
ring of polymethylpentene (PMP) or equivalent inert material are 
required. Filters shall have a minimum clean filter efficiency of 99% 
as measured by the ASTM D2986-95a DOP test (incorporated by reference 
at Sec. 86.1).
    (B) Particulate filters must have a diameter of 46.50  
0.6 mm ( 38 mm minimum stain diameter).
    (C) The dilute exhaust is simultaneously sampled by a single high-
efficiency filter during the cold-start test and by a second high 
efficiency filter during the hot-start test.
    (D) It is recommended that the filter loading should be maximized 
consistent with temperature requirements.
    (ii) Filter holder assembly. The filter holder assembly shall 
comply with the specifications set forth for ambient PM measurement in 
40 CFR Part 50, Appendix L 7.3.5, figures L-25 and L-26, with the 
following exceptions:
    (A) The material shall be 302, 303, or 304 stainless steel instead 
of anodized aluminum.
    (B) The 2.84 cm diameter entrance to the filter holder may be 
adapted, using sound engineering judgment and leak-free construction, 
to an inside diameter no smaller than 0.85 cm, maintaining the 
12.5 deg. angle from the inlet of the top filter holder to the area 
near the sealing surface of the top of the filter cartridge assembly. 
Figure N07-2 shows acceptable variation from the design in 40 CFR Part 
50, Appendix L. Similar variations using sound engineering design are 
also acceptable provided that they provide even flow distribution 
across the filter media and a similar leak-free seal with the filter 
cartridge assembly.
    (C) If additional or multiple filter cartridges are stored in a 
particulate sampler as part of an automatic sequential sampling 
capability, all such filter cartridges, unless they are installed in 
the sample flow (with or without flow established) shall be covered or 
sealed to prevent communication of semi-volatile matter from filter to 
filter; contamination of the filters before and after sampling; or loss 
of volatile or semi-volatile particulate matter after sampling.
    (iii) Filter cartridge assembly. The filter cartridge assembly 
shall comply with the specifications set forth for ambient PM 
measurement in 40 CFR Part 50, Appendix L 7.3.5, figures L-27, L-28, 
and L-29, with the following exceptions:
    (A) In addition to the specified Delrin TM material, 
302, 303, or 304 stainless steel, polycarbonate or acrylonitrile/
butadiene/styrene (ABS) resin, or a combination of these materials may 
also be used.
    (B) A bevel introduced on the inside diameter of the entrance to 
the filter cartridge, as used by some commercially available automated 
sequential particulate filter cartridge changers, is also acceptable 
(see Figure N07-3).
    (iv) Particle preclassifier. A particle preclassifier shall be 
installed immediately upstream of the filter holder assembly (N07-1). 
The purpose of the preclassifier is to remove coarse, mechanically 
generated particles (e.g., rust from the engine exhaust system or 
carbon sheared from the sampling system walls) from the sample flow 
stream while allowing combustion-generated particles to pass through to 
the filter. The preclassifier may be either an inertial impactor or a 
cyclonic separator. The preclassifier manufacturer 50% cutpoint 
particle diameter shall be between 2.5 m and 10 m at 
the volumetric flow rate selected for sampling of particulate matter 
emissions. Sharpness of cut is not specifically defined, but the

[[Page 5173]]

preclassifier geometry shall allow at least 99% of the mass 
concentration of 1 m particles to pass through the exit of the 
preclassifier to the filter at the volumetric flow rate selected for 
sampling particulate matter emissions. Periodic servicing of the 
preclassifier will be necessary to prevent a buildup of mechanically 
separated particles. The particle preclassifier may be made integral 
with the top of the filter holder assembly. The preclassifier may also 
be made integral with a mixing-tee for introduction of secondary 
dilution air, thus replacing the secondary dilution tunnel; provided 
that the preclassifier provides sufficient mixing.

BILLING CODE 6560-50-P

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    30. A new section 86.1312-2007 is added to Subpart N to read as 
follows:


Sec. 86.1312-2007  Filter stabilization and microbalance workstation 
environmental conditions, microbalance specifications, and particulate 
matter filter handling and weighing procedures.

    (a) Ambient conditions for filter stabilization and weighing.--(1) 
Temperature and humidity. (i) The filter stabilization environment 
shall be maintained at 22  deg.C  3  deg.C and a dewpoint 
of 9.5  deg.C  1  deg.C. Dewpoint shall be measured with an 
instrument that exhibits an accuracy of at least 0.25 
deg.C NIST traceable as stated by the instrument manufacturer. 
Temperature shall be measured with an instrument that exhibits an 
accuracy of at least 0.2 deg.C or better.
    (ii) The immediate microbalance workstation environment shall be 
maintained at 22  deg.C  1  deg.C and a dewpoint of 9.5 
deg.C  1  deg.C. If the microbalance workstation 
environment freely circulates with the filter stabilization 
environment, and this entire environment meets 22  deg.C  1 
 deg.C and a dewpoint of 9.5  deg.C  1  deg.C , then there 
is no requirement to measure temperature and dewpoint at the 
microbalance separate from the filter stabilization location. 
Otherwise, temperature at the microbalance workstation shall be 
measured with an instrument that exhibits an accuracy of at least 
0.2 deg.C or better, and dewpoint shall be measured with an 
instrument that exhibits an accuracy of at least 0.25 
deg.C NIST traceable as stated by the instrument manufacturer.
    (2) Cleanliness. (i) The microbalance and filter stabilization 
environments shall be free of ambient contaminants (such as dust or 
other aerosols) that could settle on the particulate filters. It is 
recommended that these environments be built to conform with the Class 
1000 specification (or cleaner) as determined by Federal Standard 209D 
or 209E for clean room classification (Available from the Institute of 
Environmental Standards and Technology website at www.iest.org or phone 
(847) 255-1561). An alternative recommendation would be to equilibrate 
and/or weigh the filters within a separate, smaller, particle-free, 
temperature and humidity-controlled chamber (i.e., ``glove box'').
    (ii) Reference filters shall be used to monitor for gross particle 
contamination. It is required that at least two unused reference 
filters remain in the filter stabilization environment at all times in 
partially covered glass petri dishes, as in paragraph (c) (1) of this 
section. These reference filters shall be placed in the filter 
stabilization environment. The reference filters shall be weighed 
within 2 hours of, but preferably at the same time as, the sample 
filters. The reference filters shall be changed at least once a month, 
but never while any sample filters are between their tare weight (pre-
sampling) and gross weight (post-sampling) measurements. The reference 
filters shall be the same size and material as the sample filters.
    (3) Quality control of ambient conditions. (i) If, before the start 
of a weighing session, the temperature or dewpoint of the filter 
stabilization environment are not within specifications, then filters 
must remain in the environment for at least 30 minutes after conditions 
are corrected. If the filter stabilization environment changes during a 
weighing session such that the specifications are no longer met, the 
weighing session shall be suspended until the environment has returned 
to within specifications for at least 30 minutes. Once the environment 
has returned to within specifications for at least 30 minutes, the 
reference filters shall be reweighed and the criteria in paragraph 
(a)(3)(ii) of this section shall apply. Note that temperature and 
dewpoint shall be sampled once per second, and an unweighted 5-minute 
moving average of this data shall be calculated once per second. This 
moving average shall be used to determine the environment temperature 
and dewpoint for the purpose of determining whether or not the 
environment is within specifications.
    (ii) If the average change in weight of the reference filters is 
more than 10 micrograms (after correcting for buoyancy as described in 
paragraph (c)(3) of this section), then all filters in the process of 
stabilization shall be discarded and all data collected with respect to 
the discarded filters shall be considered void. Note that more than 2 
reference filters may be used to achieve a more robust average of the 
change in weight of the reference filters.
    (b) Microbalance specifications. The microbalance used to determine 
the weights of all filters shall have a precision (standard deviation) 
of at least 0.25 micrograms or better for repeated weighing 
of a calibration weight, a precision of at least 2.5 
micrograms or better for repeated weighing of a clean filter, and a 
readability equal to or less than 0.1 micrograms. It is recommended 
that the microbalance be installed on a vibration isolation platform to 
isolate the microbalance's load cell from external vibration. It is 
also recommended that the microbalance should be shielded from 
convective airflow by means of an electrically grounded static 
dissipative draft shield. Microbalance manufacturer specifications for 
all preventive maintenance, periodic certification, calibration, and 
re-zeroing shall be followed. All certification and calibration 
procedures shall be NIST traceable, or traceable to an equivalent 
national standard.
    (c) Particulate matter filter handling and weighing. Care should be 
taken to prevent contamination of the sample filters and to prevent a 
buildup of static charge on the filters that could interfere with 
filter weighing. Static neutralizers, such as Po-210 sources, shall be 
used to neutralize charge on a filter prior to each weighing. A static 
neutralizer should be replaced at the interval recommended by its 
manufacturer, or when it is no longer able to reduce static charge on a 
filter to less than 2 VDC as measured with an electrostatic 
monitor at the microbalance workstation. The person weighing filters 
shall be grounded with respect to the microbalance to prevent imparting 
a static charge on the filters. This can be accomplished safely by 
using a grounding strap such as the wrist straps that are commonly used 
in the microelectronics industry, or by connecting a similar grounding 
strap to the tweezers. To prevent electrical shock, a 1-megohm resistor 
should be installed in series between the person weighing filters and 
ground.
    (1) Within the filter stabilization environment, a pair of clean 
and electrically conductive tweezers shall be used to place a filter in 
the lower half of a filter cassette and the cassette shall be placed in 
a partially open glass petri dish. The petri dish lid should extend 
over the filter to prevent gross contamination, but it should be left 
slightly open on one edge to permit stabilization with the environment 
for at least 30 minutes.
    (2) After at least 30 minutes of stabilization, each filter shall 
be weighed using the specified microbalance. The process of weighing a 
filter may be repeated and a statistical mean weight of a single filter 
may be calculated. Sound engineering judgment shall dictate the use of 
statistics to discard outliers and the weighting of averages. For a 
clean filter its single weight or statistical mean weight shall be 
considered the uncorrected tare weight of the filter.
    (3) All filter weights shall be corrected for filter buoyancy in 
air. For the uncorrected tare weight of a filter, this calculated value 
is the corrected tare weight of the filter, and it must be recorded 
(see Sec. 86.1344(e)(18)).

[[Page 5178]]

Barometric pressure of the microbalance environment shall be measured 
with an instrument that exhibits 0.01% full-scale accuracy 
and 0.01% per-year full scale stability, and the full-scale value used 
for such a specification shall not exceed 200 kPa.
    (i) Buoyancy correction calculation. (A) Calculate vapor pressure 
of liquid water using the dewpoint temperature in the Magnus formula:

Pw = 0.6113  x  10 ((7.5  x  Tdp)/
(237.3 + Tdp))

Where:

Pw=vapor pressure of liquid water, kPa.
Tdp=dewpoint temperature,  deg.C.

    (B) Calculate air density using the ideal gas relationship and 
molecular weights of standard air and water:
    A=(3.484 x P-1.317 x Pw)/(T+273.15)

Where:

A=air density, kg/m\3\.
P=barometric pressure, kPa.
Pw=vapor pressure of liquid water, kPa.
T=temperature,  deg.C.

    (C) Buoyancy correction:
    M=R x (1-(A/w))/(1-(A/s)).

Where:

M=corrected mass in units of the balance display.
R=uncorrected filter weight in units of the balance display.
A=calculated air density, kg/m\3\.
w=density of calibration weight used to 
calibrate the balance, kg/m\3\.
s=density of filter material used to sample PM 
emissions, kg/m\3\.

    (ii) For determining s note that PTFE 
(Teflon\TM\) and borosilicate glass both have densities in the range of 
2,200 to 2,400 kg/m\3\. Therefore, for PTFE-coated borosilicate glass 
fiber filters, an acceptable s is 2,300 kg/m\3\. 
Note also that polymethylpentene has a density of 850 kg/m\3\. Because 
Teflon PTFE membrane filters have an integral polymethylpentene support 
ring that accounts for 95% of the filter mass, an acceptable 
s for these filters is 920 kg/m\3\. Other 
s values for other filters may be obtained 
similarly. Information about ``s should be 
available from the calibration weight manufacturer.
    (iii) This paragraph (c)(3)(iii) shows an example of the buoyancy 
correction. This example assumes the following inputs: Barometric 
pressure (P)=101.325 kPa, temperature (T)=22.0  deg.C, dewpoint 
temperature (Tdp)=9.5  deg.C, balance display (R)=100.0000 
mg, calibration weight density (w)=8,000 kg/m\3\, 
and filter material density (s)=2,300 kg/m\3\. 
Then:
    (A) The water vapor pressure (Pw) is calculated as:

Pw = 0.6113  x  10 ((7.5  x  9.5)/(237.3 + 9.5)) = 1.186 
kPa.

    (B) The air density (A) is calculated as:

A = (3.484  x 101.325 - 1.317  x  1.186)/(22.0 + 273.15) = 1.191 kg/
m\3\.

    (C) The corrected mass (M) is calculated as:

M=100.0000  x  (1 - (1.191/8000))/(1 - (1.191/2300)) = 100.0369 mg.

    (4) The uncorrected weight, corrected weight, barometric pressure, 
temperature and humidity, of the filter shall be recorded. Afterward 
the filter shall be returned to the lower half of the filter cassette, 
and the upper half of the cassette shall be set in place. The cassette-
with filter-shall then be stored in a covered glass petri dish or a 
sealed (i.e., ends plugged) filter holder assembly, either of which 
shall remain in the filter stabilization environment until needed for 
testing. It is recommended that the filter be transported between the 
filter stabilization environment and the location of the emissions test 
within a sealed filter holder assembly.
    (5) After the emissions test, the filter cassette shall be removed 
from the filter holder assembly. If this removal is performed in the 
filter stabilization environment, the upper half of the cassette shall 
be removed using a properly designed separator tool, the lower half of 
the cassette-with filter-shall be placed in a partially covered petri 
dish, and allowed to stabilize for at least 30 minutes. Otherwise, the 
cassette and filter shall be placed in a closed petri dish until it can 
be returned to the filter stabilization environment. Once the closed 
petri dish is returned to the filter stabilization environment, the 
petri dish shall be opened, the upper half of the cassette shall be 
removed using a properly designed separator tool, the lower half of the 
cassette-with filter-shall be placed in a partially covered petri dish, 
and allowed to stabilize for at least one hour.
    (6) After at least 30 minutes, but no more than 60 hours of 
stabilization, each filter may be weighed using the specified 
microbalance. The process of weighing a filter may be repeated and a 
statistical mean may be calculated. Sound engineering judgment shall 
dictate the use of statistics to discard outliers and the weighting of 
averages. For a used filter, its single weight or statistical mean 
weight shall be identified as the uncorrected gross weight of the 
filter. The uncorrected gross weight shall be corrected for filter 
buoyancy using the procedure in (c)(3) of this section. The uncorrected 
gross filter weight, corrected gross filter weight, barometric 
pressure, temperature, and dewpoint shall be recorded.
    (7) The net particulate matter weight (Pf) of each filter shall be 
equal to the corrected gross filter weight minus the corrected tare 
filter weight.
    (8) Should the particulate matter on the filters contact the petri 
dish, tweezers, microbalance or any other surface, the data with 
respect to that filter is void.

    31. A new Sec. 86.1313-2004 is added to subpart N to read as 
follows:


Sec. 86.1313-2004  Fuel specifications.

    Section 86.1313-04 includes text that specifies requirements that 
differ from Sec. 86.1313-94 and Sec. 86.1313-98. Where a paragraph in 
Sec. 86.1313-94 or Sec. 86.1313-98 is identical and applicable to 
Sec. 86.1313-04, this may be indicated by specifying the corresponding 
paragraph and the statement ``[Reserved]. For guidance see 
Sec. 86.1313-94.'' or ``[Reserved]. For guidance see Sec. 86.1313-
98.''.
    (a) Gasoline fuel. (1) Gasoline having the following specifications 
will be used by the Administrator in exhaust and evaporative emission 
testing of petroleum-fueled Otto-cycle engines, except that the 
Administrator will not use gasoline having a sulfur specification 
higher than 0.0045 weight percent. Gasoline having the following 
specification or substantially equivalent specifications approved by 
the Administrator, must be used by the manufacturer in exhaust and 
evaporative testing except that octane specifications do not apply:

----------------------------------------------------------------------------------------------------------------
                  Item                      ASTM test method No.                        Value
----------------------------------------------------------------------------------------------------------------
(i) Octane, Research, Min..............  D2699                       93
(ii) Sensitivity, Min..................  ..........................  7.5
(iii) Lead (organic), maximum: g/U.S.    D3237                       0.050 (0.013)
 gal. (g/liter).
(iv) Distillation Range:...............  D86
(A) IBP \1\:  deg.F ( deg.C)...........  ..........................  75-95 (23.9-35)
(B) 10 pct. point:  deg.F ( deg.C).....  ..........................  120-135 (48.9-57.2)

[[Page 5179]]

 
(C) 50 pct. point:  deg.F ( deg.C).....  ..........................  200-230 (93.3-110)
(D) 90 pct. point:  deg.F ( deg.C).....  ..........................  300-325 (148.9-162.8)
(E) EP, max:  deg.F ( deg.C)...........  ..........................  415 (212.8)
(v) Sulfur, weight pct.................  D1266                       0.0015-0.008
(vi) Phosphorous, max. g/U.S. gal (g/    D3231                       0.005 (0.0013)
 liter).
(vii) RVP \2\, \3\.....................  D3231                       8.7-9.2 (60.0-63.4)
(viii) Hydrocarbon composition:........  D1319
(A) Olefins, max. pct..................  ..........................  10
(B) Aromatics, max, pct................  ..........................  35
(C) Saturates..........................  ..........................  Remainder
----------------------------------------------------------------------------------------------------------------
\1\ For testing at altitudes above 1,219 m (4000 feet), the specified range is 75-105 deg. F (23.9-40.6 deg. C).
 
\2\ For testing which is unrelated to evaporative emission control, the specified range is 8.0-9.2 psi (55.2-
  63.4 kPa).
\3\ For testing at altitudes above 1,219 m (4000 feet), the specified range is 7.6-8.0 psi (52-55 kPa).

    (2) For engines certified for sale in the 50 United States, 
``California Phase 2'' gasoline having the specifications listed in the 
table in this section may be used in exhaust emission testing as an 
option to the specifications in paragraph (a)(1) of this section. If a 
manufacturer elects to utilize this option, the manufacturer must 
conduct exhaust emission testing with gasoline having the 
specifications listed in the table in this paragraph (a)(2). However, 
the Administrator may use or require the use of test fuel meeting the 
specifications in paragraph (a)(1) of this section for certification 
confirmatory testing, selective enforcement auditing and in-use 
testing. All fuel property test methods for this fuel are contained in 
Chapter 4 of the California Regulatory Requirements Applicable to the 
National Low Emission Vehicle Program (October, 1996). These 
requirements are incorporated by reference (see Sec. 86.1). The table 
follows:

----------------------------------------------------------------------------------------------------------------
               Fuel property                                                Limit
----------------------------------------------------------------------------------------------------------------
(i) Octane, (R+M)/2 (min).................  91
(ii) Sensitivity (min)....................  7.5
(iii) Lead, g/gal (max) (No lead added)...  0-0.01
(iv) Distillation Range,  deg.F:..........  ....................................................................
(A) 10 pct. point,........................  130-150
(B) 50 pct. point,........................  200-210
(C) 90 pct. point,........................  290-300
(D) EP, maximum...........................  390
(v) Residue, vol % (max)..................  2.0
(vi) Sulfur, ppm by wt....................  15-40, except that Administrator may use and approve for use, lower
                                             ranges where such ranges are consistent with current California
                                             requirements.
(vii) Phosphorous, g/gal (max)............  0.005
(viii) RVP, psi...........................  6.7-7.0
(ix) Olefins, vol %.......................  4.0-6.0
(x) Total Aromatic Hydrocarbons (vol %)...  22-25
(xi) Benzene, vol %.......................  0.8-1.0
(xii) Multi-Substituted Alkyl Aromatic      12-14
 Hydrocarbons, vol %.
(xiii) MTBE, vol %........................  10.8-11.2
(xiv) Additives...........................  See Chapter 4 of the California Regulatory Requirements Applicable
                                             to the National Low Emission Vehicle Program (October, 1996). These
                                             procedures are incorporated by reference (see Sec.  86.1).
(xv) Copper Corrosion.....................  No. 1
(xvi) Gum, Washed, mg/100 ml (max)........  3.0
(xvii) Oxidation Stability, minutes (min).  1000
(xviii) Specific Gravity..................  No limit; report to purchaser required
(xix) Heat of Combustion..................  No limit; report to purchaser required
(xx) Carbon, wt %.........................  No limit; report to purchaser required
(xxi) Hydrogen, wt %......................  No limit; report to purchaser required
----------------------------------------------------------------------------------------------------------------

    (3)(i) Unless otherwise approved by the Administrator, unleaded 
gasoline representative of commercial gasoline that will be generally 
available through retail outlets must be used in service accumulation. 
Unless otherwise approved by the Administrator, this gasoline must have 
a minimum sulfur content of 15 ppm. Unless otherwise approved by the 
Administrator, fuel used for evaporative emission durability 
demonstration must contain ethanol as required by Sec. 86.1824-
01(a)(2)(iii). Leaded gasoline must not be used in service 
accumulation.
    (ii) Unless otherwise approved by the Administrator, the octane 
rating of the gasoline used must be no higher than 1.0 Retail octane 
number above the lowest octane rating that meets the fuel grade the 
manufacturer will recommend to the ultimate purchaser for the relevant 
production vehicles. If the manufacturer recommends a Retail octane 
number rather than a fuel grade, then the octane rating of the service 
accumulation gasoline can be no higher than 1.0 Retail octane number 
above the recommended Retail octane number. The service accumulation 
gasoline must

[[Page 5180]]

also have a minimum sensitivity of 7.5 octane numbers, where 
sensitivity is defined as the Research octane number minus the Motor 
octane number.
    (iii) The Reid Vapor Pressure of the gasoline used must be 
characteristic of the motor fuel used during the season in which the 
service accumulation takes place.
    (4) The specification range of the gasoline to be used under 
paragraph (a) of this section must be reported in accordance with 
Sec. 86.094-21(b)(3).
    (b) heading and (b)(1) [Reserved]. For guidance see Sec. 86.1313-
94.
    (b)(2) [Reserved]. For guidance see Sec. 86.1313-98.
    (b)(3) through (g) [Reserved]. For guidance see Sec. 86.1313-94.
    32. A new Sec. 86.1313-2007 is added to Subpart N to read as 
follows:


Sec. 86.1313-2007  Fuel specifications.

    Section 86.1313-2007 includes text that specifies requirements that 
differ from Sec. 86.1313-94 and Sec. 86.1313-2004. Where a paragraph in 
Sec. 86.1313-94 or Sec. 86.1313-2004 is identical and applicable to 
Sec. 86.1313-2007, this may be indicated by specifying the 
corresponding paragraph and the statement ``[Reserved]. For guidance 
see Sec. 86.1313-94.'' or ``[Reserved]. For guidance see Sec. 86.1313-
04.''.
    (a) [Reserved]. For guidance see Sec. 86.1313-2004.
    (b) heading and (b)(1) [Reserved]. For guidance see Sec. 86.1313-
94.
    (b)(2) Petroleum fuel for diesel engines meeting the specifications 
in Table N07-2, or substantially equivalent specifications approved by 
the Administrator, shall be used in exhaust emissions testing. The 
grade of petroleum fuel used shall be commercially designated as ``Type 
2-D'' grade diesel fuel except that fuel commercially designated as 
``Type 1-D'' grade diesel fuel may be substituted provided that the 
manufacturer has submitted evidence to the Administrator demonstrating 
to the Administrator's satisfaction that this fuel will be the 
predominant in-use fuel. Such evidence could include such things as 
copies of signed contracts from customers indicating the intent to 
purchase and use ``Type 1-D'' grade diesel fuel as the primary fuel for 
use in the engines or other evidence acceptable to the Administrator. 
(Note: Vehicles certified under Sec. 86.007-11(f) must be tested using 
the test fuel specified in Sec. 86.1313-2004, unless otherwise allowed 
by the Administrator.) Table N07-2 follows:

                                                   Table N07-2
----------------------------------------------------------------------------------------------------------------
            Item                                    ASTM test method No.        Type 1-D            Type 2-D
----------------------------------------------------------------------------------------------------------------
(i) Cetane Number...........  ....................  D613................  40-54...............            40-50
(ii) Cetane Index...........  ....................  D976................  40-54...............           40-50
(iii) Distillation range:
    (A) IBP.................   deg.F..............  D86.................  330-390.............          340-400
                              ( deg.C)............  ....................  (165.6-198.9).......     (171.1-204.4)
    (B) 10 pct. point.......   deg.F..............  D86.................  370-430.............          400-460
                              ( deg.C)............  ....................  (187.8-221.1).......     (204.4-237.8)
    (C) 50 pct. point.......   deg.F..............  D86.................  410-480.............          470-540
                              ( deg.C)............  ....................  (210.0-248.9).......     (243.3-282.2)
    (D) 90 pct. point.......   deg.F..............  D86.................  460-520.............          560-630
                              ( deg.C)............  ....................  (237.8-271-1).......     (293.3-332.2)
    (E) EP..................   deg.F..............  D86.................  500-560.............          610-690
                              ( deg.C)............  ....................  (260.0-293.3).......     (321.1-365.6)
(iv) Gravity................   deg.API............  D287................  40-44...............            32-37
(v) Total sulfur............  ppm.................  D2622...............  7-15................             7-15
(vi) Hydrocarbon
 composition:.
    (A) Aromatics, minimum    pct.................  D5186...............  8...................               27
     (Remainder shall be
     paraffins, naphthenes,
     and olefins).
(vii) Flashpoint, min.......   deg.F..............  D93.................  120.................              130
                              ( deg.C)............  ....................  (48.9)..............            (54.4)
(viii) Viscosity............  centistokes.........  D445................  1.6-2.0.............          2.0-3.2
----------------------------------------------------------------------------------------------------------------

    (3) Petroleum Diesel fuel for diesel engines meeting the 
specifications in table N07-3, or substantially equivalent 
specifications approved by the Administrator, shall be used in service 
accumulation. The grade of petroleum diesel fuel used shall be 
commercially designated as Type 2-D'' grade diesel fuel except that 
fuel commercially designated as ``Type 1-D'' grade Diesel fuel may be 
substituted provided that the manufacturer has submitted evidence to 
the Administrator demonstrating to the Administrator's satisfaction 
that this fuel will be the predominant in-use fuel. Such evidence could 
include such things as copies of signed contracts from customers 
indicating the intent to purchase and use ``Type 1-D'' grade diesel 
fuel as the primary fuel for use in the engines or other evidence 
acceptable to the Administrator. Table N07-03 follows:

                                                   Table N07-3
----------------------------------------------------------------------------------------------------------------
            Item                                    ASTM test method No.        Type 1-D            Type 2-D
----------------------------------------------------------------------------------------------------------------
(i) Cetane Number...........  ....................  D613................  40-56...............            38-58
(ii) Cetane Index...........  ....................  D976................  min. 40.............         min. 40
(iii) Distillation range:
    90 pct. point...........   deg.F..............  D86.................  440-530.............          540-630
                              ( deg.C)............  ....................  (226.7-276-7).......     (293.3-332.2)
(iv) Gravity................   deg.API............  D287................  39-45...............            30-39
(v) Total sulfur............  ppm.................  D2622...............  7-15................             7-15

[[Page 5181]]

 
(vi) Flashpoint, min........   deg.F..............  D93.................  130.................              130
                              ( deg.C)............  ....................  (54.4)..............            (54.4)
(vii) Viscosity.............  centistokes.........  D445................  1.2-2.2.............          1.5-4.5
----------------------------------------------------------------------------------------------------------------

    (b)(4) through (g) [Reserved]. For guiDance see Sec. 86.1313-94.

    33. Section 86.1319-90 is amended by redesignating paragraph (e) as 
paragraph (f), and adding a new paragraph (e) to read as follows:


Sec. 86.1319-90  CVS calibration.

* * * * *
    (e) SSV calibration. (1) The calibration of the SSV located in the 
tunnel shall be conducted in a similar manner as the CFV or PDP 
calibration. Gas flow within the SSV is a function of inlet pressure, 
P1, the inlet temperature, T1, and the pressure 
drop between the throat and the inlet, DP. Note that the following 
procedure is consistent with SAE J244. The calibration procedure 
described in paragraph (e)(3) of this section establishes the values of 
the coefficients at measured values of pressure, temperature and 
airflow.
    (i) The flow rate for a subsonic venturi is calculated as a 
volumetric flow rate (Qs) or a mass flow rate 
(Qm) as follows: or
[GRAPHIC] [TIFF OMITTED] TR18JA01.011

[GRAPHIC] [TIFF OMITTED] TR18JA01.012

Where:
Kq = 0.0021074 (SI units).
Qs = Air Volume Flow, SCFM (m3/min).
Qm = Air Mass Flow, lbm/min (kg/min).
s = Density at Standard Conditions, lbm/
ft3 (kg/m3) as specified in paragraph 
(e)(1)(v) of this section.
s = Density at inlet conditions, lbm/
ft3 (kg/m3), as specified in paragraph 
(e)(1)(iii) of this section.
Cd = Coefficient of Discharge = Actual Air Flow/
Theoretical Air Flow.
Y = Expansion factor, as specified in paragraph (e)(1)(ii) of this 
section.
d = Throat diameter, inch (mm).
 = Ratio of venturi throat diameter to approach pipe 
diameter.
P = Pressure drop between inlet and throat, in. 
H2O (kPa).
    (ii) The expansion factor (Y) is calculated as follows:
    [GRAPHIC] [TIFF OMITTED] TR18JA01.013
    
    (iii) The inlet density (1) is calculated as follows:
    [GRAPHIC] [TIFF OMITTED] TR18JA01.068
    
Where:
Pabs = P1+PB
Tabs = T1 + 2731
Rmix = Ru/|MWmix
Ru = 8.3144 kJ/kg-mole-K
MWmix = the molecular weight of the mix, as calculated in 
paragraph (e)(1)(iv) of this section.

    (iv) The molecular weight of the mix, is calculated as follows:
    [GRAPHIC] [TIFF OMITTED] TR18JA01.014
    
Where:
PV = Vapor pressure, in Hg (kPa)
MWAIR = 28.964 kg/kg-mole
MWH20 = 18.015 kg/kg-mole

    (v) The density at standard conditions of 101.33 kPa and 20  deg.C 
is calculated as follows:

[[Page 5182]]

[GRAPHIC] [TIFF OMITTED] TR18JA01.015

    (2) The venturi manufacturer's recommended procedure shall be 
followed for calibrating electronic portions of the SSV.
    (3) Measurements necessary for flow calibration of the SSV are as 
follows:

                                          Calibration Data Measurement
----------------------------------------------------------------------------------------------------------------
             Parameter                      Sym                  Units                      Tolerance
----------------------------------------------------------------------------------------------------------------
(i) Barometric pressure (corrected   PB                 in. Hg (kPa)...........   .01in. Hg ( .034kPa)
(ii) Air temperature, into           ETI                 deg. F ( deg. C)......  .5  deg.F (.28 deg.
 calibration venturi.                                                             C)
(iii) Pressure drop between the      EDP                in. H2O (kPA)..........   .05 in. H2O (.012kPa)
 venturi (corrected to 68 deg. F)..
(iv) Air Flow......................  QS                 Std ft\3\/min (m\3\/      5% of NIST
                                                         min).                    ``true'' value
(v) SSV inlet depression...........  P1                 in. H2O (kPa)..........   .23 in. H2O (.057kPa)
(vi) Pressure drop between the       DP                 in. H2O (kPa)..........  .05 in. H2O (.012kPa)
(vii) Water vapor pressure of inlet  PV                 in. Hg (kPa)...........  .10 in. Hg ( .34kPa)
(vii) Temperature at SSV inlet.....  T1                  deg.F ( deg.C)........  4.0  deg.F (2.2
                                                                                  deg. C)
----------------------------------------------------------------------------------------------------------------

    (4) Set up equipment similar to CFV or PDP calibration except the 
variable flow restrictor valve can be deleted or set in the open 
position, and the pressure drop reading device must be added. The 
calibration test must be conducted with the test subsonic venturi in 
place in its permanent position. Any subsequent changes in upstream or 
downstream configuration could cause a shift in calibration. Leaks 
between the calibration metering device and the SSV must be eliminated.
    (5) Adjust the variable flow blower or restrictor valve to its 
maximum in-use flow rate. Allow the system to stabilize and record data 
from all instruments. Be sure to avoid choke condition.
    (6) Vary the flow through a minimum of eight steps covering the 
intended in-use operating range of the SSV.
    (7) Data analyses. If the calibration venturi is used at the tunnel 
inlet (free standing), then assume a value of =0. If the SSV 
installed in the CVS tunnel, use the actual inside tunnel diameter and 
the throat diameter to compute .
    (i) Assume an initial value for Cd = 0.98 to calculate 
Qm for the calculation of Reynolds number, Re,:
[GRAPHIC] [TIFF OMITTED] TR18JA01.016

Where:  = viscosity of air, centipoise
[GRAPHIC] [TIFF OMITTED] TR18JA01.017

K=1.458E-3
TK=(T1 deg.C+273.16)
    (ii) From the initial calibration of the venturi, establish an 
equation of Cd as a function of Re. The following functional forms 
should be reviewed, but a power series, least-squares fit polynomial 
equation may result in the best fit. Many factors involved in the 
installation of SSV and the operating range of the Reynolds number can 
affect the functional relationship of the Cd with Re. Calculate Cd 
based on this initial equation of Re. Compute a final Qm 
based on this calculated Cd for both the calibration nozzle and the 
inline SSV.
    (8)(i) Compute the percent difference in air flow between the 
calibration venturi and the inline SSV. If the difference in percent of 
point is greater than 1%, compute a new Cd and Re for the in-tunnel 
venturi as follows:
Cdnew=Actual Air Flow/Theoretical Air Flow=Qmact 
/Qmtheo
[GRAPHIC] [TIFF OMITTED] TR18JA01.018

    (ii) Qmact is flow measured by the calibration venturi 
and Qmtheo is the theoretical calculated flow based on the 
in-tunnel SSV conditions with Cd set equal to 1. Renew is 
based on the calibrated venturi flow, but the in-tunnel SSV properties. 
Recalculate a new curve fit of Cdnew for the inline venturi 
as a function of Renew following the guidelines in paragraph 
(e)(7) of this section. Agreement of the fit should be within 1.0% of 
point. Install the new Cd curve fit in the test cell flow computing 
device and conduct the propane injection, flow verification test.
* * * * *

    34. A new section 86.1323-2007 is added to Subpart N to read as 
follows:


Sec. 86.1323-2007  Oxides of nitrogen analyzer calibration.

    This section describes the initial and periodic calibration of the 
chemiluminescent oxides of nitrogen analyzer.
    (a) Prior to introduction into service and at least monthly 
thereafter, the chemiluminescent oxides of nitrogen analyzer must be 
checked for NO2 to NO converter efficiency. The Administrator may 
approve less frequent checks of the converter efficiency. Figure N84-9 
is a reference for paragraphs (a) (1) through (11) of this section.
    (1) Follow good engineering practices for instrument start-up and 
operation. Adjust the analyzer to optimize performance.
    (2) Zero the oxides of nitrogen analyzer with zero-grade nitrogen.
    (3) Connect the outlet of the NOX generator to the 
sample inlet of the oxides of nitrogen analyzer, which has been set to 
the most common operating range.
    (4) Introduce into the NOX generator-analyzer system an 
NO-in-nitrogen (N2) mixture with an NO concentration equal to 
approximately 80 percent of the most common operating range. The NO2 
content of the gas mixture shall be less than 5 percent of the NO 
concentration.
    (5) With the oxides of nitrogen analyzer in the NO mode, record the 
concentration of NO indicated by the analyzer.
    (6) Turn on the NOX generator O2 supply and adjust the 
O2 flow rate so that the NO indicated by the analyzer is about 10 
percent less than indicated in paragraph (a)(5) of this section. Record 
the concentration of NO in this NO + O2 mixture.
    (7) Switch the NOX generator to the generation mode and 
adjust the generation rate so that the NO measured by the analyzer is 
20 percent of that

[[Page 5183]]

measured in paragraph (a)(5) of this section. There must be at least 10 
percent unreacted NO at this point. Record the concentration of 
residual NO.
    (8) Switch the oxides of nitrogen analyzer to the NOX 
mode and measure total NOX. Record this value.
    (9) Switch off the NOX generator but maintain gas flow 
through the system. The oxides of nitrogen analyzer will indicate the 
NOX in the NO + O2 mixture. Record this value.
    (10) Turn off the NOX generator O2 supply. The analyzer 
will now indicate the NOX in the original NO-in-N2 mixture. 
This value should be no more than 5 percent above the value indicated 
in paragraph (a)(4) of this section.
    (11) Calculate the efficiency of the NOX converter by 
substituting the concentrations obtained into the following equation:
[GRAPHIC] [TIFF OMITTED] TR18JA01.019

Where:
a = concentration obtained in paragraph (a)(8) of this section,
b = concentration obtained in paragraph (a)(9) of this section,
c = concentration obtained in paragraph (a)(6) of this section,
d = concentration obtained in paragraph (a)(7) of this section.

    (12) If converter efficiency is not greater than 90 percent, repair 
the analyzer. The repaired analyzer must achieve a converter efficiency 
greater than 90 percent before the analyzer may be used.
    (b) Accuracy. The accuracy at the minimum limit of the 
NOX analyzer is defined in Sec. 86.1338-2007. In general the 
analyzer's minimum limit shall be the lowest concentration within a 
given range, in which it has an accuracy of 2 percent of 
point.
    (c) Initial and periodic calibration. Prior to its introduction 
into service and monthly thereafter, the chemiluminescent oxides of 
nitrogen analyzer shall be calibrated on all normally used instrument 
ranges. Use the same flow rate as when analyzing samples. Proceed as 
follows:
    (1) Adjust analyzer to optimize performance.
    (2) Zero the oxides of nitrogen analyzer with zero-grade nitrogen 
(N2).
    (3) (i) Calibrate all operating ranges with a minimum of 9 NO-in-N2 
calibration gases (e.g., 10, 20, 30, 40, 50, 60, 70, 80, and 90 percent 
of that range) and one zero-grade N2 gas. Sound engineering judgment 
shall dictate appropriate spacing and weighting of the calibration 
points.
    (ii) For each range calibrated, if all deviations from a least-
squares best-fit straight line are within 2 percent of the 
value at each non-zero data point and within 0.3 percent of 
full scale on the zero data point, then concentration values may be 
calculated using the linear calibration equation for that range. If the 
specified deviations are exceeded for ranges that have a minimum limit 
of 1 ppm or greater, then the best-fit non-linear equation that 
represents the data within these deviations may be used to determine 
concentration values. For ranges that have a minimum limit less than 1 
ppm, only a linear or second order non-linear equation that represents 
the data within these deviations, may be used to determine 
concentration values.
    (d) Chemiluminescent NOX analyzer interference check 
(i.e., quench check). Prior to its introduction into service and at 
least once per year thereafter, the quench check described in this 
section shall be performed on CLD NOX analyzers. CO2 and 
water vapor interfere with the response of a CLD by collisional 
quenching. The combined quench effect at their highest expected 
concentrations shall not exceed 2 percent.
    (1) CO2 quench check procedure: (i) For the procedure 
described in this paragraph, variations are acceptable provided that 
they produce equivalent %CO2quench results. Connect a 
pressure-regulated CO2 span gas to one of the inlets of a 
three-way valve. Its CO2 concentration should be approximately twice 
the maximum CO2 concentration expected during testing. The 
valve must be leak-free, and its wetted parts must be made of a 
stainless steel or other inert material. Connect a pressure-regulated 
zero-grade N2 gas to the other inlet of the three-way valve. 
Connect the single outlet of the valve to the balance-gas port of a 
properly operating gas divider. Connect a pressure-regulated NO span 
gas, which has approximately twice the typical NO concentration 
expected during testing, to the span-port of the gas divider. Configure 
the gas divider such that nearly equal amounts of the span gas and 
balance gas are blended with each other. Viscosity corrections shall be 
applied appropriately to ensure correct mass flow determinations.
    (ii) With the CO2 flowing to the balance port and the NO 
flowing to the span port, measure a stable CO2 concentration 
from the gas divider's outlet with a properly calibrated NDIR analyzer. 
Record this concentration in percent (%); this is ``%CO2''. 
This value will be used in the water vapor quench check calculations 
that are detailed in the following section. After the %CO2 
measurement, measure the NO concentration at the gas divider outlet 
with the CLD analyzer in the NO mode. Record this concentration in ppm; 
this is ``NOCO2''. Then switch the three-way valve such that 
100 percent N2 flows to the balance port inlet. Monitor the 
CO2 concentration of the gas divider's outlet until its 
concentration stabilizes at zero. Then measure the stable NO 
concentration from the gas divider's outlet. Record this value in ppm; 
this is ``NON2''. Calculate %CO2quench as 
follows:

%CO2quench = (1.00-(NOCO2/NON2))  x  
100

    (2) Water vapor quench check procedure:
    (i) For all dry CLD analyzers it must be demonstrated that for the 
highest expected water vapor concentration (i.e., 
``%H2Oexp'' as calculated later in this section), 
the water removal technique maintains CLD humidity at less than or 
equal to 5 gwater/kgdry air (or about 0.008 
percent H2O), which is 100% RH at 3.9  deg.C and 101.3 kPa. 
This humidity specification is also equivalent to about 25% RH at 25 
deg.C and 101.3 kPa. This may be demonstrated by measuring the 
temperature at the outlet of a thermal dehumidifier, or by measuring 
humidity at a point just upstream of the CLD. Humidity of the CLD 
exhaust might also be measured as long as the only flow into the CLD is 
the flow out of the dehumidifier.
    (ii) For all ``wet'' CLD analyzers the following water vapor quench 
check procedure shall be followed. Measure an NO span gas, which has 
90% to 100% of the typical NO expected during testing, using the CLD in 
the NO mode. Record this concentration in ppm; this is 
``NOdry''. Then bubble the same NO span gas through 
distilled water in a sealed vessel at 25  deg.C 10  deg.C. 
This temperature specification imposed to ensure that the 
H2Ovol calculation (refer to (iii) of this 
section) returns an accurate result. To prevent subsequent 
condensation, this temperature must also be less than any temperature 
that the wetted sample will experience between the sealed vessel's 
outlet and the CLD. Record the vessel's water temperature in  deg.C; 
this is ``Tsat''. Record the vessel's absolute pressure in 
kPa; this is ``Psat''. Measure the wetted span gas with the 
CLD, and record this value in ppm; this is ``NOwet''.
    (iii) Calculations for water quench must consider dilution of the 
NO span gas with water vapor and scaling of the water vapor 
concentration to that expected during testing.

[[Page 5184]]

    (A) Calculate the volume fraction of water vapor in the wetted span 
gas, as H2Ovol = (exp(3.69-(81.28/
Tsat)) + 1.61)/Psat. This calculation 
approximates some of the thermodynamic properties of water based on the 
``1995 Formulation for the Thermodynamic Properties of Ordinary Water 
Substance for General and Scientific Use'', issued by The International 
Association for the Properties of Water and Steam (IAPWS). However, 
this approximation should only be used as prescribed in this section 
because it is an exponential fit that is accurate for data at 25  deg.C 
10  deg.C. Then, assuming a diesel fuel atomic hydrogen to 
carbon ratio of 1.8, and an intake and dilution air humidity of 75 
grains (10.71 gwater/kgdry air or 54.13 percent 
RH at 25  deg.C and 101.3 kPa),
    (B) Calculate the maximum percent water vapor expected during 
testing; as %H2Oexp = (0.90  x  %CO2) 
+ 1.69. %CO2 is the value measured during the 
%CO2 quench check.
    (C) Calculate the expected wet concentration of NO in ppm; as 
NOexp = NOdry  x  
(1.00-H2Ovol)
    (iv) Calculate the percent water vapor quench as:


%H2Oquench = 
((NOexp-NOwet)/NOexp)  x  
(%H2Oexp/H2Ovol)

    (3) Add the %CO2quench and the 
%H2Oquench values. Their sum may not exceed the 
limit set in paragraph (d). If their sum is greater than this limit, 
then the CLD instrument may not be used to perform testing unless it is 
repaired. The analyzer must be shown to pass this quench check after 
the repair before it may be used for testing.

    35. Section 86.1330-90 is amended by revising paragraph (a) to read 
as follows:


Sec. 86.1330-90  Test sequence; general requirements.

    (a) The test sequence shown in Figure N90-10 shows the major steps 
of the test procedure, as follows:

BILLING CODE 6560-50-P

[[Page 5185]]

[GRAPHIC] [TIFF OMITTED] TR18JA01.020


BILLING CODE 6560-50-C

[[Page 5186]]

* * * * *

    36. Section 86.1334-84 is amended by revising paragraph (a)(1) and 
(a)(2) to read as follows:


Sec. 86.1334-84  Pre-test engine and dynamometer preparation.

    (a) * * * (1) Before the cold soak or cool down:
    (i) Final calibration of the dynamometer and throttle control 
systems may be performed. These calibrations may consist of steady-
state operations and/or actual practice cycle runs, and must be 
completed before sampling system preconditioning (if applicable).
    (ii) Conduct sampling system preconditioning for diesel engines 
(optional for model years prior to 2007) by operating the engine at a 
condition of rated-speed, 100 percent torque for a minimum of 20 
minutes while simultaneously operating the CVS and secondary dilution 
system and taking particulate matter emissions samples from the 
secondary dilution tunnel . Particulate sample filters need not be 
stabilized or weighed, and may be discarded. Filter media may be 
changed during conditioning as long as the total sampled time through 
the filters and sampling system exceeds 20 minutes. Flow rates shall be 
set at the approximate flow rates selected for transient testing. 
Torque shall be reduced from 100 percent torque while maintaining the 
rated speed condition as necessary to prevent exceeding the maximum 
sample zone temperature specifications of Sec. 86.1310-2007.
    (2) Following sampling system preconditioning cycle, the engine 
shall be cooled per Sec. 86.1335-90.
* * * * *

    37. A new section 86.1337-2007 is added to subpart N to read as 
follows:


Sec. 86.1337-2007  Engine dynamometer test run.

    (a) The following steps shall be taken for each test:
    (1) Prepare for the cold-start test.
    (i) For gasoline- and methanol-fueled engines only, evaporative 
emission canisters shall be prepared for use in this testing in 
accordance with the procedures specified in Sec. 86.1232-96 (h) or (j). 
The size of the canisters used for testing shall correspond with the 
largest canister capacity expected in the range of vehicle applications 
for each engine. (The Administrator may, at his/her discretion, use a 
smaller canister capacity.) Attach the evaporative emission canister(s) 
to the engine, using the canister purge plumbing and controls employed 
in vehicle applications of the engine being tested. Plug the canister 
port that is normally connected to the fuel tank.
    (ii) Prepare the engine, dynamometer, and sampling system.
    (iii) Change filters, etc., and leak check as necessary.
    (2) Connect evacuated sample collection bags to the dilute exhaust 
and dilution air sample collection systems if bag sampling is used.
    (3) For methanol-fueled vehicles, install fresh methanol and 
formaldehyde impingers (or cartridges) in the exhaust and dilution air 
sample systems for methanol and formaldehyde. A single dilution air 
sample covering the total test period may be utilized for methanol and 
formaldehyde background. (Background measurements of methanol and 
formaldehyde may be omitted and concentrations assumed to be zero for 
calculations in Sec. 86.1344.)
    (4) Attach the CVS to the engine exhaust system any time prior to 
starting the CVS.
    (5) Start the CVS (if not already on), the sample pumps (except for 
the particulate sample pump(s), if applicable), the engine cooling 
fan(s), and the data collection system. The heat exchanger of the 
constant volume sampler (if used), and the heated components of any 
continuous sampling system(s) (if applicable) shall be preheated to 
their designated operating temperatures before the test begins. (See 
Sec. 86.1340(e) for continuous sampling procedures.)
    (6) Adjust the sample flow rates to the desired flow rates and set 
the CVS gas flow measuring devices to zero. CFV-CVS sample flow rate is 
fixed by the venturi design.
    (7) For engines tested for particulate emissions, carefully install 
a clean, loaded particulate sample filter cartridge into the filter 
holder assembly. It is recommended that this be done within the filter 
stabilization environment, with both ends of the filter holder assembly 
plugged during transport to the emissions test facility. Install the 
assembled filter holder into the sample flow line.
    (8) Follow the manufacturer's instructions for cold starting. 
Simultaneously start the engine and begin exhaust and dilution air 
sampling. For petroleum-fueled diesel engines (and natural gas-fueled, 
liquified petroleum gas-fueled or methanol-fueled diesels, if used) 
Turn on the hydrocarbon and NOX (and CO and CO2, 
if continuous) analyzer system integrators (if used), and turn on the 
particulate sample pumps and indicate the start of the test on the data 
collection medium.
    (9) Allow the engine to idle freely with no-load for 
241 seconds. This idle period for automatic transmission 
engines may be interpreted as an idle speed in neutral or park. All 
other idle conditions shall be interpreted as an idle speed in gear. It 
is permissible to lug the engine down to curb idle speed during the 
last 8 seconds of the free idle period for the purpose of engaging 
dynamometer control loops.
    (10) Begin the transient engine cycles such that the first non-idle 
record of the cycle occurs at 251 seconds. The free idle 
time is included in the 251 seconds.
    (i) During particulate sampling it must be demonstrated that the 
ratio of main tunnel flow to particulate sample flow does not change by 
more than 5.0 percent of its set point value (except for 
the first 10 seconds of sampling). For double dilution operation, 
sample flow is the net difference between the flow rate through the 
sample filters and the secondary dilution air flow rate.
    (ii) Record flow. If the set flow rate cannot be maintained because 
of high particulate loading on the filter, the test shall be 
terminated. The test shall be rerun using a lower sample flow rate or 
greater dilution.
    (11) Begin the transient engine cycles such that the first non-idle 
record of the cycle occurs at 251 seconds. The free idle 
time is included in the 251 seconds.
    (12) On the last record of the cycle, cease sampling. Immediately 
turn the engine off and start a hot-soak timer. Also turn off the 
particulate sample pumps, the gas flow measuring device(s) and any 
continuous analyzer system integrator and indicate the end of the test 
on the data collection medium. Sampling systems should continue to 
sample after the end of the test cycle until system response times have 
elapsed.
    (13) Immediately after the engine is turned off, turn off the 
engine cooling fan(s) if used. As soon as possible, transfer the ``cold 
start cycle'' exhaust and dilution air bag samples to the analytical 
system and process the samples according to Sec. 86.1340. A stabilized 
reading of the exhaust sample on all analyzers shall be obtained within 
20 minutes of the end of the sample collection phase of the test. 
Analysis of the methanol and formaldehyde samples shall be obtained 
within 24 hours of the end of the sample collection period. For 
particulate measurements, carefully remove the filter holder from the 
sample flow apparatus
    (14) Allow the engine to soak for 201 minutes.

[[Page 5187]]

    (15) Prepare the engine and dynamometer for the hot start test.
    (16) Connect evacuated sample collection bags to the dilute exhaust 
and dilution air sample collection systems.
    (17) Install fresh methanol and formaldehyde impingers (or 
capsules) in the exhaust and dilution air sample systems for methanol 
and formaldehyde.
    (18) Start the sample pumps (except the particulate sample pump(s), 
if applicable), the engine cooling fan(s) and the data collection 
system. The heat exchanger of the constant volume sampler (if used) and 
the heated components of any continuous sampling system(s) (if 
applicable) shall be preheated to their designated operating 
temperatures before the test begins. See Sec. 86.1340(e) for continuous 
sampling procedures.
    (19) Adjust the sample flow rates to the desired flow rate and set 
the CVS gas flow measuring devices to zero.
    (20) For diesel engines tested for particulate, carefully install a 
clean, loaded particulate sample filter cartridge in the filter holder 
assembly and install the filter holder assembly in the sample flow 
line.
    (21) Follow the manufacturer's choke and throttle instruction for 
hot starting. Simultaneously start the engine and begin exhaust and 
dilution air sampling. For diesel engines, turn on the hydrocarbon and 
NOX (and CO and CO2, if continuous) analyzer system 
integrator (if used), indicate the start of the test on the data 
collection medium, and turn on the particulate sample pump(s).
    (22) [Reserved]
    (23) Allow the engine to idle freely with no-load for 
241 seconds. The provisions and interpretations of 
paragraph (a)(9) of this section apply.
    (24) Begin the transient-engine cycle such that the first non-idle 
record of the cycle occurs at 251 seconds. The free idle is 
included in the 251 seconds.
    (25) On the last record of the cycle, allow sampling system 
response times to elapse and cease sampling. Turn off the particulate 
sample pump(s) (if appropriate), the gas flow measuring device(s) and 
any continuous analyzer system integrator and indicate the end of the 
test on the data collection medium.
    (26) As soon as possible, transfer the ``hot start cycle'' exhaust 
and dilution air bag samples to the analytical system and process the 
samples according to Sec. 86.1340. A stabilized reading of the exhaust 
sample on all analyzers shall be obtained within 20 minutes of the end 
of the sample collection phase of the test. Analyze the methanol and 
formaldehyde samples within 24 hours. (If it is not possible to perform 
analysis within 24 hours, the samples should be stored in a cold 
(approximately 0 deg.C) dark environment until analysis can be 
performed). For particulate measurements, carefully remove the filter 
holder assembly. It is recommended that the filter cartridge be 
transferred to and from the filter stabilization environment within the 
filter holder assembly with both ends plugged, and that the cartridge 
be removed from the filter holder assembly within the stabilization 
environment. Transfer the particulate filter to the stabilization 
environment for post-test stabilization. Filters may be stabilized in 
the petri dishes while still within the filter cartridges, or the 
cartridge tops may be removed for stabilization, or the filters may be 
entirely removed from the filter cartridges and stabilized in the petri 
dishes alone. Removal of the filters from the filter cartridges shall 
only take place within the stabilization environment.
    (27) The CVS and the engine may be turned off, if desired.
    (b) The procedure in paragraph (a) of this section is designed for 
one sample bag for the cold start portion and one for the hot start 
portion.
    (c) If a dynamometer test run is determined to be void, corrective 
action may be taken. The engine may then be allowed to cool (naturally 
or forced) and the dynamometer test rerun.

    38. A new section 86.1338-2007 is added to Subpart N to read as 
follows:


Sec. 86.1338-2007  Emission measurement accuracy.

    (a) Minimum limit. (1) The minimum limit of an analyzer must be 
equal to or less than one-half of the average diluted concentration for 
an engine emitting the maximum amount of the applicable pollutant 
allowed by the applicable standard. For example, if with a given 
dilution and sampling system, an engine emitting NOX at the 
level of the standard (e.g., 0.20 g/bhp-hr NOX) would result 
in an average NOX concentration of 1.0 ppm in the diluted 
sample, then the minimum limit for the NOX analyzer must be 
less than or equal to 0.5 ppm.
    (2) For the purpose of this section, ``minimum limit'' means the 
lowest of the following levels:
    (i) The lowest NOX concentration in the calibration 
curve for which an accuracy of 2 percent of point has been 
demonstrated as specified in paragraph (a)(3) of this section; or
    (ii) Any NOX concentration for which the test facility 
has demonstrated sufficient accuracy to the Administrator's 
satisfaction prior to the start of testing, such that it will allow a 
meaningful determination of compliance with respect to the applicable 
standard.
    (3) For determination of the analyzer's minimum limit, a 
NOX concentration that is less than or equal to one-half of 
the average NOX concentration determined in paragraph (a)(1) 
of this section shall be measured by the oxides of nitrogen analyzer 
following the analyzer's monthly periodic calibration. This measurement 
must be made to ensure the accuracy of the calibration curve to within 
2 percent of point accuracy of the appropriate least-
squares fit, at less than or equal to one half of the average expected 
diluted NOX concentration determined in paragraph (a)(1) of 
this section.
    (b) Measurement accuracy--Bag sampling. Analyzers used for bag 
analysis must be operated such that the measured concentration falls 
between 15 and 100 percent of full scale, with the following exception: 
concentrations below 15 percent of full scale may be used if the 
minimum limit of the analyzer within the range meets the requirement of 
paragraph (a) of this section.
    (c) Measurement accuracy--Continuous measurement. (1) Analyzers 
used for continuous analysis must be operated such that the measured 
concentration falls between 15 and 100 percent of full scale, with the 
following exceptions:
    (i) Concentrations below 15 percent of full scale may be used if 
the minimum limit of the analyzer within the range meets the 
requirement of paragraph (a) of this section.
    (ii) Analyzer response over 100% of full scale may be used if it 
can be shown that readings in this range are accurate.
    (2) If the analyzer response exceeds the level allowed by paragraph 
(c)(1)(ii) of this section, the test must be repeated using a higher 
range and both results must be reported. The Administrator may waive 
this requirement.
    (d) If a gas divider is used, the gas divider shall conform to the 
accuracy requirements specified in Sec. 86.1314-84(g), and shall be 
used according to the procedures contained in paragraphs (a) and (b) of 
this section.

    39. Section 86.1339-90 is amended by adding paragraph (h) to read 
as follows:


Sec. 86.1339-90  Particulate filter handling and weighing.

* * * * *
    (h) This section does not apply for tests conducted according to 
the provisions of Sec. 86.1312-2007.

[[Page 5188]]


    40. Section 86.1360-2007 is amended by revising the section 
heading, adding introductory text, and revising paragraphs (b), (e)(2), 
(e)(3), and (e)(6)(ii), to read as follows:


Sec. 86.1360-2007  Supplemental emission test; test cycle and 
procedures.

    The test procedures of this subpart N apply for supplemental 
emission testing, except as specified otherwise in this section.
* * * * *
    (b) Test cycle. (1)(i) The following 13-mode cycle must be followed 
in dynamometer operation on the test engine:

----------------------------------------------------------------------------------------------------------------
                                                                                     Weighting      Mode length
             Mode number                     Engine speed          Percent load       factor         (minutes)
----------------------------------------------------------------------------------------------------------------
1...................................  Idle                        ..............            0.15               4
2...................................  A                                      100            0.08               2
3...................................  B                                       50            0.10               2
4...................................  B                                       75            0.10               2
5...................................  A                                       50            0.05               2
6...................................  A                                       75            0.05               2
7...................................  A                                       25            0.05               2
8...................................  B                                      100            0.09               2
9...................................  B                                       25            0.10               2
10..................................  C                                      100            0.08               2
11..................................  C                                       25            0.05               2
12..................................  C                                       75            0.05               2
13..................................  C                                       50            0.05               2
----------------------------------------------------------------------------------------------------------------

    (ii) Upon Administrator approval, the manufacturer may use mode 
lengths other than those listed in paragraph (b)(1)(i) of this section.
    (2) In addition to the 13 test points identified in paragraph 
(b)(1) of this section, for engines not certified to a NOX 
standard or FEL less than1.5 g/bhp-hr, EPA may select, and require the 
manufacturer to conduct the test using, up to 3 additional test points 
within the control area (as defined in paragraph (d) of this section). 
EPA will notify the manufacturer of these supplemental test points in 
writing in a timely manner before the test. Emissions sampling for the 
additional test modes must include all regulated gaseous pollutants. 
Particulate matter does not need to be measured.
* * * * *
    (e) * * *
    (2) Test sequence. The test must be performed in the order of the 
mode numbers in paragraph (b)(1) of this section. Where applicable, the 
EPA-selected test points identified under paragraph (b)(2) of this 
section must be performed immediately upon completion of mode 13. The 
engine must be operated for the prescribed time in each mode, 
completing engine speed and load changes in the first 20 seconds of 
each mode. The specified speed must be held to within 50 
rpm and the specified torque must be held to within plus or minus two 
percent of the maximum torque at the test speed.
    (3) Particulate sampling. One filter shall be used for sampling PM 
over the 13-mode test procedure. The modal weighting factors specified 
in paragraph (b)(1) of this section shall be taken into account by 
taking a sample proportional to the exhaust mass flow during each 
individual mode of the cycle. This can be achieved by adjusting sample 
flow rate, sampling time, and/or dilution ratio, accordingly, so that 
the criterion for the effective weighting factors is met. The sampling 
time per mode must be at least 4 seconds per 0.01 weighting factor. 
Sampling must be conducted as late as possible within each mode. 
Particulate sampling shall be completed no earlier than 5 seconds 
before the end of each mode.
* * * * *
    (6) * * *
    (ii) For PM measurements, a single filter must be used to measure 
PM over the 13 modes. The brake-specific PM emission level for the test 
must be calculated as described for a transient hot start test in 
Sec. 86.1343. Only the power measured during the sampling period shall 
be used in the calculation.
* * * * *

    41. Section 86.1370-2007 is amended by revising paragraphs (a), 
(b)(6) and (d), removing and reserving paragraph (b)(5), and adding 
paragraphs (b)(7) and (g) to read as follows:


Sec. 86.1370-2007  Not-To-Exceed test procedures.

    (a) General. The purpose of this test procedure is to measure in-
use emissions of heavy-duty diesel engines while operating within a 
broad range of speed and load points (the Not-To-Exceed Control Area) 
and under conditions which can reasonably be expected to be encountered 
in normal vehicle operation and use. Emission results from this test 
procedure are to be compared to the Not-To-Exceed Limits specified in 
Sec. 86.007-11 (a)(4), or to later Not-To-Exceed limits. The Not-To-
Exceed Limits do not apply for engine starting conditions.
    (b) * * *
    (5) [Reserved]
    (6)(i) For petroleum-fueled diesel cycle engines, the manufacturer 
may identify particular engine-vehicle combinations and may petition 
the Administrator at certification to exclude operating points from the 
Not-to-Exceed Control Area defined in Sec. 86.1370(b)(1) through (5) if 
the manufacturer can demonstrate that the engine is not capable of 
operating at such points when used in the specified engine-vehicle 
combination(s).
    (ii) For diesel cycle engines that are not petroleum-fueled, the 
manufacturer may petition the Administrator at certification to exclude 
operating points from the Not-to-Exceed Control Area defined in 
Sec. 86.1370(b)(1) through (5) if the manufacturer can demonstrate that 
the engine is not expected to operate at such points in normal vehicle 
operation and use.
    (7) Manufacturers may petition the Administrator to limit NTE 
testing in a single defined region of speeds and loads. Such a defined 
region must generally be of elliptical or rectangular shape, and must 
share some portion of its boundary with the outside limits of the NTE 
zone. Under this provision testing would not be allowed with sampling 
periods in which operation within that region constitutes more than 5.0 
percent of the time-weighted operation within the sampling period. 
Approval of this limit by the Administrator is contingent on the 
manufacturer satisfactorily demonstrating that operation at the

[[Page 5189]]

speeds and loads within that region accounts for less than 5.0 percent 
of all in-use operation (weighted by vehicle-miles-traveled or other 
EPA-approved weightings) for the in-use engines of that configuration 
(or sufficiently similar engines). At a minimum, this demonstration 
must include operational data from representative in-use vehicles.
* * * * *
    (d) Not-to-exceed control area limits. (1) When operated within the 
Not-To-Exceed Control Area defined in paragraph (b) of this section, 
diesel engine emissions shall not exceed the applicable Not-To-Exceed 
Limits specified in Sec. 86.007-11(a)(4) when averaged over any period 
of time greater than or equal to 30 seconds, except where a longer 
averaging period is required by paragraph (d)(2) of this section.
    (2) For engines equipped with emission controls that include 
discrete regeneration events, if a regeneration event occurs during the 
NTE test, then the averaging period must be at least as long as the 
time between the events multiplied by the number of full regeneration 
events within the sampling period. The requirement in this paragraph 
(d)(2) only applies for engines that send an electronic signal 
indicating the start of the regeneration event.
* * * * *
    (g) NOX and NMHC aftertreatment warm-up. For engines 
equipped with one or more aftertreatment devices that reduce 
NOX or NMHC emissions, the NTE NOX and NMHC 
emission limits do not apply when the exhaust gas temperature is 
measured within 12 inches of the outlet of the aftertreatment device 
and is less the 250 deg.C. For multi-bed systems, it is the temperature 
at the outlet of the device with the maximum flow rate that determines 
whether the NTE limits apply.

    42. Sec. 86.1803-01 is amended by adding a definition of ``U.S. 
heavy-duty vehicle sales'' in alphabetical order to read as follows:


Sec. 86.1803-01  Definitions.

* * * * *
    U.S. heavy-duty vehicle sales means sales of heavy-duty vehicles 
subject to the standards of this subpart, where the sale takes place in 
any state of the United States except for California (or a state that 
has adopted California motor vehicle standards for that model year 
pursuant to section 177 of the Clean Air Act).
* * * * *
    43. Sec. 86.1806-05 is amended by revising paragraphs (b) 
introductory text, (b)(1), and (l) to read as follows:


Sec. 86.1806-05  On-board diagnostics.

* * * * *
    (b) Malfunction descriptions. The OBD system must detect and 
identify malfunctions in all monitored emission-related powertrain 
systems or components according to the following malfunction 
definitions as measured and calculated in accordance with test 
procedures set forth in subpart B of this part (chassis-based test 
procedures), excluding those test procedures defined as 
``Supplemental'' test procedures in Sec. 86.004-2 and codified in 
Secs. 86.158, 86.159, and 86.160.
    (1) Catalysts and particulate traps. (i) Otto-cycle. Catalyst 
deterioration or malfunction before it results in an increase in NMHC 
emissions 1.5 times the NMHC standard or FEL, as compared to the NMHC 
emission level measured using a representative 4000 mile catalyst 
system.
    (ii) Diesel. (A) If equipped, catalyst deterioration or malfunction 
before it results in exhaust emissions exceeding 1.5 times the 
applicable standard or FEL for NOX or PM. This requirement 
applies only to reduction catalysts; monitoring of oxidation catalysts 
is not required. This monitoring need not be done if the manufacturer 
can demonstrate that deterioration or malfunction of the system will 
not result in exceedance of the threshold.
    (B) If equipped with a particulate trap, catastrophic failure of 
the device must be detected. Any particulate trap whose complete 
failure results in exhaust emissions exceeding 1.5 times the applicable 
standard or FEL for NOX or PM must be monitored for such 
catastrophic failure. This monitoring need not be done if the 
manufacturer can demonstrate that a catastrophic failure of the system 
will not result in exceedance of the threshold.
* * * * *
    (l) Phase-in for complete heavy-duty vehicles. Complete heavy-duty 
vehicles weighing 14,000 pounds GVWR or less that are not Otto-cycle 
MDPVs must meet the OBD requirements of this section according to the 
following phase-in schedule, based on the percentage of projected 
vehicle sales. The 2004 model year requirements in the following phase-
in schedule are applicable only to heavy-duty Otto-cycle vehicles where 
the manufacturer has selected Otto-cycle Option 1 or 2 for alternative 
2003 or 2004 compliance according to Sec. 86.004-01(c)(1) or (2). The 
2005 through 2007 requirements in the following phase-in schedule apply 
to all heavy-duty vehicles weighing 14,000 pounds GVWR or less, 
excluding MDPVs. If the manufacturer has selected Otto-cycle Option 3 
it may exempt 2005 model year complete heavy-duty engines and vehicles 
whose model year commences before July 31, 2004 from the requirements 
of this section. For the purposes of calculating compliance with the 
phase-in provisions of this paragraph (l), heavy-duty vehicles subject 
to the phase-in requirements of this section may be combined with 
heavy-duty vehicles subject to the phase-in requirements of paragraph 
Sec. 86.005-17 (k). The phase-in schedule follows:

OBD Compliance Phase-in for Complete Heavy-Duty Vehicles Weighing 14,000
                           Pounds GVWR or Less
------------------------------------------------------------------------
          Model year                Phase-in based on projected sales
------------------------------------------------------------------------
2004 MY                         Applicable only to Otto-cycle engines
                                 complying with Options 1 or 2; 40%
                                 compliance; alternative fuel waivers
                                 available.
2005 MY                         60% compliance; alternative fuel waivers
                                 available.
2006 MY                         80% compliance; alternative fuel waivers
                                 available.
2007 MY                         80% compliance; alternative fuel waivers
                                 available.
2008+ MY                        100% compliance.
------------------------------------------------------------------------


    44. A new Sec. 86.1807-07 is added to subpart S to read as follows:

[[Page 5190]]

Sec. 86.1807-07  Vehicle labeling.

    Section 86.1807-07 includes text that specifies requirements that 
differ from those specified in Sec. 86.1807-01. Where a paragraph in 
Sec. 86.1807-01 is identical and applicable to Sec. 86.1807-07, this 
may be indicated by specifying the corresponding paragraph and the 
statement ``[Reserved]. For guidance see Sec. 86.1807-01.''.
    (a) through (g) [Reserved]. For guidance see Sec. 86.1807-01.
    (h) Model year 2007 and later diesel-fueled Tier 2 vehicles 
(certified using a test fuel with 15 ppm sulfur or less), must include 
permanent readily visible labels on the dashboard (or instrument panel) 
and near all fuel inlets that state ``Use Low-sulfur Diesel Fuel Only'' 
or ``Low-sulfur Diesel Fuel Only''.

    45. A new Sec. 86.1808-07 is added to subpart S to read as follows:


Sec. 86.1808-07  Maintenance instructions.

    Section 86.1808-07 includes text that specifies requirements that 
differ from those specified in Sec. 86.1808-01. Where a paragraph in 
Sec. 86.1808-01 is identical and applicable to Sec. 86.1808-07, this 
may be indicated by specifying the corresponding paragraph and the 
statement ``[Reserved]. For guidance see Sec. 86.1808-01.''.
    (a) through (f) [Reserved]. For guidance see Sec. 86.1808-01.
    (g) For each new diesel-fueled Tier 2 vehicle (certified using a 
test fuel with 15 ppm sulfur or less), the manufacturer shall furnish 
or cause to be furnished to the purchaser a statement that ``This 
vehicle must be operated only with low sulfur diesel fuel (that is., 
diesel fuel meeting EPA specifications for highway diesel fuel, 
including a 15 ppm sulfur cap).''.

    46. Section 86.1810-01 is amended by revising the introductory text 
to read as follows:


Sec. 86.1810-01  General standards; increase in emissions; unsafe 
conditions; waivers.

    This section applies to model year 2001 and later light-duty 
vehicles and light-duty trucks fueled by gasoline, diesel, methanol, 
natural gas and liquefied petroleum gas fuels. This section also 
applies to MDPVs and complete heavy-duty vehicles certified according 
to the provisions of this subpart. Multi-fueled vehicles (including 
dual-fueled and flexible-fueled vehicles) shall comply with all 
requirements established for each consumed fuel (or blend of fuels in 
the case of flexible fueled vehicles). The standards of this subpart 
apply to both certification and in-use vehicles unless otherwise 
indicated. For Tier 2 and interim non-Tier 2 vehicles, this section 
also applies to hybrid electric vehicles and zero emission vehicles. 
Unless otherwise specified, requirements and provisions of this subpart 
applicable to methanol fueled vehicles are also applicable to Tier 2 
and interim non-Tier 2 ethanol fueled vehicles.
* * * * *

    47. Section 86.1816-05 is amended by revising paragraph (g) to read 
as follows:


Sec. 86.1816-05  Emission standards for complete heavy-duty vehicles.

* * * * *
    (g) Idle exhaust emission standards, complete heavy-duty vehicles. 
Exhaust emissions of carbon monoxide from 2005 and later model year 
gasoline, methanol, natural gas-and liquefied petroleum gas-fueled 
complete heavy-duty vehicles shall not exceed 0.50 percent of exhaust 
gas flow at curb idle for a useful life of 11 years or 120,000 miles, 
whichever occurs first. This does not apply for vehicles certified to 
the requirements of Sec. 86.1806-05
* * * * *

    48. A new Sec. 86.1816-08 is added to subpart S, to read as 
follows:


Sec. 86.1816-08  Emission standards for complete heavy-duty vehicles.

    Section 86.1816-08 includes text that specifies requirements that 
differ from those specified in Sec. 86.1816-05. Where a paragraph in 
Sec. 86.1816-05 is identical and applicable to Sec. 86.1816-08, this 
may be indicated by specifying the corresponding paragraph and the 
statement ``[Reserved]. For guidance see Sec. 86.1816-05.''. This 
section applies to 2008 and later model year complete heavy-duty 
vehicles (excluding MDPVs) fueled by gasoline, methanol, natural gas 
and liquefied petroleum gas fuels except as noted. Multi-fueled 
vehicles shall comply with all requirements established for each 
consumed fuel. For methanol fueled vehicles, references in this section 
to hydrocarbons or total hydrocarbons shall mean total hydrocarbon 
equivalents and references to non-methane hydrocarbons shall mean non-
methane hydrocarbon equivalents.
    (a) Exhaust emission standards. (1) Exhaust emissions from 2008 and 
later model year complete heavy-duty vehicles at and above 8,500 pounds 
Gross Vehicle Weight Rating but equal to or less than 10,000 Gross 
Vehicle Weight Rating pounds shall not exceed the following standards 
at full useful life:
    (i) [Reserved]
    (ii) Non-methane hydrocarbons. (A) 0.195 grams per mile; this 
requirement may be satisfied by measurement of non-methane organic gas 
or total hydrocarbons, at the manufacturer's option. For alcohol-fueled 
vehicles, this standard is 0.195 grams per mile NMHCE.
    (B) A manufacturer may elect to include any or all of its test 
groups in the NMHC emissions ABT programs for heavy-duty vehicles, 
within the restrictions described in Sec. 86.1817-05. or Sec. 86.1817-
08. If the manufacturer elects to include test groups in any of these 
programs, the NMHC FEL may not exceed 0.28 grams per mile. This ceiling 
value applies whether credits for the family are derived from 
averaging, banking, or trading.
    (iii) Carbon monoxide. 7.3 grams per mile.
    (iv) Oxides of nitrogen. (A)0.2 grams per mile.
    (B) A manufacturer may elect to include any or all of its test 
groups in the NOX emissions ABT programs for heavy-duty 
vehicles, within the restrictions described in Sec. 86.1817-05 or 
Sec. 86.1817-08. If the manufacturer elects to include test groups in 
any of these programs, the NOX FEL may not exceed 0.9 grams 
per mile. This ceiling value applies whether credits for the family are 
derived from averaging, banking, or trading.
    (v) Particulate. 0.02 grams per mile.
    (vi) Formaldehyde. 0.032 grams per mile.
    (2) Exhaust emissions from 2008 and later model year complete 
heavy-duty vehicles above 10,000 pounds Gross Vehicle Weight Rating but 
less than 14,000 pounds Gross Vehicle Weight Rating shall not exceed 
the following standards at full useful life:
    (i) [Reserved]
    (ii) Non-methane hydrocarbons. (A) 0.230 grams per mile; this 
requirement may be satisfied by measurement of non-methane organic gas 
or total hydrocarbons, at the manufacturer's option. For alcohol-fueled 
vehicles, this standard is 0.230 grams per mile NMHCE.
    (B) A manufacturer may elect to include any or all of its test 
groups in the NMHC emissions ABT programs for heavy-duty vehicles, 
within the restrictions described in Sec. 86.1817-05. or Sec. 86.1817-
08. If the manufacturer elects to include test groups in any of these 
programs, the NMHC FEL may not exceed 0.33 grams per mile. This ceiling 
value applies whether credits for the family are derived from 
averaging, banking, or trading.

[[Page 5191]]

    (iii) Carbon monoxide. 8.1 grams per mile.
    (iv) Oxides of nitrogen. (A)0.4 grams per mile.
    (B) A manufacturer may elect to include any or all of its test 
groups in the NOX emissions ABT programs for heavy-duty 
vehicles, within the restrictions described in Sec. 86.1817-05. or 
Sec. 86.1817-08. If the manufacturer elects to include test groups in 
any of these programs, the NOX FEL may not exceed 1.0 grams 
per mile. This ceiling value applies whether credits for the family are 
derived from averaging, banking, or trading.
    (v) Particulate. 0.02 grams per mile.
    (vi) Formaldehyde. 0.040 grams per mile.
    (b) [Reserved]
    (c) [Reserved]
    (d) Evaporative emissions. Evaporative hydrocarbon emissions from 
gasoline-fueled, natural gas-fueled, liquefied petroleum gas-fueled, 
and methanol-fueled complete heavy-duty vehicles shall not exceed the 
following standards. The standards apply equally to certification and 
in-use vehicles. The spitback standard also applies to newly assembled 
vehicles.
    (1) For the full three-diurnal test sequence, diurnal plus hot soak 
measurements: 1.4 grams per test.
    (2) Gasoline and methanol fuel only. For the supplemental two-
diurnal test sequence, diurnal plus hot soak measurements: 1.75 grams 
per test.
    (3) Gasoline and methanol fuel only. Running loss test: 0.05 grams 
per mile.
    (4) Gasoline and methanol fuel only. Fuel dispensing spitback test: 
1.0 grams per test.
    (e) through (h) [Reserved]. For guidance see Sec. 86.1816-05.
    (i) Phase-in options. (1)(i) For model year 2008, manufacturers may 
certify some of their test groups to the standards applicable to model 
year 2008 vehicles under Sec. 86.1816-05, in lieu of the exhaust 
standards specified in this section. These vehicles must comply with 
all other requirements applicable to model year 2007 vehicles. The 
combined number of vehicles in the test groups certified to the 2008 
standards may not exceed 50 percent of the manufacturer's U.S. heavy-
duty vehicle sales of complete heavy-duty Otto-cycle motor vehicles for 
model year 2008, except as explicitly allowed by paragraph (i)(2) of 
this section.
    (ii) For model year 2008, manufacturers may certify some of their 
test groups to the evaporative standards applicable to model year 2007 
engines under Sec. 86.1816-05, in lieu of the evaporative standards 
specified in this section. These vehicles must comply with all other 
requirements applicable to model year 2008 vehicles, except as allowed 
by paragraph (i)(1)(i) of this section. The combined number of vehicles 
in the test groups certified to the 2007 standards may not exceed 50 
percent of the manufacturer's U.S. heavy-duty vehicle sales of complete 
heavy-duty Otto-cycle motor vehicles for model year 2008.
    (2)(i) Manufacturers certifying vehicles to all of the applicable 
standards listed in paragraph (a) of this section prior to model year 
2008 (without using credits) may reduce the number of vehicles that are 
required to meet the standards listed in paragraph (a) of this section 
in model year 2008 and/or 2009, taking into account the phase-in option 
provided in paragraph (i)(1) of this section. For every vehicle that is 
certified early, the manufacturer may reduce the number of vehicles 
that are required by paragraph (i)(1) of this section to meet the 
standards listed in paragraph (a) of this section by one vehicle. For 
example, if a manufacturer produces 100 heavy-duty Otto-cycle vehicles 
in 2007 that meet all of the applicable the standards listed in 
paragraph (a) of this section, and it produced 10,000 heavy-duty Otto-
cycle vehicles in 2009, then only 9,900 of the vehicles would need to 
comply with the standards listed in paragraph (a) of this section.
    (ii) Manufacturers certifying vehicles to all of the applicable 
evaporative standards listed in paragraph (d) of this section prior to 
model year 2008 may reduce the number of vehicles that are required to 
meet the standards listed in paragraph (d) of this section in model 
year 2008 and/or 2009, taking into account the phase-in option provided 
in paragraph (i)(1) of this section. For every vehicle that is 
certified early, the manufacturer may reduce the number of vehicles 
that are required by paragraph (i)(1) of this section to meet the 
evaporative standards listed in paragraph (d) of this section by one 
vehicle.
    (3) Manufacturers certifying vehicles to all of the applicable 
standards listed in paragraph (i)(3)(i) or (ii) of this section 
(without using credits) and the evaporative standards listed in 
paragraph (d) of this section prior to model year 2008 may reduce the 
number of vehicles that are required to meet the standards listed in 
paragraph (a) of this section in model year 2008 and/or 2009, taking 
into account the phase-in option provided in paragraph (i)(1)(i) of 
this section. For every such vehicle that is certified early with 
sufficiently low emissions, the manufacturer may reduce the number of 
vehicles that are required by paragraph (i)(1)(i) of this section to 
meet the standards listed in paragraph (a) of this section by two 
vehicles. The applicable standards are:
    (i) For complete heavy-duty vehicles at and above 8,500 pounds 
Gross Vehicle Weight Rating but equal to or less than 10,000 Gross 
Vehicle Weight Rating: 0.100 g/mile NMHC, 0.10 g/mile NOX, 
3.2 g/mile CO, 0.008 g/mile formaldehyde, and 0.02 g/mile PM.
    (ii) For complete heavy-duty vehicles at or above 10,000 pounds 
Gross Vehicle Weight Rating but equal to or less than 14,000 Gross 
Vehicle Weight Rating: 0.117 g/mile NMHC, 0.20 g/mile NOX, 
3.7 g/mile CO, 0.010 g/mile formaldehyde, and 0.02 g/mile PM.
    (j) (1) For model years prior to 2012, for purposes of determining 
compliance after title or custody has transferred to the ultimate 
purchaser, for vehicles meeting the applicable emission standards of 
this section, the applicable compliance limits shall be determined by 
adding the applicable adjustment from paragraph (j)(2) of this section 
to the otherwise applicable standard or FEL.

[[Page 5192]]

    (2) The in-use adjustments are:
    (i) 0.1 g/bhp-hr for NOX.
    (ii) 0.100 g/bhp-hr NMHC.
    (iii) 0.01 g/bhp-hr for PM.

    49. A new Sec. 86.1817-08 is added to Subpart S to read as follows:


Sec. 86.1817-08  Complete heavy-duty vehicle averaging, trading, and 
banking program.

    Section 86.1817-08 includes text that specifies requirements that 
differ from Sec. 86.1817-05. Where a paragraph in Sec. 86.1817-05 is 
identical and applicable to Sec. 86.1817-08, this may be indicated by 
specifying the corresponding paragraph and the statement ``[Reserved]. 
For guidance see Sec. 86.1817-05.''
    (a) through (o) [Reserved]. For guidance see Sec. 86.1817-05.
    (p) The following provisions apply for model year 2008 and later 
engines. These provisions apply instead of the provisions of paragraphs 
Sec. 86.1817-05 (a) through (o) to the extent that they are in 
conflict.
    (1) Manufacturers of Otto-cycle vehicles may participate in an NMHC 
averaging, banking and trading program to show compliance with the 
standards specified in Sec. 86.1806-08. The generation and use of NMHC 
credits are subject to the same provisions in paragraphs Sec. 86.1817-
05 (a) through (o) that apply for NOX credits, except as 
otherwise specified in this section.
    (2) NOX or NMHC (or NOX plus NMHC) credits 
may be exchanged between heavy-duty Otto-cycle test groups certified to 
the engine standards of subpart A of this part and heavy-duty Otto-
cycle test groups certified to the chassis standards of this subpart, 
subject to an 0.8 discount factor (e.g., 100 grams of NOX 
credits generated from vehicles would be equivalent to 80 grams of 
NOX credits if they are used in the engine program of 
subpart A of this part, and vice versa). Credits that were previously 
discounted when they were banked according to Sec. 86.1817-05(c), are 
subject to an additional discount factor of 0.888 instead of the 0.8 
discount factor otherwise required by this paragraph (p)(2). This 
results in a total discount of 0.8 (0.9  x  0.888 = 0.8).
    (3) Credits are to be rounded to the nearest one-hundredth of a 
Megagram.
    (4) To calculate credits relative to the NOX standards 
listed in Sec. 86.1816-08 (a)(1)(iv)(A) or (a)(2)(iv)(A) (0.2 or 0.4 
grams per mile, respectively) express the standard and FEL to the 
nearest one-hundredth of a gram per mile prior to calculating the 
credits. Thus, either 0.20 or 0.40 should be used as the value for 
``Std''.
    (5) Credits generated for 2008 and later model year test groups are 
not discounted (except as specified in Sec. 86.1817-05(c) and paragraph 
(p)(2) of this section), and do not expire.
    (6) For the purpose of using or generating credits during a phase-
in of new standards, a manufacturer may elect to split an test group 
into two subgroups: one which uses credits and one which generates 
credits. The manufacturer must indicate in the application for 
certification that the test group is to be split, and may assign the 
numbers and configurations of vehicles within the respective 
subfamilies at any time prior to the submission of the end-of-year 
report described in Sec. 86.1817-05 (i)(3). Manufacturers certifying a 
split test group may label all of the vehicles within that test group 
with the same FELs: either with a NOX FEL and an NMHC FEL, 
or with a single NOX+NMHC FEL. The FEL(s) on the label will 
apply for all SEA or other compliance testing.
    (7) Vehicles meeting all of the applicable standards of 
Sec. 86.1816-08 prior to model year 2008 may generate NMHC credits for 
use by 2008 or later test groups. Credits are calculated according to 
Sec. 86.1817-05(c), except that the applicable FEL cap listed in 
Sec. 86.1816-08(a)(1)(ii)(B) or (2)(ii)(B) applies instead of ``Std'' 
(the applicable standard).

    50. A new Sec. 86.1824-07 is added to subpart S, to read as 
follows:

[[Page 5193]]

Sec. 86.1824-07  Durability demonstration procedures for evaporative 
emissions.

    Sec. 86.1824-07 includes text that specifies requirements that 
differ from those specified in Sec. 86.1824-01. Where a paragraph in 
Sec. 86.1824-01 is identical and applicable to Sec. 86.1824-07, this 
may be indicated by specifying the corresponding paragraph and the 
statement ``[Reserved]. For guidance see Sec. 86.1824-01.''. This 
section applies to gasoline-, methanol-, natural gas- and liquefied 
petroleum gas-fueled LDV/Ts, MDPVs, and HDVs.
    (a) through (f) [Reserved]. For guidance see Sec. 86.1824-01.

    51. Sec. 86.1829-01 is amended by revising paragraph (b)(1)(iii)(B) 
and adding paragraph (b)(1)(iii)(F) to read as follows:


Sec. 86.1829-01  Durability and emission testing requirements; waivers.

* * * * *
    (b) * * *
    (1) * * *
    (iii)* * *
    (B) In lieu of testing an Otto-cycle light-duty vehicle, light-duty 
truck, or heavy-duty vehicle for particulate emissions for 
certification, a manufacturer may provide a statement in its 
application for certification that such vehicles comply with the 
applicable standards. Such a statement must be based on previous 
emission tests, development tests, or other appropriate information.
* * * * *
    (F) In lieu of testing a petroleum-fueled heavy-duty vehicle for 
formaldehyde emissions for certification, a manufacturer may provide a 
statement in its application for certification that such vehicles 
comply with the applicable standards. Such a statement must be based on 
previous emission tests, development tests, or other appropriate 
information.
* * * * *

    52. A new Sec. 86.1863-07 is added to subpart S, to read as 
follows:


Sec. 86.1863-07  Optional chassis certification for diesel vehicles.

    (a) A manufacturer may optionally certify heavy-duty diesel 
vehicles under 14,000 pounds GVWR to the standards specified in 
Sec. 86.1816-08. Such vehicles must meet all requirements of Subpart S 
that are applicable to Otto-cycle vehicles, except for evaporative, 
refueling, and OBD requirements.
    (b) Diesel vehicles optionally certified under this section are 
subject to the OBD requirements of Sec. 86.005-17.
    (c) Diesel vehicles optionally certified under this section may be 
tested using the test fuels, sampling systems, or analytical systems 
specified for diesel engines in Subpart N of this part.
    (d) Diesel vehicles optionally certified under this section may not 
be included in any averaging, banking, or trading program.
    (e) The provisions of Sec. 86.004-40 apply to the engines in 
vehicles certified under this section.
    (f) Diesel vehicles may be certified under this section to the 
standards applicable to model year 2008 prior to model year 2008.
    (g) Diesel vehicles optionally certified under this section in 
model years 2007, 2008, or 2009 shall be included in phase-in 
calculations specified in Sec. 86.007-11(g).
[FR Doc. 01-2 Filed 1-17-01; 8:45 am]
BILLING CODE 6560-50-P