```

[Federal Register Volume 76, Number 229 (Tuesday, November 29, 2011)]
[Proposed Rules]
[Pages 73956-73982]
From the Federal Register Online via the Government Printing Office [www.gpo.gov]
[FR Doc No: 2011-30650]

[[Page 73955]]

Vol. 76

Tuesday,

No. 229

November 29, 2011

Part VI

Environmental Protection Agency

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40 CFR Part 52

Approval and Promulgation of Air Quality Implementation Plans; Maine; 
Regional Haze; Proposed Rule

Federal Register / Vol. 76, No. 229 / Tuesday, November 29, 2011 / 
Proposed Rules

[[Page 73956]]

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ENVIRONMENTAL PROTECTION AGENCY

40 CFR Part 52

[EPA-R01-OAR-2010-1043; A-1-FRL-9496-5]

Approval and Promulgation of Air Quality Implementation Plans; 
Maine; Regional Haze

AGENCY: Environmental Protection Agency (EPA).

ACTION: Proposed rule.

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SUMMARY: EPA is proposing approval of a revision to the Maine State 
Implementation Plan (SIP) submitted by the Maine Department of 
Environmental Protection (Maine DEP) on December 9, 2010, with 
supplemental submittals on September 14, 2011 and November 9, 2011, 
that addresses regional haze for the first planning period from 2008 
through 2018. This revision addresses the requirements of the Clean Air 
Act (CAA) and EPA's rules that require States to prevent any future, 
and remedy any existing, manmade impairment of visibility in mandatory 
Class I areas caused by emissions of air pollutants from numerous 
sources located over a wide geographic area (also referred to as the 
``regional haze program''). States are required to assure reasonable 
progress toward the national goal of achieving natural visibility 
conditions in Class I areas.

DATES: Written comments must be received on or before December 29, 
2011.

ADDRESSES: Submit your comments, identified by Docket ID Number EPA-
R01-OAR-2010-1043 by one of the following methods:
    1. http://www.regulations.gov: Follow the on-line instructions for 
submitting comments.
    2. Email: arnold.anne@epa.gov.
    3. Fax: (617) 918-0047.
    4. Mail: ``Docket Identification Number EPA-R01-OAR-2010-1043 Anne 
Arnold, U.S. Environmental Protection Agency, EPA New England Regional 
Office, Office of Ecosystem Protection, Air Quality Planning Unit, 5 
Post Office Square--Suite 100, (Mail code OEP05-2), Boston, MA 02109-
3912.
    5. Hand Delivery or Courier. Deliver your comments to: Anne Arnold, 
Manager, Air Quality Planning Unit, U.S. Environmental Protection 
Agency, EPA New England Regional Office, Office of Ecosystem 
Protection, Air Quality Planning Unit, 5 Post Office Square--Suite 100, 
(mail code OEP05-2), Boston, MA 02109-3912. Such deliveries are only 
accepted during the Regional Office's normal hours of operation. The 
Regional Office's official hours of business are Monday through Friday, 
8:30 to 4:30, excluding legal holidays.
    Instructions: Direct your comments to Docket ID No. EPA-R01-OAR-
2010-1043. EPA's policy is that all comments received will be included 
in the public docket without change and may be made available online at 
http://www.regulations.gov, including any personal information 
provided, unless the comment includes information claimed to be 
Confidential Business Information (CBI) or other information whose 
disclosure is restricted by statute. Do not submit through http://www.regulations.gov, or email, information that you consider to be CBI 
or otherwise protected. The http://www.regulations.gov Web site is an 
``anonymous access'' system, which means EPA will not know your 
identity or contact information unless you provide it in the body of 
your comment. If you send an email comment directly to EPA without 
going through http://www.regulations.gov your email address will be 
automatically captured and included as part of the comment that is 
placed in the public docket and made available on the Internet. If you 
submit an electronic comment, EPA recommends that you include your name 
and other contact information in the body of your comment and with any 
disk or CD-ROM you submit. If EPA cannot read your comment due to 
technical difficulties and cannot contact you for clarification, EPA 
may not be able to consider your comment. Electronic files should avoid 
the use of special characters, any form of encryption, and be free of 
any defects or viruses.
    Docket: All documents in the electronic docket are listed in the 
http://www.regulations.gov index. Although listed in the index, some 
information is not publicly available, i.e., CBI or other information 
whose disclosure is restricted by statute. Certain other material, such 
as copyrighted material, is not placed on the Internet and will be 
publicly available only in hard copy form. Publicly available docket 
materials are available either electronically in http://www.regulations.gov or in hard copy at Office of Ecosystem Protection, 
U.S. Environmental Protection Agency, EPA New England Regional Office, 
Office of Ecosystem Protection, Air Quality Planning Unit, 5 Post 
Office Square--Suite 100, Boston, MA. EPA requests that if at all 
possible, you contact the contact listed in the FOR FURTHER INFORMATION 
CONTACT section to schedule your inspection. The Regional Office's 
official hours of business are Monday through Friday, 8:30 to 4:30, 
excluding legal holidays.
    In addition, copies of the state submittal are also available for 
public inspection during normal business hours, by appointment at the 
Bureau of Air Quality Control, Department of Environmental Protection, 
First Floor of the Tyson Building, Augusta Mental Health Institute 
Complex, Augusta, ME 04333-0017.

FOR FURTHER INFORMATION CONTACT: Anne McWilliams, Air Quality Unit, 
U.S. Environmental Protection Agency, EPA New England Regional Office, 
5 Post Office Square--Suite 100, (Mail Code OEP05-02), Boston, MA 
02109-3912, telephone number (617) 918-1697, fax number (617) 918-0697, 
email mcwilliams.anne@epa.gov.

SUPPLEMENTARY INFORMATION: 

Table of Contents

I. What is the background for EPA's proposed action?
    A. The Regional Haze Problem
    B. Background Information
    C. Roles of Agencies in Addressing regional haze
II. What are the requirements for the regional haze SIPs?
    A. The CAA and the Regional Haze Rule (RHR)
    B. Determination of Baseline, Natural, and Current Visibility 
Conditions
    C. Determination of Reasonable Progress Goals (RPGs)
    D. Best Available Retrofit Technology (BART)
    E. Long-Term Strategy (LTS)
    F. Coordinating Regional Haze and Reasonably Attributable 
Visibility Impairment (RAVI) LTS
    G. Monitoring Strategy and Other Implementation Plan 
Requirements
    H. Consultation With States and Federal Land Managers (FLMs)
III. What is the relationship of the Clean Air Interstate Rule 
(CAIR) and the Cross-State Air Pollution Rule (CSAPR) to the 
regional haze requirements?
    A. Overview of EPA's CAIR
    B. Remand of the CAIR
    C. Regional Haze SIP Elements Potentially Affected by the CAIR 
Remand and Promulgation of CSAPR
IV. What is EPA's analysis of Maine's regional haze SIP submittal?
    A. Maine's Affected Class I Area
    B. Determination of Baseline, Natural and Current Visibility 
Conditions
    1. Estimating Natural Visibility Conditions
    2. Estimating Baseline Conditions
    3. Summary of Baseline and Natural Conditions
    4. Uniform Rate of Progress
    C. Reasonable Progress Goals
    1. Relative Contributions of Pollutants to Visibility 
Impairments

[[Page 73957]]

    2. Procedure for Identifying Sources to Evaluate for Reasonable 
Progress Controls
    3. Application of the Four Clean Air Act Factors in the 
Reasonable Progress Analysis
    D. Best Available Retrofit Technology (BART)
    1. Identification of all BART Eligible Sources
    2. Identification of Sources Subject to BART
    3. Modeling to Demonstrate Source Visibility Impact
    4. Maine BART Analysis Protocol
    5. Source Specific BART Determinations
    6. Enforceability of BART
    E. Long-Term Strategy
    1. Emissions Inventory for 2018 With Federal and State Control 
Requirements
    2. Modeling to Support the LTS and Determine Visibility 
Improvement for Uniform Rate of Progress
    3. Meeting the MANE-VU ``Ask''
    4. Additional Considerations for the LTS
    F. Consultation With States and Federal Land Managers
    G. Monitoring Strategy and Other Implementation Plan 
Requirements
    H. Periodic SIP Revisions and Five-Year Progress Reports
V. What Action is EPA Proposing?
VI. Statutory and Executive Order Reviews

    Throughout this document, wherever ``we,'' ``us,'' or ``our'' is 
used, we mean the EPA.

I. What is the background for EPA's proposed action?

A. The Regional Haze Problem

    Regional haze is visibility impairment that is produced by a 
multitude of sources and activities which are located across a broad 
geographic area and emit fine particles and their precursors (e.g., 
sulfur dioxide, nitrogen oxides, and in some cases, ammonia and 
volatile organic compounds). Fine particle precursors react in the 
atmosphere to form fine particulate matter (PM2.5) (e.g., 
sulfates, nitrates, organic carbon, elemental carbon, and soil dust), 
which also impair visibility by scattering and absorbing light. 
Visibility impairment reduces the clarity, color, and visible distance 
that one can see. PM2.5 can also cause serious health 
effects and mortality in humans and contributes to environmental 
effects such as acid deposition.
    Data from the existing visibility monitoring network, the 
``Interagency Monitoring of Protected Visual Environments'' (IMPROVE) 
monitoring network, show that visibility impairment caused by air 
pollution occurs virtually all the time at most national park and 
wilderness areas. The average visual range in many Class I areas (i.e., 
national parks and memorial parks, wilderness areas, and international 
parks meeting certain size criteria) in the Western United States is 
100-150 kilometers, or about one-half to two-thirds of the visual range 
that would exist without anthropogenic air pollution. In most of the 
eastern Class I areas of the United States, the average visual range is 
less than 30 kilometers, or about one-fifth of the visual range that 
would exist under estimated natural conditions. (64 FR 35715, (July 1, 
1999))

B. Background Information

    In section 169A(a)(1) of the 1977 Amendments to the CAA, Congress 
created a program for protecting visibility in the nation's national 
parks and wilderness areas. This section of the CAA establishes as a 
national goal the ``prevention of any future, and the remedying of any 
existing, impairment of visibility in mandatory Class I Federal areas 
\1\ which impairment results from manmade air pollution.'' On December 
2, 1980, EPA promulgated regulations to address visibility impairment 
in Class I areas that is ``reasonably attributable'' to a single source 
or small group of sources, i.e., ``reasonably attributable visibility 
impairment'' (RAVI), (45 FR 80084). These regulations represented the 
first phase in addressing visibility impairment. EPA deferred action on 
regional haze that emanates from a variety of sources until monitoring, 
modeling and scientific knowledge about the relationships between 
pollutants and visibility impairment were improved.
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    \1\ Areas designated as mandatory Class I Federal areas consist 
of national parks exceeding 6,000 acres, wilderness areas and 
national memorial parks exceeding 5,000 acres, and all international 
parks that were in existence on August 7, 1977 (42 U.S.C. 7472(a)). 
In accordance with section 169A of the CAA, EPA, in consultation 
with the Department of Interior, promulgated a list of 156 areas 
where visibility is identified as an important value (44 FR 69122, 
November 30, 1979). The extent of a mandatory Class I area includes 
subsequent changes in boundaries, such as park expansions (42 U.S.C. 
7472(a)). Although states and Tribes may designate as Class I 
additional areas which they consider to have visibility as an 
important value, the requirements of the visibility program set 
forth in section 169A of the CAA apply only to ``mandatory Class I 
Federal areas.'' Each mandatory Class I Federal area is the 
responsibility of a ``Federal Land Manager'' (FLM). (42 U.S.C. 
7602(i)). When we use the term ``Class I area'' in this action, we 
mean a ``mandatory Class I Federal area.''
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    Congress added section 169B to the CAA in 1990 to address regional 
haze issues. In 1993, the National Academy of Sciences determined that 
current knowledge of regional haze was adequate and that existing 
technologies were available to protect visibility. (64 FR 35714, 35714 
(July 1, 1999)). EPA promulgated a rule to address regional haze on 
July 1, 1999 (64 FR 35714), the Regional Haze Rule. The Regional Haze 
Rule revised the existing visibility regulations to integrate into the 
regulation provisions addressing regional haze impairment and 
established a comprehensive visibility protection program for Class I 
areas. The requirements for regional haze, found at 40 CFR 51.308 and 
51.309, are included in EPA's visibility protection regulations at 40 
CFR 51.300-309. Some of the main elements of the regional haze 
requirements are summarized in section II. The requirement to submit a 
regional haze SIP applies to all 50 States, the District of Columbia 
and the Virgin Islands. Section 51.308(b) requires States to submit the 
first implementation plan addressing regional haze visibility 
impairment no later than December 17, 2007. On January 15, 2009, EPA 
found that 37 States, the District of Columbia and the U.S. Virgin 
Islands failed to submit this required implementation plan. (74 FR 
2392, (Jan. 15, 2009)). In particular, EPA found that Maine failed to 
submit a plan that met the requirements of 40 CFR 51.308. (74 FR 2393). 
On December 6, 2010, the Air Bureau of the Maine DEP submitted 
revisions to the Maine SIP to address regional haze as required by 40 
CFR 51.308. Supplemental documentation was submitted on September 14, 
2011 and November 9, 2011. EPA has reviewed Maine's submittal and finds 
that it is consistent with the requirements of 40 CFR 51.308 outlined 
in section II.

C. Roles of Agencies in Addressing Regional Haze

    Successful implementation of the regional haze program will require 
long-term regional coordination among States, Tribal governments and 
various federal agencies. As noted above, pollution affecting the air 
quality in Class I areas can be transported over long distances, even 
hundreds of kilometers. Therefore, to effectively address the problem 
of visibility impairment in Class I areas, States need to develop 
strategies in coordination with one another, taking into account the 
effect of emissions from one jurisdiction on the air quality in 
another.
    Because the pollutants that lead to regional haze can originate 
from sources located across broad geographic areas, EPA has encouraged 
the States and Tribes across the United States to address visibility 
impairment from a regional perspective. Five regional planning 
organizations (RPOs) were developed to address regional haze and 
related issues. The RPOs first evaluated

[[Page 73958]]

technical information to better understand how their States and Tribes 
impact Class I areas across the country, and then pursued the 
development of regional strategies to reduce emissions of 
PM2.5 and other pollutants leading to regional haze.
    The Mid-Atlantic/Northeast Visibility Union (MANE-VU) RPO is a 
collaborative effort of state governments, Tribal governments, and 
various federal agencies established to initiate and coordinate 
activities associated with the management of regional haze, visibility 
and other air quality issues in the Northeastern United States. Member 
state and Tribal governments include: Connecticut, Delaware, the 
District of Columbia, Maine, Maryland, Massachusetts, New Hampshire, 
New Jersey, New York, Pennsylvania, Penobscot Indian Nation, Rhode 
Island, and Vermont.

II. What are the requirements for regional haze SIPs?

A. The CAA and the Regional Haze Rule (RHR)

    Regional haze SIPs must assure reasonable progress towards the 
national goal of achieving natural visibility conditions in Class I 
areas. Section 169A of the CAA and EPA's implementing regulations 
require States to establish long-term strategies for making reasonable 
progress toward meeting this goal. Implementation plans must also give 
specific attention to certain stationary sources that were in existence 
on August 7, 1977, but were not in operation before August 7, 1962, and 
require these sources, where appropriate, to install Best Available 
Retrofit Technology controls for the purpose of eliminating or reducing 
visibility impairment. The specific regional haze SIP requirements are 
discussed in further detail below.

B. Determination of Baseline, Natural, and Current Visibility 
Conditions

    The RHR establishes the deciview (dv) as the principal metric for 
measuring visibility. This visibility metric expresses uniform changes 
in haziness in terms of common increments across the entire range of 
visibility conditions, from pristine to extremely hazy conditions. 
Visibility is determined by measuring the visual range (or deciview), 
which is the greatest distance, in kilometers or miles, at which a dark 
object can be viewed against the sky. The deciview is a useful measure 
for tracking progress in improving visibility, because each deciview 
change is an equal incremental change in visibility perceived by the 
human eye. Most people can detect a change in visibility at one 
deciview.\2\
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    \2\ The preamble to the RHR provides additional details about 
the deciview (64 FR 35714, 35725 (July 1, 1999)).
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    The deciview is used to: Express Reasonable Progress Goals (RPGs) 
(which are interim visibility goals towards meeting the national 
visibility goal); define baseline, current, and natural conditions; and 
track changes in visibility. The regional haze SIPs must contain 
measures that ensure ``reasonable progress'' toward the national goal 
of preventing and remedying visibility impairment in Class I areas 
caused by manmade air pollution by reducing anthropogenic emissions 
that cause regional haze. The national goal is a return to natural 
conditions, i.e., manmade sources of air pollution would no longer 
impair visibility in Class I areas.
    To track changes in visibility over time at each of the 156 Class I 
areas covered by the visibility program and as part of the process for 
determining reasonable progress, States must calculate the degree of 
existing visibility impairment at each Class I area within the state at 
the time of each regional haze SIP submittal and periodically review 
progress every five years midway through each 10-year planning period. 
To do this, the RHR requires States to determine the degree of 
impairment (in deciviews) for the average of the 20 percent least 
impaired (``best'') and 20 percent most impaired (``worst'') visibility 
days over a specified time period at each of their Class I areas. In 
addition, States must also develop an estimate of natural visibility 
conditions for the purposes of comparing progress toward the national 
goal. Natural visibility is determined by estimating the natural 
concentrations of pollutants that cause visibility impairment and then 
calculating total light extinction based on those estimates. EPA has 
provided guidance to States regarding how to calculate baseline, 
natural and current visibility conditions in documents titled, Guidance 
For Estimating Natural Visibility Conditions Under the Regional Haze 
Rule, September 2003, (EPA-454/B-03-005), available at www.epa.gov/ttncaaa1/t1/memoranda/rh_envcurhr_gd.pdf [hereinafter EPA's 2003 
Natural Visibility Guidance], and Guidance for Tracking Progress Under 
the Regional Haze Rule, September 2003 (EPA-454/B-03-004), available at 
www.epa.gov/ttncaaa1/t1/memoranda/rh_tpurhr_gd.pdf [hereinafter EPA's 
2003 Tracking Progress Guidance].
    For the first regional haze SIPs that were due by December 17, 
2007, ``baseline visibility conditions'' were the starting points for 
assessing ``current'' visibility impairment. Baseline visibility 
conditions represent the degree of impairment for the 20 percent least 
impaired days and 20 percent most impaired days at the time the 
regional haze program was established. Using monitoring data from 2000 
through 2004, States are required to calculate the average degree of 
visibility impairment for each Class I area within the state, based on 
the average of annual values over the five year period. The comparison 
of initial baseline visibility conditions to natural visibility 
conditions indicates the amount of improvement necessary to attain 
natural visibility, while the future comparison of baseline conditions 
to the then current conditions will indicate the amount of progress 
made. In general, the 2000-2004 baseline period is considered the time 
from which improvement in visibility is measured.

C. Determination of Reasonable Progress Goals (RPGs)

    The vehicle for ensuring continuing progress towards achieving the 
natural visibility goal is the submission of a series of regional haze 
SIPs from the States that establish RPGs for Class I areas for each 
(approximately) 10-year planning period. The RHR does not mandate 
specific milestones or rates of progress, but instead calls for States 
to establish goals that provide for ``reasonable progress'' toward 
achieving natural (i.e., ``background'') visibility conditions for 
their Class I areas. In setting RPGs, States must provide for an 
improvement in visibility for the most impaired days over the 
(approximately) 10-year period of the SIP, and ensure no degradation in 
visibility for the least impaired days over the same period.
    States have significant discretion in establishing RPGs, but are 
required to consider the following factors established in the CAA and 
in EPA's RHR: (1) The costs of compliance; (2) the time necessary for 
compliance; (3) the energy and non-air quality environmental impacts of 
compliance; and (4) the remaining useful life of any potentially 
affected sources. States must demonstrate in their SIPs how these 
factors are considered when selecting the RPGs for the best and worst 
days for each applicable Class I area. (40 CFR 51.308(d)(1)(i)(A)). 
States have considerable flexibility in how they take these factors 
into consideration, as noted in EPA's Guidance for Setting Reasonable 
Progress Goals under the Regional Haze Program, (``EPA's

[[Page 73959]]

Reasonable Progress Guidance''), July 1, 2007, memorandum from William 
L. Wehrum, Acting Assistant Administrator for Air and Radiation, to EPA 
Regional Administrators, EPA Regions 1-10 (pp. 4-2, 5-1). In setting 
the RPGs, States must also consider the rate of progress needed to 
reach natural visibility conditions by 2064 (referred to as the 
``uniform rate of progress'' or the ``glide path'') and the emission 
reduction measures needed to achieve that rate of progress over the 10-
year period of the SIP. The year 2064 represents a rate of progress 
which States are to use for analytical comparison to the amount of 
progress they expect to achieve. In setting RPGs, each state with one 
or more Class I areas (``Class I State'') must also consult with 
potentially ``contributing states,'' i.e., other nearby states with 
emission sources that may be affecting visibility impairment at the 
Class I State's areas. (40 CFR 51.308(d)(1)(iv)).

D. Best Available Retrofit Technology (BART)

    Section 169A of the CAA directs States to evaluate the use of 
retrofit controls at certain larger, often uncontrolled, older 
stationary sources in order to address visibility impacts from these 
sources. Specifically, the CAA requires States to revise their SIPs to 
contain such measures as may be necessary to make reasonable progress 
towards the natural visibility goal, including a requirement that 
certain categories of existing stationary sources built between 1962 
and 1977 procure, install, and operate the ``Best Available Retrofit 
Technology'' as determined by the state.(CAA 169A(b)(2)a)).\3\ States 
are directed to conduct BART determinations for such sources that may 
be anticipated to cause or contribute to any visibility impairment in a 
Class I area. Rather than requiring source-specific BART controls, 
States also have the flexibility to adopt an emissions trading program 
or other alternative program as long as the alternative provides 
greater reasonable progress towards improving visibility than BART.
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    \3\ The set of ``major stationary sources'' potentially subject 
to BART are listed in CAA section 169A(g)(7).
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    On July 6, 2005, EPA published the Guidelines for BART 
Determinations Under the Regional Haze Rule at Appendix Y to 40 CFR 
part 51 (hereinafter referred to as the ``BART Guidelines'') to assist 
States in determining which of their sources should be subject to the 
BART requirements and in determining appropriate emission limits for 
each applicable source. In making a BART applicability determination 
for a fossil fuel-fired electric generating plant with a total 
generating capacity in excess of 750 megawatts (MW), a state must use 
the approach set forth in the BART Guidelines. A state is encouraged, 
but not required, to follow the BART Guidelines in making BART 
determinations for other types of sources.
    States must address all visibility impairing pollutants emitted by 
a source in the BART determination process. The most significant 
visibility impairing pollutants are sulfur dioxide (SO2), 
nitrogen oxides (NOX), and particulate matter (PM). EPA has 
stated that States should use their best judgment in determining 
whether volatile organic compounds (VOCs), or ammonia (NH3) 
and ammonia compounds impair visibility in Class I areas.
    The RPOs provided air quality modeling to the States to help them 
in determining whether potential BART sources can be reasonably 
expected to cause or contribute to visibility impairment in a Class I 
area. Under the BART Guidelines, States may select an exemption 
threshold value for their BART modeling, below which a BART eligible 
source would not be expected to cause or contribute to visibility 
impairment in any Class I area. The state must document this exemption 
threshold value in the SIP and must state the basis for its selection 
of that value. Any source with emissions that model above the threshold 
value would be subject to a BART determination review. The BART 
Guidelines acknowledge varying circumstances affecting different Class 
I areas. States should consider the number of emission sources 
affecting the Class I areas at issue and the magnitude of the 
individual sources' impacts. Any exemption threshold set by the state 
should not be higher than 0.5 deciviews (70 FR 39161, (July 6, 2005)).
    In their SIPs, States must identify potential BART sources, 
described as ``BART-eligible sources'' in the RHR, and document their 
BART control determination analyses. The term ``BART-eligible source'' 
used in the BART Guidelines means the collection of individual emission 
units at a facility that together comprises the BART-eligible source. 
(70 FR 39161, (July 6, 2005)). In making BART determinations, section 
169A(g)(2) of the CAA requires that States consider the following 
factors: (1) The costs of compliance; (2) the energy and non-air 
quality environmental impacts of compliance; (3) any existing pollution 
control technology in use at the source; (4) the remaining useful life 
of the source; and (5) the degree of improvement in visibility which 
may reasonably be anticipated to result from the use of such 
technology. States are free to determine the weight and significance to 
be assigned to each factor. (70 FR 39170, (July 6, 2005)).
    A regional haze SIP must include source-specific BART emission 
limits and compliance schedules for each source subject to BART. Once a 
state has made its BART determination, the BART controls must be 
installed and in operation as expeditiously as practicable, but no 
later than five years after the date of EPA approval of the regional 
haze SIP, as required in the CAA (section 169(g)(4)) and in the RHR (40 
CFR 51.308(e)(1)(iv)). In addition to what is required by the RHR, 
general SIP requirements mandate that the SIP must also include all 
regulatory requirements related to monitoring, recordkeeping, and 
reporting for the BART controls on the source. States have the 
flexibility to choose the type of control measures they will use to 
meet the requirements of BART.

E. Long-Term Strategy (LTS)

    Section 51.308(d)(3) of the RHR requires that States include a LTS 
in their SIPs. The LTS is the compilation of all control measures a 
state will use to meet any applicable RPGs. The LTS must include 
``enforceable emissions limitations, compliance schedules, and other 
measures as necessary to achieve the reasonable progress goals'' for 
all Class I areas within, or affected by emissions from, the state. (40 
CFR 51.308(d)(3)).
    When a state's emissions are reasonably anticipated to cause or 
contribute to visibility impairment in a Class I area located in 
another state, the RHR requires the impacted state to coordinate with 
the contributing States in order to develop coordinated emissions 
management strategies. (40 CFR 51.308(d)(3)(i)). In such cases, the 
contributing state must demonstrate that it has included in its SIP all 
measures necessary to obtain its share of the emission reductions 
needed to meet the RPGs for the Class I area. The RPOs have provided 
forums for significant interstate consultation, but additional 
consultations between States may be required to sufficiently address 
interstate visibility issues. This is especially true where two States 
belong to different RPOs.
    States should consider all types of anthropogenic sources of 
visibility impairment in developing their LTS, including stationary, 
minor, mobile, and

[[Page 73960]]

area sources. At a minimum, States must describe how each of the seven 
factors listed below is taken into account in developing their LTS: (1) 
Emission reductions due to ongoing air pollution control programs, 
including measures to address RAVI; (2) measures to mitigate the 
impacts of construction activities; (3) emissions limitations and 
schedules for compliance to achieve the RPG; (4) source retirement and 
replacement schedules; (5) smoke management techniques for agricultural 
and forestry management purposes including plans as currently exist 
within the state for these purposes; (6) enforceability of emissions 
limitations and control measures; (7) the anticipated net effect on 
visibility due to projected changes in point, area, and mobile source 
emissions over the period addressed by the LTS. (40 CFR 
51.308(d)(3)(v)).

F. Coordinating Regional Haze and Reasonably Attributable Visibility 
Impairment (RAVI) LTS

    As part of the RHR, EPA revised 40 CFR 51.306(c) regarding the LTS 
for RAVI to require that the RAVI plan must provide for a periodic 
review and SIP revision not less frequently than every three years 
until the date of submission of the state's first plan addressing 
regional haze visibility impairment, which was due December 17, 2007, 
in accordance with 51.308(b) and (c). On or before this date, the state 
must revise its plan to provide for review and revision of a 
coordinated LTS for addressing reasonably attributable and regional 
haze visibility impairment, and the state must submit the first such 
coordinated LTS with its first regional haze SIP. Future coordinated 
LTS's, and periodic progress reports evaluating progress towards RPGs, 
must be submitted consistent with the schedule for SIP submission and 
periodic progress reports set forth in 40 CFR 51.308(f) and 51.308(g), 
respectively. The periodic reviews of a state's LTS must report on both 
regional haze and RAVI impairment and must be submitted to EPA as a SIP 
revision.

G. Monitoring Strategy and Other Implementation Plan Requirements

    Section 51.308(d)(4) of the RHR includes the requirement for a 
monitoring strategy for measuring, characterizing, and reporting of 
regional haze visibility impairment that is representative of all 
mandatory Class I Federal areas within the state. The strategy must be 
coordinated with the monitoring strategy required in section 51.305 for 
RAVI. Compliance with this requirement may be met through participation 
in the IMPROVE network. The monitoring strategy is due with the first 
regional haze SIP, and it must be reviewed every five years. The 
monitoring strategy must also provide for additional monitoring sites 
if the IMPROVE network is not sufficient to determine whether RPGs will 
be met.
    The SIP must also provide for the following:
     Procedures for using monitoring data and other information 
in a state with mandatory Class I areas to determine the contribution 
of emissions from within the state to regional haze visibility 
impairment at Class I areas both within and outside the state;
     Procedures for using monitoring data and other information 
in a state with no mandatory Class I areas to determine the 
contribution of emissions from within the state to regional haze 
visibility impairment at Class I areas in other States;
     Reporting of all visibility monitoring data to the 
Administrator at least annually for each Class I area in the state, and 
where possible, in electronic format;
     Developing a statewide inventory of emissions of 
pollutants that are reasonably anticipated to cause or contribute to 
visibility impairment in any Class I area. The inventory must include 
emissions for a baseline year, emissions for the most recent year for 
which data are available, and estimates of future projected emissions. 
A state must also make a commitment to update the inventory 
periodically; and
     Other elements, including reporting, recordkeeping, and 
other measures necessary to assess and report on visibility.
    Section 51.308(f) of the RHR requires control strategies to cover 
an initial implementation period extending to the year 2018, with a 
comprehensive reassessment and revision of those strategies, as 
appropriate, every 10 years thereafter. Periodic SIP revisions must 
meet the core requirements of section 51.308(d) with the exception of 
BART. The BART provisions of section 51.308(e), as noted above, apply 
only to the first implementation period. Periodic SIP revisions will 
assure that the statutory requirement of reasonable progress will 
continue to be met.

H. Consultation With States and Federal Land Managers (FLMs)

    The RHR requires that States consult with FLMs before adopting and 
submitting their SIPs. (40 CFR 51.308(i)). States must provide FLMs an 
opportunity for consultation, in person and at least 60 days prior to 
holding any public hearing on the SIP. This consultation must include 
the opportunity for the FLMs to discuss their assessment of impairment 
of visibility in any Class I area and to offer recommendations on the 
development of the RPGs and on the development and implementation of 
strategies to address visibility impairment. Further, a state must 
include in its SIP a description of how it addressed any comments 
provided by the FLMs. Finally, a SIP must provide procedures for 
continuing consultation between the state and FLMs regarding the 
state's visibility protection program, including development and review 
of SIP revisions, five-year progress reports, and the implementation of 
other programs having the potential to contribute to impairment of 
visibility in Class I areas.

III. What is the relationship of the Clean Air Interstate Rule (CAIR) 
and the Cross-State Air Pollution Rule (CSAPR) to the regional haze 
requirements?

A. Overview of EPA's CAIR

    CAIR, as originally promulgated, required 28 States and the 
District of Columbia to reduce emissions of SO2 and 
NOX that significantly contributed to, or interfered with 
maintenance of, the 1997 national ambient air quality standards (NAAQS) 
for fine particulates and/or the 1997 NAAQS for 8-hour ozone in any 
downwind state. (70 FR 25162, (May 12, 2005)). CAIR established 
emissions budgets for SO2 and NOX for States 
found to contribute significantly to nonattainment in downwind States 
and required these States to submit SIP revisions that implemented 
these budgets. States had the flexibility to choose which control 
measures to adopt to achieve the budgets, including participation in 
EPA-administered cap-and-trade programs addressing SO2, 
NOX-annual, and NOX-ozone season emissions. In 
2006, EPA promulgated FIPs for all States covered by CAIR to ensure the 
reductions were achieved in a timely manner.

B. Remand of the CAIR

    On July 11, 2008, the DC Circuit issued its decision to vacate and 
remand both CAIR and the associated CAIR FIPs in their entirety. See 
North Carolina v. EPA, 531 F.3d 836 (DC Cir. 2008). However, in 
response to EPA's petition for rehearing, the Court issued an order 
remanding CAIR to EPA without vacating either CAIR or the CAIR FIPs. 
The Court thereby left the EPA CAIR rule and CAIR SIPs and FIPs in 
place in order to ``temporarily preserve the environmental values 
covered by CAIR'' until EPA replaces it with a rule

[[Page 73961]]

consistent with the court's opinion. See North Carolina v. EPA, 550 
F.3d at 1178. The Court directed EPA to ``remedy CAIR's flaws'' 
consistent with its July 11, 2008, opinion but declined to impose a 
schedule on EPA for completing that action. EPA subsequently issued a 
new rule to address interstate transport of NOX and 
SO2 in the eastern United States (i.e., the Transport Rule, 
also known as the Cross-State Air Pollution Rule). (76 FR 48208, 
(August 8, 2011)). EPA explained in that action that EPA is 
promulgating the Transport Rule as a replacement for (not a successor 
to) CAIR's SO2 and NOX emissions reduction and 
trading programs.

C. Regional Haze SIP Elements Potentially Affected by the CAIR Remand 
and Promulgation of CSAPR

    The following is a summary of the elements of the regional haze 
SIPs that are potentially affected by the remand of CAIR. As described 
above, EPA determined in 2005 that States opting to participate in the 
CAIR cap-and-trade program need not require BART for SO2 and 
NOX at BART-eligible Electric Generating Units (EGUs). (70 
FR 39142-39143). Many States relied on CAIR as an alternative to BART 
for SO2 and NOX for subject EGUs, as allowed 
under the BART provisions at 40 CFR 51.308(e)(4). Additionally, several 
States established RPGs that reflect the improvement in visibility 
expected to result from controls planned for or already installed on 
sources within the State to meet the CAIR provisions for this 
implementation period for specified pollutants. Many States relied upon 
their own CAIR SIPs or the CAIR FIPs for their States to provide the 
legal requirements which lead to these planned controls, and did not 
include enforceable measures in the LTS in the regional haze SIP 
submission to ensure these reductions. States also submitted 
demonstrations showing that no additional controls on EGUs beyond CAIR 
would be reasonable for this implementation period.

IV. What is EPA's analysis of Maine's regional haze SIP submittal?

    On December 6, 2010, Maine DEP's Air Bureau submitted revisions to 
the Maine SIP to address regional haze as required by 40 CFR 51.308. 
Supplemental documentation was submitted on September 14, 2011 and 
November 9, 2011. EPA has reviewed Maine's submittal and finds that it 
is consistent with the requirements of 40 CFR 51.308 outlined in 
section II. A detailed analysis follows.
    Maine is responsible for developing a regional haze SIP which 
addresses visibility in Maine's Class I areas. They are Acadia National 
Park, Moosehorn Wilderness Area, and Roosevelt Campobello International 
Park. The State must also address Maine's impact on any other nearby 
Class I areas.

A. Maine's Affected Class I Area

    Maine is home to three Class I areas: (1) Acadia National Park 
(`Acadia'); (2) Moosehorn Wilderness Area (`Moosehorn'); and (3) 
Roosevelt Campobello International Park (`Roosevelt Campobello'). In 
addition to these areas, the MANE-VU RPO contains four other Class I 
areas in three States: The Lye Brook, Presidential Range/Dry River, and 
Great Gulf Wilderness Areas in New Hampshire; and the Brigantine 
Wilderness Area in New Jersey.
    The Maine regional haze SIP establishes RPGs for visibility 
improvement at its Class I areas and a LTS to achieve those RPGs within 
the first regional haze implementation period ending in 2018. In 
developing the RPGs for each Class I area, Maine considered both 
emission sources inside and outside of Maine that may cause or 
contribute to visibility impairment in Maine's Class I areas. The State 
also identified and considered emission sources within Maine that may 
cause or contribute to visibility impairment in Class I areas in 
neighboring States as required by 40 CFR 51.308(d)(3). The MANE-VU RPO 
worked with the State in developing the technical analyses used to make 
these determinations, including state-by-state contributions to 
visibility impairment in specific Class I areas, which included the 
three areas in Maine and those areas affected by emissions from Maine.

B. Determination of Baseline, Natural and Current Visibility Conditions

    As required by the RHR and in accordance with EPA's 2003 Natural 
Visibility Guidance, Maine calculated baseline/current and natural 
conditions for its Class I areas.
1. Estimating Natural Visibility Conditions
    Natural background refers to visibility conditions that existed 
before human activities affected air quality in the region. The 
national goal, as set out in the Clean Air Act, is a return to natural 
conditions.
    Estimates of natural visibility conditions are based on annual 
average concentrations of fine particle components. The IMPROVE \4\ 
equation is a formula for estimating light extinction from species 
measured by the IMPROVE monitors. As documented in EPA's 2003 Natural 
Visibility Guidance, EPA determined, with concurrence from the IMPROVE 
Steering Committee, that States may use a ``refined approach'' to the 
then current IMPROVE formula to estimate the values that characterize 
the natural visibility conditions of the Class I areas. The purpose of 
the refinement to the ``old IMPROVE equation'' is to provide more 
accurate estimates of the various factors that affect the calculation 
of light extinction. The new IMPROVE equation takes into account the 
most recent review of the science \5\ and it accounts for the effect of 
particle size distribution on light extinction efficiency of sulfate, 
nitrate, and organic carbon. It also adjusts the mass multiplier for 
organic carbon (particulate organic matter) by increasing it from 1.4 
to 1.8. New terms are added to the equation to account for light 
extinction by sea salt and light absorption by gaseous nitrogen 
dioxide. Site-specific values are used for Rayleigh scattering 
(scattering of light due to atmospheric gases) to account for the site-
specific effects of elevation and temperature. Separate relative 
humidity enhancement factors are used for small and large size 
distributions of ammonium sulfate and ammonium nitrate and for sea 
salt. The terms for the remaining contributors, elemental

[[Page 73962]]

carbon (light-absorbing carbon), fine soil, and coarse mass terms, do 
not change between the original and new IMPROVE equations. Maine opted 
to use this refined approach, referred to as the ``new IMPROVE 
equation,'' for all of its areas.
---------------------------------------------------------------------------

    \4\ The Interagency Monitoring of Protected Visual Environments 
(IMPROVE) program is a cooperative measurement effort governed by a 
steering committee composed of representatives from Federal 
(including representatives from EPA and the FLMs) and RPOs. The 
IMPROVE monitoring program was established in 1985 to aid the 
creation of Federal and State implementation plans for the 
protection of visibility in Class I areas. One of the objectives of 
IMPROVE is to identify chemical species and emission sources 
responsible for existing man-made visibility impairment. The IMPROVE 
program has also been a key participant in visibility-related 
research, including the advancement of monitoring instrumentation, 
analysis techniques, visibility modeling, policy formulation and 
source attribution field studies.
    \5\ The science behind the revised IMPROVE equation is 
summarized in numerous published papers. See, eg., J. L. Hand & W. 
C. Malm, Review of the IMPROVE Equation for Estimating Ambient Light 
Extinction Coefficients--Final Report, March 2006 (Interagency 
Monitoring of Protected Visual Environments (IMPROVE), Colorado 
State University, Cooperative Institute for Research in the 
Atmosphere, Fort Collins, CO), available at http://vista.cira.colostate.edu/improve/publications/GrayLit/016_IMPROVEeqReview/IMPROVEeqReview.htm; Marc Pitchford, Natural Haze 
Levels II: Application of the New IMPROVE Alogrithm to Natural 
Species Concentrations Estimates: Final Report of the Natural Haze 
Levels II Committee to the RPO Monitoring/Data Analysis Workgroup, 
Sept. 2006, available at http://vista.cira.colostate.edu/improve/Publications/GrayLit/029_NaturalCondII/naturalhazelevelsIIreport.ppt.
---------------------------------------------------------------------------

    Natural visibility conditions using the new IMPROVE equation were 
calculated separately for each Class I area by MANE-VU. EPA finds that 
the best and worst 20 percent natural visibility values for Acadia, 
Moosehorn, and Roosevelt Campobello as shown in Table 1 were calculated 
using the EPA guidelines.
2. Estimating Baseline Conditions
    The Roosevelt Campobello International Park and the Moosehorn 
Wilderness Area do not contain an IMPROVE monitor. In cases where 
onsite monitoring is not available, 40 CFR 51.308(d)(2)(i) requires 
States to use the most representative monitoring available for the 
2000-2004 period to establish baseline visibility conditions, in 
consultation with EPA. Maine used, and EPA concurs with the use of, 
2000-2004 data from the IMPROVE monitor located one mile northeast from 
the Moosehorn Wilderness Area as representing Moosehorn and Roosevelt 
Campobello.
    As explained in section III.B, for the first regional haze SIP, 
baseline visibility conditions are the same as current conditions. A 
five-year average of the 2000 to 2004 monitoring data was calculated 
for each of the 20 percent worst and 20 percent best visibility days 
for Acadia National Park and Moosehorn/Roosevelt Campobello. IMPROVE 
data records for the period 2000 to 2004 meet the EPA requirements for 
data completeness. (See page 2-8 of EPA's 2003 Tracking Progress 
Guidance.)
3. Summary of Baseline and Natural Conditions
    For the Maine Class I areas, baseline visibility conditions on the 
20 percent worst days are 22.89 deciviews at Acadia National Park and 
21.72 deciviews at Moosehorn/Roosevelt Campobello. Natural visibility 
conditions for these areas are estimated to be 12.43 dv and 12.01 dv, 
respectively, on the 20 percent worst visibility days. The natural and 
background conditions for the Acadia National Park and Moosehorn 
Wilderness Area/Roosevelt Campobello International Park for both the 20 
percent worst and 20 percent best days are presented in Table 1 below.

 Table 1--Natural Background and Baseline Conditions for the Acadia National Park and Moosehorn Wilderness Area/
                                     Roosevelt Campobello International Park
----------------------------------------------------------------------------------------------------------------
                                                               2000-2004 Baseline (dv)   Natural conditions (dv)
                        Class I area                         ---------------------------------------------------
                                                               Worst 20%     Best 20%    Worst 20%     Best 20%
----------------------------------------------------------------------------------------------------------------
Acadia National Park........................................        22.89         8.77        12.43         4.66
Moosehorn Wilderness Area and Roosevelt Campobello                  21.72         9.15        12.01         5.01
 International Park.........................................
----------------------------------------------------------------------------------------------------------------

4. Uniform Rate of Progress
    In setting the RPGs, Maine considered the uniform rate of progress 
needed to reach natural visibility conditions by 2064 (``glide path'') 
and the emission reduction measures needed to achieve that rate of 
progress over the period of the SIP to meet the requirements of 40 CFR 
51.308(d)(1)(i)(B). As explained in EPA's Reasonable Progress Guidance 
document, the uniform rate of progress is not a presumptive target, and 
RPGs may be greater, lesser, or equivalent to the glide path.
    For Acadia National Park, the overall visibility improvement 
necessary to reach natural conditions is the difference between the 
baseline visibility of 22.89 dv and natural background visibility of 
12.43 dv, or an improvement of 10.46 dv for the 20 percent worst 
visibility days. For Moosehorn Wilderness area and Roosevelt Campobello 
International Park, the overall visibility improvement necessary to 
reach natural conditions is the difference between the baseline of 
21.72 dv and natural background visibility of 12.01 dv, or an 
improvement of 9.71 dv for the 20 percent worst visibility days. Maine 
DEP must also ensure no degradation in visibility for the best 20 
percent visibility days over the same period in accordance with 40 CFR 
51.308(d)(1).
    Maine's SIP submittal presents two graphs, one for the 20 percent 
best days, and one for the 20 percent worst days, for each Class I 
area. Maine constructed the graphs for the worst days (i.e., the glide 
path) in accordance with EPA's 2003 Tracking Progress Guidance by 
plotting a straight graphical line from the baseline level of 
visibility impairment for 2000-2004 to the level of natural visibility 
conditions in 2064. For the best days, the graphs include a horizontal, 
straight line spanning from baseline conditions in 2004 out to 2018 to 
depict no degradation in visibility over the implementation period of 
the SIP. Maine's SIP shows that the State's RPG for its Class I areas 
provide for improvement in visibility for the 20 percent worst days 
over the period of the implementation plan and ensure no degradation in 
visibility for the 20 percent best visibility days over the same period 
in accordance with 40 CFR 51.308(d)(1).

C. Reasonable Progress Goals

    As a state containing a Class I area, 40 CFR 51.308(d)(1) of the 
RHR requires Maine to develop the reasonable progress goals for 
visibility improvement during the first planning period.
1. Relative Contributions of Pollutants to Visibility Impairments
    An important step toward identifying reasonable progress measures 
is to identify the key pollutants contributing to visibility impairment 
at each Class I area. To understand the relative benefit of further 
reducing emissions from different pollutants, MANE-VU developed 
emission sensitivity model runs using EPA's Community Multiscale Air 
Quality (CMAQ) air quality model \6\ to evaluate visibility and air 
quality impacts from various groups of emissions and pollutant 
scenarios in the Class I areas on the 20 percent worst visibility days.
---------------------------------------------------------------------------

    \6\ CMAQ is a photochemical grid model. The model uses 
simulations of chemical reactions, emissions of PM2.5 and 
PM2.5 precursors, and the Pennsylvania State University/
National Center for Atmospheric Research Mesoscale Meteorological 
Model to produce speciated PM2.5 concentrations. For more 
information, see http://www.epa.gov/asmdnerl/CMAQ/cmaq_model.html.
---------------------------------------------------------------------------

    Regarding which pollutants are most significantly impacting 
visibility in the MANE-VU region, MANE-VU's contribution assessment 
demonstrated that sulfate is the major contributor to PM2.5 
mass and visibility impairment at Class I areas in the Northeast and 
Mid-

[[Page 73963]]

Atlantic Region.\7\ Sulfate particles commonly account for more than 50 
percent of particle-related light extinction at northeastern Class I 
areas on the clearest days and for as much as, or more than, 80 percent 
on the haziest days. For example, at the Brigantine National Wildlife 
Refuge Class I area (the MANE-VU Class I area with the greatest 
visibility impairment), on the 20 percent worst visibility days in 2000 
through 2004, sulfate accounted for 66 percent of the particle 
extinction. After sulfate, organic carbon (OC) consistently accounts 
for the next largest fraction of light extinction. Organic carbon 
accounted for 13 percent of light extinction on the 20 percent worst 
visibility days for Brigantine, followed by nitrate that accounts for 9 
percent of light extinction.
---------------------------------------------------------------------------

    \7\ See the NESCAUM Document ``Regional Haze and Visibility in 
the Northeast and Mid-Atlantic States,'' January 31, 2001.
---------------------------------------------------------------------------

    The emissions sensitivity analyses conducted by MANE-VU predict 
that reductions in SO2 emissions from EGU and non-EGU 
industrial point sources will result in the greatest improvements in 
visibility in the Class I areas in the MANE-VU region, more than any 
other visibility-impairing pollutant. As a result of the dominant role 
of sulfate in the formation of regional haze in the Northeast and Mid-
Atlantic Region, MANE-VU concluded that an effective emissions 
management approach would rely heavily on broad-based regional 
SO2 control efforts in the eastern United States.
    Through source apportionment modeling MANE-VU assisted States in 
determining their contribution to the visibility impairment of each 
Class I area in the MANE-VU region. Maine and the other MANE-VU States 
adopted a weight-of-evidence approach which relied on several 
independent methods for assessing the contribution of different sources 
and geographic source regions to regional haze in the northeastern and 
mid-Atlantic portions of the United States. Details about each 
technique can be found in the NESCAUM Document Contributions to 
Regional Haze in the Northeast and Mid-Atlantic United States, August 
2006 [hereinafter MANE-VU Contribution Report].\8\
---------------------------------------------------------------------------

    \8\ The August 2006 NESCAUM document ``Contributions to Regional 
Haze in the Northeast and Mid-Atlantic United States'' has been 
provided as part of the docket to this proposed rulemaking.
---------------------------------------------------------------------------

    The MANE-VU Class I States determined that any state contributing 
at least 2% of the total sulfate observed on the 20 percent worst 
visibility days in 2002 were contributors to visibility impairment at 
the Class I area. Connecticut, Rhode Island, Vermont, and the District 
of Columbia were determined to contribute less than 2% of sulfate at 
any of the MANE-VU Class I areas. States found to contribute 2% or more 
of the sulfate at any of the MANE-VU Class I areas were: Georgia, 
Illinois, Indiana, Kentucky, Maine, Maryland, Massachusetts, Michigan, 
New Hampshire, New Jersey, New York, North Carolina, Ohio, 
Pennsylvania, Tennessee, Virginia, and West Virginia.
    The contribution of Maine emissions to the total sulfate was 
determined to impact the visibility in not only the Maine Class I 
areas, but the Great Gulf Wilderness area in New Hampshire as well. The 
impact of sulfate on visibility is discussed in greater detail below.
    EPA finds that Maine DEP has adequately demonstrated that emissions 
from Maine sources cause or contribute to visibility in nearby Class I 
Areas.
2. Procedure for Identifying Sources To Evaluate for Reasonable 
Progress Controls
    In developing the 2018 reasonable progress goal, Maine relied 
primarily upon the information and analysis developed by MANE-VU to 
meet this requirement. Based on the contribution assessment, MANE-VU 
focused on SO2 as the dominant contributor to visibility 
impairment at all MANE-VU Class I areas during all seasons. In 
addition, the Contribution Assessment found that only 25 percent of the 
sulfate at the MANE-VU Class I areas originate in the MANE-VU States. 
Sources in the Midwest and Southeast regions were responsible for 15 to 
25 percent, respectively. Point sources dominated the inventory of 
SO2 emissions. Therefore, MANE-VU's strategy includes 
additional measures to control sources of SO2 both within 
the MANE-VU region and in other States that were determined to 
contribute to regional haze at the MANE-VU Class I Areas.
    Based on information from the contribution assessment and 
additional emission inventory analysis, MANE-VU and Maine identified 
the following source categories for further examination for reasonable 
controls:
     Coal and oil-fired EGUs;
     Point and area source industrial, commercial and 
institutional boilers;
     Cement and Lime Kilns;
     Heating Oil; and
     Residential wood combustion.
    MANE-VU analyzed these sources categories as potential sources of 
emission reductions for making reasonable progress based on the ``four 
statutory factors'' according to 40 CFR 51.308(d)(3)(V).
3. Application of the Four Clean Air Act Factors in the Reasonable 
Progress Analysis
    As discussed in II.C above, Maine must consider the following 
factors in developing the RPGs: (1) Cost of compliance; (2) the time 
necessary for compliance; (3) the energy and non-air quality 
environmental impacts of compliance; and (4) the remaining useful life 
of any potentially affected sources. MANE-VU's four factor analysis can 
be found in ``Assessment of Reasonable Progress for Regional Haze in 
MANE-VU Class I Areas,'' July 9, 2007, otherwise known as the 
Reasonable Progress Report. This report has been included as part of 
the docket for this rulemaking.
    Maine and the other MANE-VU States reviewed the Reasonable Progress 
Report, consulted with one another about possible controls measures, 
and agreed to the following measures as recommended strategies for 
making reasonable progress: Implementation of the BART requirements, a 
90 percent reduction in SO2 emissions from 167 EGUs 
identified as causing the greatest visibility impact \9\ (or other 
equivalent emission reduction), and a reduction in the sulfur content 
of fuel oil. These measures are collectively known as the MANE-VU 
``Ask.''
---------------------------------------------------------------------------

    \9\ MANE-VU identified these 167 units based on source 
apportionment modeling using two different meteorological data sets. 
From each of the modeling runs, MANE-VU identified the top 100 units 
which contribute to visibility impairment. Differences in model 
output resulted in a total of 167 units being identified for further 
control.
---------------------------------------------------------------------------

    MANE-VU used model projections to calculate the RPG for the Class I 
areas in the MANE-VU area. Additional modeling details are provided in 
section IV.E.2. The projected improvement in visibility due to emission 
reductions expected by the end of the first period, 2018, is shown in 
Table 2.

[[Page 73964]]

  Table 2--Projected Reasonable Progress Goal and Uniform Rate of Progress for Maine Class I Areas From NESCAUM
                                    2018 Visibility Projections in Deciviews
----------------------------------------------------------------------------------------------------------------
                                                                 2000-2004       2018                  Natural
                                                                 Baseline     Projection     URP     background
----------------------------------------------------------------------------------------------------------------
Acadia National Park................  20% Worst Visibility             22.9          19.4     20.4          12.4
                                       Days.
                                      20% Best Visibility               8.8           8.3  .......           4.7
                                       Days.
Moosehorn National Wildlife Refuge/   20% Worst Visibility             21.7          19.0     19.4          12.0
 Roosevelt Campobello International    Days.
 Park.
                                      20% Best Visibility               9.2           8.6  .......           5.0
                                       Days.
----------------------------------------------------------------------------------------------------------------

    At the time of MANE-VU modeling some of the other States with 
sources potentially impacting visibility, in the Class I areas in both 
Maine and the rest of the MANE-VU domain, had not yet made final 
control determinations for BART, and thus, these controls were not 
included in the modeling prepared by MANE-VU and used by Maine. This 
modeling demonstrates that the 2018 control scenario (2018 projection) 
provides for an improvement in visibility greater than the uniform rate 
of progress for the Maine Class I areas for the most impaired days over 
the period of the implementation plan and ensures no degradation in 
visibility for the least impaired days over the same period.
    The modeling supporting the analysis of these RPGs is consistent 
with EPA guidance prior to the CAIR remand. The regional haze 
provisions specify that a state may not adopt a RPG that represents 
less visibility improvement than is expected to result from other CAA 
requirements during the implementation period. (40 CFR 
51.308(d)(1)(vi)). Therefore, in estimating the RPGs for 2018, many 
States took into account emission reductions anticipated from CAIR. 
MANE-VU initially reduced emissions from highest impacting 167 EGUs by 
ninety percent. However, many of the units targeted for the 90% 
reduction were part of the CAIR program. Since the 90% reduction was 
larger, in total tons of emissions reduced, than the reductions 
expected from CAIR, MANE-VU added the excess emissions back into the 
inventory to account for trading of the emission credits across the 
modeling domain. This way, MANE-VU States would not overestimate the 
emission reductions in case States used the CAIR program as their 
response to the MANE-VU's ``Ask'' of ninety percent reduction from the 
167 EGUs in the eastern United States.
    The RPGs for the Class I areas in Maine are based on modeled 
projections of future conditions that were developed using the best 
available information at the time the analysis was completed. While 
MANE-VU's emission inventory used for modeling included estimates of 
future emission growth, projections can change as additional 
information regarding future conditions becomes available. It would be 
both impractical and resource-intensive to require a state to 
continually adjust the RPG every time an event affecting these future 
projections changed.
    EPA recognized the problems of a rigid requirement to meet a long-
term goal based on modeled projections of future visibility conditions, 
and addressed the uncertainties associated with RPGs in several ways. 
EPA made clear in the RHR that the RPG is not a mandatory standard 
which must be achieved by a particular date. (64 FR at 35733). At the 
same time, EPA established a requirement for a five-year, midcourse 
review and, if necessary, correction of the States' regional haze 
plans. (40 CFR 52.308(g)). In particular, the RHR calls for a five-year 
progress review after submittal of the initial regional haze plan. The 
purpose of this progress review is to assess the effectiveness of 
emission management strategies in meeting the RPG and to provide an 
assessment of whether current implementation strategies are sufficient 
for the state or affected states to meet their RPGs. If a state 
concludes, based on its assessment, that the RPGs for a Class I area 
will not be met, the RHR requires the state to take appropriate action. 
(40 CFR 52.308(h)). The nature of the appropriate action will depend on 
the basis for the state's conclusion that the current strategies are 
insufficient to meet the RPGs. In its SIP submittal, Maine commits to 
the midcourse review and submitting revisions to the regional haze plan 
where necessary.
    EPA is proposing to approve Maine's RPG for the first regional haze 
planning period. Maine has demonstrated that the emission controls in 
the MANE-VU ``Ask''--timely installation of BART Controls, a 90 percent 
reduction in SO2 emissions from EGUs and a low sulfur fuel 
oil strategy are reasonable measures for the reduction of visibility 
impairment as required by EPA's RHR.

D. Best Available Retrofit Technology (BART)

1. Identification of All Bart Eligible Sources
    Determining BART-eligible sources is the first step in the BART 
process. The Maine BART-eligible sources were identified in accordance 
with the methodology in Appendix Y of the Regional Haze Rule, 
Guidelines for BART Determinations Under the Regional Haze Rule, Part 
II, How to Identify BART-Eligible Sources, (70 FR 39104, 39156 (July 6, 
2005)).
    The BART Guidelines requires States to address SO2, 
NOX, and particulate matter. States are allowed to use their 
best judgment in deciding whether VOC or ammonia emissions from a 
source are likely to have an impact on visibility in the area. The 
Maine DEP addressed SO2, NOx, and used particulate matter 
less than 10 microns in diameter (PM10) as an indicator for 
particulate matter to identify BART eligible units, as the Guidelines 
require. Consistent with the Guidelines, the Maine DEP did not evaluate 
emissions of VOCs and ammonia in BART determinations due to the lack of 
impact on visibility in the area due to anthropogenic sources. The 
majority of VOC emissions in Maine are biogenic in nature, especially 
near the Maine Class I areas. Therefore, the ability to further reduce 
total ambient VOC concentrations at Class I areas is limited. Point, 
area, and mobile sources of VOCs in Maine are already comprehensively 
controlled as part of ozone attainment and maintenance strategy. In 
respect to ammonia, the overall ammonia inventory is very uncertain, 
but the amount of anthropogenic emissions at sources that were BART-
eligible is relatively small.
    The identification of BART sources in Maine was undertaken as part 
of a multi-state analysis conducted by the Northeast States for 
Coordinated Air Use Management (NESCAUM). NESCAUM worked with Maine DEP 
licensing engineers to review all sources and determine their BART 
eligibility. Maine DEP identified 10 sources as

[[Page 73965]]

BART-eligible. These sources are shown in Table 3 below.
---------------------------------------------------------------------------

    \10\ On October 1, 2010 and November 8, 2010, Dragon Products, 
LLC submitted documentation asserting that the facility (kiln) 
qualifies as a reconstructed source. After reviewing the 
documentation and conferring with EPA, via a letter dated September 
14, 2011, Maine DEP found the facility meets the criteria of a 
``reconstructed source'' and therefore is not BART eligible.

                                     Table 3--BART-Eligible Sources in Maine
----------------------------------------------------------------------------------------------------------------
                                                                         National
                                                                         emission
                                                                         inventory
             Source and unit                       Location                (NEI)         BART Source category
                                                                      identification
                                                                           code
----------------------------------------------------------------------------------------------------------------
FPLE Wyman Station......................  Yarmouth, ME..............      2300500135  SC 1--Fossil fuel fired
                                                                                       electric plants.
    Boiler 3...................  ..........................            -004
    Boiler 4...................  ..........................            -005
Woodland Pulp, LLC......................  Woodland, ME..............      2302900020  SC 3--Kraft pulp mills.
    Power Boiler 9.............  ..........................            -001
    Lime Kiln...........................  ..........................            -002
Dragon Products \10\....................  Thomaston, ME.............      2301300028  SC 4--Portland cement
                                                                                       plants.
Red Shield Acquisition, LLC.............  Old Town, ME..............      2301900034  SC 3--Kraft pulp mills.
    Recovery Boiler 4..........  ..........................            -002
    Lime Kiln...........................  ..........................            -004
Verso Bucksport.........................  Bucksport, ME.............      2300900004  SC 22--Fossil fuel fired
                                                                                       boilers.
    Boiler 5...................  ..........................            -001
SD Warren...............................  Hinckley, ME..............      2302500027  SC 3--Kraft pulp mills.
    Recovery Boiler.....................  ..........................            -003
    Smelt Tanks 1 and 2.
    Lime Kiln...........................  ..........................            -004
Verso Androscoggin......................  Jay, ME...................      2300700021  SC 3--Kraft pulp mills.
    Power Boiler 1.............  ..........................            -001
    Power Boiler 2.............  ..........................            -002
    Waste Fuel Incinerator..............  ..........................            -003
    Recovery Boilers 1 and       ..........................        -004/005
     2.
    Smelt Tank 1...............  ..........................            -009
    Smelt Tank 2...............  ..........................            -010
    Lime Kiln A.........................  ..........................            -007
    Lime Kiln B.........................  ..........................            -008
    Flash Dryer.........................  ..........................            -018
Katahdin Paper..........................  Millinocket, ME...........      2301900056  SC 22--Fossil fuel fired
                                                                                       boilers.
    Power Boiler 4.............  ..........................            -004
Lincoln Paper and Tissue................  Lincoln, ME...............      2301900023  SC 3--Kraft pulp mills.
    Recovery Boiler 2..........  ..........................            -002
Rumford Paper...........................  Rumford, ME...............      2301700045  SC 3--Kraft pulp mills.
    Power Boiler 5.............  ..........................            -003
----------------------------------------------------------------------------------------------------------------

    The initial list of BART-eligible sources complied by NESCAUM 
included SAPPI Somerset 1 Power Boiler. This unit was 
subsequently determined to not be BART eligible due to a federally 
enforceable permit condition which limits the operation of this unit to 
less than 250 million BTUs per hour heat input. Additionally, boiler 
1 is not considered integral to the Kraft pulp process since 
it only provides steam and power to the facility.
Cap-Outs
    BART applies to sources with the potential to emit 250 tons or more 
per year of any visibility impairing pollutant. (70 FR 39160). BART-
eligible sources that adopt a federally enforceable permit limit to 
permanently limit emissions of visibility impairing pollutants to less 
than 250 tons per year may thereby ``cap-out'' of BART. Three Maine 
sources capped out of BART by taking such limits:

1. Katahdin Paper Company, LLC
2. Rumford Paper Company
3. Verso Bucksport, LLC

    These sources have actual emissions of visibility impairing 
pollutants of less than 250 tons per year, but are BART-eligible 
because their potential emissions exceed the 250 tons per year 
threshold. Pursuant to the requests of these sources, the Maine DEP has 
established federally enforceable permit conditions that limit the 
potential to emit (PTE) of these units to less 250 tons per year for 
all visibility impairing pollutants. As a result, Maine has concluded 
that these sources are not BART eligible.
    Federally enforceable terms and conditions were established for 
each source that limits the PTE for SO2, PM10 and 
NOX to less than 250 TPY. If, in the future, a source 
requests an increase in its PTE above the 250 tons per year threshold 
for a visibility impairing pollutant, then it shall be subject BART 
requirements.
2. Identification of Sources Subject to BART
    Maine, working with MANE-VU, found that every MANE-VU state with 
BART-eligible sources contributes to visibility impairment at one or 
more Class I areas to a significant degree (See the MANE-VU 
Contribution Report). As a result, Maine found that all BART eligible 
sources within Maine are subject to BART. The Maine DEP utilized this 
option for demonstrating its sources are reasonably anticipated to 
cause or contribute to visibility impairment at Class I areas for three 
reasons: (1) The BART sources represent an opportunity to achieve 
greater reasonable progress; (2) additional public health and welfare 
benefits will accrue for the resulting decreases in fine particulate 
matter; and (3) to demonstrate its commitment to federal

[[Page 73966]]

land managers and other RPOs as it seeks the implementation of 
reasonable measures in other States.
    According to Section III of the Guidelines, once the state has 
compiled its list of BART-eligible sources, it needs to determine 
whether to make BART determinations for all of the sources or to 
consider exempting some of them from BART because they may not 
reasonably be anticipated to cause or contribute to any visibility 
impairment in a Class I area.
    Based on the collective importance of BART sources, Maine decided 
that no exemptions would be given for sources; a BART determination 
will be made for each BART-eligible source.\11\
---------------------------------------------------------------------------

    \11\ Maine's decision that all BART eligible sources are subject 
to BART should not be misconstrued to mean that all BART-eligible 
sources must install controls. Maine's approach simply requires the 
consideration of each of the five statutory factors before 
determining whether or not controls are warranted.
---------------------------------------------------------------------------

3. Modeling to Demonstrate Source Visibility Impact
    MANE-VU conducted modeling analyses of BART-eligible sources using 
the EPA approved air quality model, California Pollution Model 
(CALPUFF), in order to provide a regionally-consistent foundation for 
assessing the degree of visibility improvement which could result from 
the installation of BART controls.\12\ While this modeling analysis 
differed slightly from the guidance, it was intended to provide a 
first-order estimate of the maximum visibility benefit that could be 
achieved by eliminating all emissions from a BART source, and provides 
a useful metric for determining which sources are unlikely to warrant 
additional controls to satisfy BART.
---------------------------------------------------------------------------

    \12\ The MANE-VU modeling protocol can be found in the NESCAUM 
``BART Resource Guide,'' dated August 23, 2006, (http://www.nescaum.org/documents/bart-resource-guide/bart-resource-guide-08-23-06-final.pdf/).
---------------------------------------------------------------------------

    The MANE-VU modeling effort analyzed 136 BART-eligible sources in 
the MANE-VU region using the CALPUFF modeling platform and two 
meteorological data sets: (1) A wind field based on National Weather 
Service (NWS) observations; and (2) a wind field based on the 
Pennsylvania State University/National Center for Atmospheric Research 
Mesoscale Meteorological Model (MM5) version 3.6. Modeling results from 
both the NWS and MM5 platforms include each BART eligible unit's 
maximum 24-hr, 8th highest 24-hr, and annual average impact at the 
Class I area. These visibility impacts were modeled relative to the 20 
percent best, 20 percent worst, and average annual natural background 
conditions. In accordance with EPA guidance, which allows the use of 
either estimates of the 20 percent best or the annual average of 
natural background visibility conditions as the basis for calculating 
the deciview difference that individual sources would contribute for 
BART modeling purposes, MANE-VU opted to utilize the more conservative 
best conditions estimates approach because it is more protective of 
visibility.
    The 2002 baseline modeling provides an estimate of the maximum 
improvement in visibility at Class I Areas in the region that could 
result from the installation of BART controls (the maximum improvement 
is equivalent to a ``zero-out'' of emissions). In virtually all cases, 
the installation of BART controls would result in less visibility 
improvement than what is represented by a source's 2002 impact, but 
this approach does provide a consistent means of identifying those 
sources with the greatest contribution to visibility impairment.
    In addition to modeling the maximum potential improvement from 
BART, MANE-VU also determined that 98 percent of the cumulative 
visibility impact from all MANE-VU BART eligible sources which 
corresponds to a maximum 24-hr impact of 0.22 dv from the NWS-driven 
data and 0.29 dv from the MM5 data. As a result, MANE-VU concluded 
that, on the average, a range of 0.2 to 0.3 dv would represent a 
significant impact at MANE-VU Class I areas, and sources having less 
than 0.1 dv impact are unlikely to warrant additional controls under 
BART.\13\
---------------------------------------------------------------------------

    \13\ As an additional demonstration that sources whose impacts 
were below the 0.1 dv level were too small to warrant BART controls, 
the entire MANE-VU population of these units was modeled together to 
examine their cumulative impacts at each Class I area. The results 
of this modeling demonstrated that the maximum 24-hour impact at any 
Class I area of all modeled sources with individual impacts below 
0.1 dv was only a 0.35 dv change relative to the estimated best days 
natural conditions at Acadia National Park. This value is well below 
the 0.5 dv impact used by most RPOs and States for determining 
whether a BART-eligible source contributes to visibility impairment.
---------------------------------------------------------------------------

4. Maine BART Analysis Protocol
    40 CFR 51.308(e)(1)(ii)(A) requires that, for each BART-eligible 
source within the state, any BART determination must be based on an 
analysis of the best system of continuous emission control technology 
available and the associated emission reductions achievable. In 
addition to considering available technologies, this analysis must 
evaluate five specific factors for each source: (1) The costs of 
compliance; (2) the energy and non-air quality environmental impacts of 
compliance; (3) any existing pollution control technology in use at the 
source; (4) the remaining useful life of the source; and (5) the degree 
of visibility improvement which may reasonably be anticipated from the 
use of BART.
    Although Maine did not exempt any BART-eligible sources from a BART 
determination, it did utilize the MANE-VU zero-out modeling as a 
surrogate for estimating the visibility improvement reasonably expected 
from the application of controls. There are eight BART-eligible sources 
with less than 0.1 deciview impact at any Class I area, with impacts 
ranging from 0.01 deciviews to 0.0651 deciviews. These sources are: SD 
Warren smelt tanks 1 and 2; SD Warren lime kiln; 
Verso Androscoggin smelt tank 1 and 2; Verso 
Androscoggin lime kilns A and B; and Verso Androscoggin flash dryer. 
Maine noted that the majority of these units have existing controls in 
place that would likely satisfy the BART requirements. Given this and 
the fact that zero-out modeling shows that the elimination of all 
emissions from these sources would provide only insignificant 
visibility benefits at nearby Class I areas, Maine used a streamline 
approach for the BART determinations for these sources.
5. Source Specific BART Determinations
    The following section discusses the BART determinations for sources 
in Maine.
a. Woodland Pulp LLC (Formerly Domtar Maine, LLC)
i. Background
    The Woodland Pulp facility is a pulp mill, which utilizes the Kraft 
Pulping process and produces market pulp. The Mill also operates 
support facilities including woodyards, wastewater treatment plant, 
sludge press, pulp production labs, environmental labs, finishing, 
shipping, and receiving operations, storage areas, a landfill, and a 
power boiler.
    There are two BART eligible units at the facility; Power boiler 
9 and the lime kiln.
    Power boiler 9 is rated at 625 MMBtu/hr and was placed 
into operation in 1971. Power boiler 9 is fueled primarily by 
biomass but is also licensed to burn 6 fuel oil, sludge, tire 
derived fuel (TDF), specification waste oil, high volume low 
concentration (HVLC) gas, low volume high concentration (LVHC) non-
condensable gas, mill yard waste, oily rags, stripper off-gas, and 
propane. Emissions are controlled using a variable-throat wet

[[Page 73967]]

venturi scrubber and low-NOX burners (LNBs). The lime kiln 
is rated at 75 MMBtu/hr and was placed into operation in 1966. 
Emissions are controlled using a variable-throat wet venturi scrubber 
and a Ceilcote cross-flow scrubber. The lime kiln is fueled by 
6 fuel oil.
ii. Power Boiler 9
    (1) PM BART Review: Maine evaluated the use of fabric filters, wet 
electrostatic precipitator (WESP), dry electrostatic precipitator 
(DESP), and wet scrubbers to control PM at power boiler 9. 
Fabric filters were found not technically feasible due to fire risk 
from combustible fly-ash, while WESP is not technically feasible due to 
operational difficulties with multi-fuel boilers. A DESP could not be 
installed post-scrubber due to excess moisture levels in the exhaust 
stream, but could be installed upstream. An upstream DESP was evaluated 
and found to provide a 98-99% control efficiency for biomass and a 90% 
efficiency for oil for PM. For comparison, a wet scrubber provides an 
85-98% control efficiency for PM. Maine estimated the cost for DESP 
installation at $4,640 per ton of PM removed. Maine concluded that the 
addition of DESP with the existing wet venturi scrubber is not a cost-
effective option and determined that current controls represent BART 
for PM for power boiler 9.
    (2) SO2 BART Review: Power boiler 9 is currently 
controlled through the use of a wet scrubber. In addition, the boiler 
is fueled primarily by biomass, a naturally low sulfur fuel. Maine 
concluded that the combination of a wet scrubber in use with primarily 
biomass is the maximum level of control available for this type of 
unit. Maine determined that current controls represent BART.
    (3) NOX BART Review: Maine identified a number of potential 
NOX control strategies for use on power boiler 9, 
including NOX tempering, flue gas recirculation (FGR), 
selective non-catalytic reduction (SNCR), selective catalytic reduction 
(SCR), LNBs and good combustion practices. The State found that several 
potential NOX controls were technically infeasible and did 
not warrant further investigation. Maine concluded that NOX 
tempering is not technically feasible due to reduced thermal efficiency 
and that SCR is not technically feasible due to the increased frequency 
of catalyst fouling from multi-fuel boilers. FGR was determined to be 
not technically feasible based on previous failed FGR trials conducted 
on power boiler 9. SNCR, with a 30-40% control efficiency, and 
LNBs, with 10% control efficiency, were identified as technically 
feasible control strategies. Maine estimated the cost-effectiveness of 
SNCR at $7,360 per ton and noted that SNCR has a reduced effectiveness 
on boilers with significant load swings (such as the Power Boiler 
9). Given the low cost-effectiveness of SNCR, Maine determined 
the continued use of LNBs represent BART for the power boiler 
9.
iii. Lime Kiln
    (1) PM BART Review: The lime kiln is subject to the Maximum 
Available Control Technology (MACT) standard for PM found in 40 CFR 
Part 63, Subpart MM. The BART Guidelines state that for sources subject 
to a MACT standard, ``[u]nless there are new technologies subsequent to 
the MACT standards which would lead to cost-effective increases in the 
level of control, you may rely on the MACT standards for purposes of 
BART.'' (50 FR 39164, (July 6, 2005)) Maine determined that there are 
no new technologies for control of this source and therefore that 
compliance with MACT therefore represents BART for the lime kiln.
    (2) SO2 BART Review: Maine identified the use of a wet scrubber and 
in-process capture as feasible technologies for the control of 
SO2 from the lime kiln. Both technologies are currently 
employed by Woodland Pulp (including two wet scrubbers). Therefore, 
current controls were determined to be BART.
    (3) NOX BART Review: A number of potential NOX control 
strategies were identified for the lime kiln, including: SNCR, SCR, 
non-selective catalytic reduction (NSCR), FGR, LNBs, and good 
combustion practices. Maine determined the impracticality of installing 
chemical injection nozzles inside a rotating kiln drum makes SNCR 
technically infeasible. Maine also concluded that SCR and NSCR are not 
feasible due to the known presence of catalyst fouling substances in 
the lime kiln. The State found that FGR is not feasible as it reduces 
the temperature in the flame zone, thus hindering the chemical reaction 
taking place in the lime kiln. The State also concluded that LNBs are a 
non-demonstrated technology and are not listed in the EPA BACT/RACT/
LEAR Clearinghouse for lime kiln emissions control. Maine concluded 
that good combustion practices are the only feasible option for 
controlling NOX which is already employed at the lime kiln. 
Therefore, current controls were determined to represent BART for the 
lime kiln.
iv. EPA Assessment
    EPA finds that Maine's analyses and conclusions for the BART 
emission units located at the Woodland Pulp LLC facility are 
reasonable. EPA has reviewed the Maine analyses and concluded they were 
conducted in a manner consistent with EPA's BART Guidelines.
b. FPL Energy Wyman, LLC
i. Background
    FPL Energy Wyman is an 850-megawatt electric generating facility 
located on Cousins Island in Yarmouth, Maine. The plant consists of 
four generation units, all of which fire 6 residual fuel oil. 
A fifth unit is a smaller oil-fired auxiliary boiler which provides 
building heat and auxiliary steam and a sixth unit is an emergency 
backup diesel generator that provides electricity for use on-site. 
There are two BART eligible units at the facility--boiler 3 
and boiler 4.
    Boiler 3 is a Combustion Engineering boiler, installed in 
1963, with a maximum design heat input capacity of 1,190 MMBtu/hr 
firing 6 fuel oil (with 2.0% sulfur content by weight). The 
boiler is equipped with multiple centrifugal cyclones for control of 
particulate matter and optimization and combustion controls for 
NOX. Boiler 4 is a Foster Wheeler boiler, installed 
in 1975, with a maximum design heat input capacity of 6,290 MMBtu/hr 
firing 2 or 6 fuel oil (with 0.7% sulfur). The boiler 
is equipped with an electrostatic precipitator for control of 
particulate matter and optimization and combustion controls for 
NOX.
ii. Boilers 3 and 4
    (1) PM BART Review: Emissions of PM from oil fired boilers are a 
function of the efficiency of the fuel firing.\14\ Both boilers 
3 and 4 have high efficiency combustion systems in 
conjunction with PM control devices. Boiler 3 has a Multiclone 
dust collectors. Boiler 4 has an ESP, the most stringent 
control available. The cost analysis of installing an ESP on boiler 
3 resulted in a pollutant removal cost effectiveness of 
$19,000/ton of PM removed and a visibility improvement cost 
effectiveness of $143 million per deciview of visibility improvement. 
This was determined to be not cost-

[[Page 73968]]

effective. Therefore, Maine determined that current controls on boiler 
3 represent BART. Maine determined the ESP on boiler 
4 represents BART because it is the most stringent control 
available.
---------------------------------------------------------------------------

    \14\ It is estimated from the MANE-VU August 2006 document 
Contributions to Regional Haze in the Northeast and Mid-Atlantic 
United States, Tools and Techniques for Apportioning Fine Particle/
Visibility Impairment in MANE-VU (pages 3-2, 4-7, 4-8) that coarse 
particulate matter is responsible for typically less than 4% of the 
contribution to visibility impairment at the MANE-VU Class I areas.
---------------------------------------------------------------------------

    (2) SO2 BART Review: Emissions of SO2 from oil fired 
boilers are related to the sulfur in the fuel. Maine identified the 
following available retrofit control technologies for reducing 
SO2 emissions from boilers 3 and 4: Low 
sulfur 2 fuel oil, reduced sulfur 6 fuel oil, and wet 
or dry scrubbers. The use of low sulfur 2 fuel oil (0.05% down 
to 0.0015% sulfur by weight) and reduced sulfur 6 fuel oil (1% 
or less sulfur by weight) were considered technically feasible options. 
The application of post combustion controls of wet or dry scrubbers on 
large, oil-fired boilers was researched by Maine. The state found that, 
generally such controls were typically applied only to coal-fired 
boilers. As a general matter, the use of scrubbers on oil-fired boilers 
is considered cost prohibitive. As a result, Maine did not consider wet 
or dry scrubbers as a BART option.
    Maine performed a cost analysis on lowering the sulfur content in 
the fuel used in both boilers. Boiler 3 currently fires 2% 
sulfur by weight oil and boiler 4 currently fires 0.7% sulfur 
by weight oil. The annual costs were calculated to be the following 
(based on the differential fuel costs):

         Table 4--SO2 Control Costs Analysis for Wyman #3 and #4
------------------------------------------------------------------------
               Boiler 3                    Boiler 4
------------------------------------------------------------------------
                                      Annual                    Annual
             % Sulfur               costs (in     % Sulfur    costs (in
                                    millions)                 millions)
------------------------------------------------------------------------
1.0..............................        $0.68  ...........  ...........
0.7..............................         0.80  ...........  ...........
0.5..............................          3.2          0.5         $9.2
0.3..............................          5.7          0.3         18.3
------------------------------------------------------------------------

    Maine also estimated the visibility cost effectiveness, incremental 
visibility improvement, and incremental visibility cost effectiveness 
from switching from 2% sulfur by weight to reduced sulfur content fuel 
oil for boiler 3. In estimating these values, Maine used the 
cumulative visibility benefits at several of the nearest Class I areas 
on the highest impacting visibility day. Maine estimated the following:

                           Table 5--SO2 Control Visibility Analysis for Wyman Unit #3
----------------------------------------------------------------------------------------------------------------
                                                                                                    Incremental
                                                                    Visibility                      visibility
                                                                       cost         Incremental        cost
                            % Sulfur                               effectiveness    visibility     effectiveness
                                                                   ($/deciview)     improvement    ($/deciview)
                                                                   (in millions)                   (in millions)
----------------------------------------------------------------------------------------------------------------
1.0.............................................................           $0.69  ..............  ..............
0.7.............................................................            0.56         0.44 dv           $0.27
0.5.............................................................            1.82         0.35 dv            6.97
0.3.............................................................            2.64         0.37 dv            6.59
----------------------------------------------------------------------------------------------------------------

    The visibility cost effectiveness, incremental visibility 
improvement, and incremental visibility cost effectiveness from 
switching from 0.7% sulfur to reduced sulfur content fuel oil for 
boiler 4 was the following:

                           Table 6--SO2 Control Visibility Analysis for Wyman Unit #4
----------------------------------------------------------------------------------------------------------------
                                                                                                    Incremental
                                                                    Visibility                      visibility
                                                                       cost         Incremental        cost
                            % Sulfur                               effectiveness    visibility     effectiveness
                                                                   ($/deciview)     improvement    ($/deciview)
                                                                   (in millions)                   (in millions)
----------------------------------------------------------------------------------------------------------------
0.5.............................................................           $22.3  ..............  ..............
0.3.............................................................            19.5         0.53 dv           $17.3
----------------------------------------------------------------------------------------------------------------

    Based on the information above, Maine determined 0.7% sulfur by 
weight fuel oil for boiler 3 beginning in 2013, and the 
current limit of 0.7% sulfur by weight fuel oil for boiler 4 
represents BART for these units.
    (3) NOX BART Review: In order to meet the ozone National Ambient 
Air Quality Standard (NAAQS) requirement, FPL Energy Wyman installed 
combustion control technologies pursuant to Maine's Chapter 145, NOX 
Control Program Regulation. FPL Energy Wyman installed combustion 
control technology upgrades, including low NOX fuel 
atomizers, improved swirler design, and overfire and interstage air 
ports. The burners were optimized and fuel/air flows were balanced to 
the burners on each unit. The combustion control technology upgrades 
were completed in April 2003 and reductions in NOX emissions 
of 29-35% have been documented with boiler 3 and reductions of 
24-47% have been documented with boiler 4 depending on each 
unit's load. These reductions are equivalent to the reductions that

[[Page 73969]]

could be achieved through the use of SNCR on the boilers.
    The cost analysis of installing additional NOX controls 
of regenerative selective catalytic reduction (RSCR) on the boilers in 
addition to the current combustion controls resulted in a pollutant 
removal cost effectiveness of $125,000/ton and $83,000/ton of 
NOX removed for boiler 3 and boiler 4, 
respectively. Maine concluded that such controls are not cost 
effective. Therefore, Maine determined the current combustion controls 
represent BART for these units.
iii. EPA Assessment
    EPA finds that Maine's analyses and conclusions for the BART 
emission units located at the FPL Energy Wyman, LLC facility are 
reasonable. Although EPA does not generally recommend that States rely 
solely on $/deciview consideration in making BART determinations, EPA 
does not believe that broader analysis of the costs and visibility 
benefits associated with changing the sulfur content of the fuel used 
in boiler 3 and 4 would have resulted in a different 
BART determination in this case. EPA has reviewed the remaining Maine 
analyses for FPL Energy Wyman, LLC and concluded they were conducted in 
a manner consistent with EPA's BART Guidelines.
c. Lincoln Paper and Tissue, LLC
i. Background
    Lincoln Paper & Tissue (LPT) is an integrated Kraft pulp and paper 
mill. Currently, LPT operates a hardwood digester and a softwood 
sawdust digester to produce pulp with approximately 50% recycled 
content. LPT uses one recovery boiler and a lime kiln in the recaust 
process for reclamation of the pulping chemicals. Also, LPT has three 
oil-fired boilers and one multi-fuel boiler to supply the mill with 
steam. The two paper machines produce specialty paper and the two 
tissue machines produce multi-ply dyed tissue. The pulp dryer machine 
produces bailed pulp which is either used by LPT or sold to other paper 
manufacturers.
    At LPT, the only BART-eligible source is the recovery boiler 
2, which is used to recover the pulping chemicals and produce 
steam. Emissions exit through two identical 175 foot stacks.
    The recovery boiler is a straight fire unit burning black liquor, 
typically without combustion support from fossil fuel. Normally, oil is 
used only during start-ups and shutdowns and to stabilize operation of 
the boiler. Recovery boiler 2 is exhausted to an ESP to 
control particulate emissions. This unit also serves to re-introduce 
salt cake into the black liquor which further concentrates the solids 
content.
ii. Recovery Boiler 2
    (1) PM BART Review: PM emissions are currently controlled with the 
ESP to levels meeting compliance with MACT standards (40 CFR Part 63, 
Subpart MM). Since the unit is meeting the MACT standard, Maine 
determined that these controls represent BART.
    (2) SO2 and NOX BART Review: SO2 and NOX 
emissions are controlled by proper operation of the recovery boiler, 
including a three-level staged combustion air control system, and 
limitations on fuel oil use and the sulfur content. As no new control 
technologies are available for further control of these pollutants from 
a recovery boiler, current controls constitute BART for this unit.
iii. EPA Assessment
    EPA finds that Maine's analyses and conclusions for the BART 
emission unit located at the Lincoln Paper and Tissue, LLC facility are 
reasonable. EPA has reviewed the Maine analyses and concluded they were 
conducted in a manner consistent with EPA's BART Guidelines. Current 
NOX and SO2 emission limits are federally 
enforceable via the Maine Air License A-177-71-A/R issued under Maine's 
EPA approved Prevention of Significant Deterioration program.
d. SD Warren Company, Somerset
i. Background
    SD Warren Company (SDW) is an integrated Kraft pulp and paper mill. 
Whole logs, chips, and other biomass, are delivered to the mill by 
truck and/or train. The logs are sawn, debarked, chipped and stored in 
the mill's woodyard. The biomass is stored in piles and then conveyed 
to the boilers. The chips are stored in piles and then conveyed to the 
chip bin, chip steaming vessel, and then the digester. SDW operates one 
Kamyr continuous digester to produce pulp (hardwood, softwood, or any 
combination thereof), one recovery boiler and one lime kiln in the 
recaust process for reclamation of the pulping chemicals. There are two 
multi-fuel boilers and an oil fired package boiler to supply the mill 
with steam. SDW has three paper machines which produce paper. There are 
also two pulp machines. One pulp machine has a steam operated dryer and 
both machines produce bailed pulp. The mill also operates support 
facilities, including the wood yard, wastewater treatment plant, sludge 
presses, pulp and paper production labs, environmental labs, roll 
wrapping, shipping and receiving operations, and a landfill.
    There are four emissions units that were determined to be BART 
eligible at this facility: the recovery boiler, smelt tanks 1 
and 2, and the lime kiln.
ii. Recovery Boiler
    The recovery boiler was installed in 1975-1976. It is used to 
recover chemicals from spent pulping liquors and to produce steam for 
mill operations. The recovery boiler is licensed to fire black liquor 
(spent pulping liquor), residual (6) fuel oil, distillate 
(2) fuel oil, and used oil. The recovery boiler is also 
licensed to combust low volume-high concentration (LVHC) and high 
volume-low concentration (HVLC) gases produced at various points in the 
pulping process. The licensed maximum black liquor firing rate is 5.5 
million pounds per day of BLS. The recovery boiler is subject to MACT 
standards for Chemical Recovery Combustion Sources at Kraft Soda, 
Sulfite, and Stand-Alone Semichemical Pulp Mills (40 CFR Part 63, 
Subpart MM).
    (1) PM BART Review: SDW currently operates a three-chamber 
electrostatic precipitator on the recovery boiler. Maine identified the 
following available retrofit technologies for control of PM from Kraft 
mill recovery boilers: Electrostatic precipitators, wet scrubbers, and 
fabric filters. Wet scrubbers were eliminated as a feasible control 
strategy because the ESP currently installed is capable of a greater 
degree of emissions control at a lower operating cost. Fabric filters 
are generally considered to be equivalent to ESPs in regards to 
pollution control; however, fabric filters have not been applied to 
recovery boilers at Kraft mills. Maine therefore eliminated fabric 
filters as a feasible control alternative and concluded that the 
current control, specifically operation of the ESP, represents BART for 
this unit.
    (2) SO2 BART Review: SDW's recovery boiler is currently equipped 
with a four-level staged combustion air system. SDW identified staged 
combustion systems and wet scrubbers as available retrofit technologies 
for control of SO2 from Kraft mill recovery boilers. 
SO2 emissions from recovery boilers occur due to the 
volatilization and subsequent oxidation of sulfur compounds that are 
present in the black liquor. Proper operation of the recovery boiler 
maximizes the conversion of sulfur compounds in the liquor to the 
principal constituents of the pulping chemicals. This occurs through 
capture

[[Page 73970]]

of these sulfur compounds in the combustion zone of the boiler by 
sodium fume released from the smelt bed. Consequently, proper 
combustion control achieved through the use of staged combustion air 
systems results in effective control of SO2 emissions. The 
only available alternative for SO2 emission control is a wet 
scrubber. However, recovery boilers with a properly operated staged air 
combustion system operate at much lower concentrations of 
SO2 in the flue gas than emission units to which wet 
scrubbers are routinely applied. Given the already low SO2 
levels, the installation and use of a scrubber would be prohibitively 
expensive. The maximum modeled visibility impairment from this unit due 
to SO2 is 0.02 dv. Maine determined therefore that current 
control represents BART for this unit.
    (3) NOX BART Review: SDW's recovery boiler is upgraded to a four-
level staged combustion air system. Maine identified the following 
available retrofit technologies for control of NOX from 
Kraft mill recovery boilers: Staged combustion systems, SNCR, SCR, 
LNBs, Flue Gas Recirculation, and Low-Temperature Oxidation. Emission 
controls which have been demonstrated on conventional steam boilers, 
including SNCR, SCR, FGR, and LNBs have not been demonstrated to be 
feasible on Kraft mill recovery boilers. There has been some small-
scale work done on ``low-temperature oxidation'' where pure oxygen is 
injected into the evaporation process to drive ammonia from the black 
liquor. However, the company currently looking into this technology has 
advised Maine that they are not aware of any commercial size units 
where this technology has been used. Maine did not consider this 
technology to be technically feasible. Maine concluded that there are 
no technically feasible alternatives for control of NOX 
emissions from recovery boilers other than proper operation of the 
boiler and the staged combustion control system. Since the controls 
already in place are considered the most stringent available, Maine 
determined that these controls represent BART for this unit.
iii. Smelt Tanks 1 and 2
    SDW operates two smelt tanks which were installed in 1975-1976. The 
smelt tanks operate in conjunction with the recovery boiler. Recovered 
sodium-based pulping chemicals, in the form of molten salts, are 
discharged from the bottom of the recovery boiler into the smelt tanks, 
where they are mixed with a water/caustic solution to form green 
liquor. The smelt tanks are subject to MACT standards (40 CFR Part 63, 
Subpart MM).
    (1) PM BART Review: SDW currently operates a wetted fan scrubber on 
each of the smelt tanks for control of particulate emissions. The 
scrubbing media for the scrubbers is either water or weak wash from the 
white liquor clarification system. Maine identified the following 
potential retrofit technologies for control of PM from smelt tanks: 
ESPs, wet scrubbers, fabric filters, and mist eliminators. The most 
common PM emission control system employed on smelt tanks is wet 
scrubbers. The use of wet scrubbers also provides a secondary 
environmental benefit by controlling reduced sulfur compound emissions. 
The high moisture content of the smelt tank exhaust gases makes dry PM 
control systems, including fabric filters and dry ESPs, technically 
infeasible on this type of emission unit. The only remaining control 
technology, mist eliminators, provides a lower degree of PM emission 
control than the use of wet scrubbers. Therefore, Maine determined that 
the current operation of the wet scrubbers represents BART for these 
units.
    (2) SO2 BART Review: Since no combustion takes place within smelt 
tanks, SO2 is not generated within the emission unit. Maine 
has found that SO2 emissions from the smelt tanks are 
dependent on how much sulfur carries over from the respective recovery 
boilers with the smelt. SO2 emissions from both smelt 
dissolving tanks combined are very low at approximately 10.5 tons per 
year, primarily because the wet scrubber used for PM control also 
reduces SO2 emissions. Maine determined that BART for 
SO2 emissions from smelt tanks 1 and 2 is 
no additional control based on the following: (1) SO2 
emissions from the smelt dissolving tanks during the BART baseline 
period were, and are expected to continue to be, extremely low (~10.5 
TPY, combined); (2) the smelt dissolving tanks and associated scrubbers 
are designed and operated to minimize SO2 emissions; (3) 
SO2 emissions from the smelt dissolving tanks have a minimal 
impact on visibility (2 emissions from the smelt dissolving tanks would have a 
minimal impact on overall visibility. Therefore, Maine determined that 
current controls represent BART for these units.
    (3) NOX BART Review: Since no combustion takes place within smelt 
tanks, NOX is not generated within the emission unit. 
Therefore, Maine determined that current controls represent BART for 
these units.
iv. Lime Kiln
    The lime kiln was installed in 1975-1976. It is used to convert 
lime mud (principally calcium carbonate) to lime (calcium oxide). Fuel 
is fired in the lime kiln to generate the heat that is needed to 
convert lime mud to lime. The lime kiln is licensed to fire residual 
(6) fuel oil, distillate (2) fuel oil, used oil, and 
propane. The lime kiln is also licensed to combust LVHC gases and foul 
condensate streams.
    (1) PM BART Review: Particulate emissions from the lime kiln are 
currently controlled by a variable throat venturi scrubber system 
followed by a cyclone separator. Maine identified the following 
available retrofit technologies for control of PM from lime kilns: 
Electrostatic precipitators, wet scrubbers, and fabric filters. Fabric 
filters have never been applied to Kraft pulp mill lime kilns. They are 
generally deemed to be technically infeasible on lime kilns. ESPs 
provide a greater degree of particulate matter control than venturi 
scrubbers. However, the possible annual reduction in emissions to be 
gained by replacing the existing scrubber with an ESP is relatively 
small (estimated at under 40 tons/year). Additionally, the scrubber 
also helps control emissions of SO2 and reduced sulfur 
compounds. This beneficial removal of other pollutants is not available 
to lime kilns equipped with ESPs. Consequently, replacement of the 
existing scrubber with an ESP would be expected to result in higher 
Total Reduced Sulfur (TRS) and SO2 emissions from the lime 
kiln. Furthermore, any potential improvement in visibility impacts 
associated with retrofitting an ESP on the lime kiln, the modeling 
result for current PM emissions from the Lime Kiln was 0.0463 dv; well 
below the State's de minimis level of 0.1 dv. Therefore, Maine 
determined that the current operation of the scrubber represents BART 
for the lime kiln.
    (2) SO2 BART Review: SO2 forms in the lime kiln from 
either the combustion of sulfur in the fuel or combustion of TRS 
compounds in the LVHC gases. Currently, emissions of SO2 are 
controlled by using a combination of the inherent sulfur removal 
provided by operation of the kiln itself (i.e. extensive contact 
between burner exhaust gases and the calcium compounds in the kiln) 
enhanced through the use of a venturi wet scrubber (post-combustion). 
SDW also uses a caustic scrubber (pre-combustion) on the LVHC gases 
fired in the boiler. Firing of LVHC gases in the

[[Page 73971]]

lime kiln without pre-treatment with the caustic scrubber causes 
formation of rings within the lime kiln leading to excessive down-time 
of the equipment. Emissions of SO2 from the lime kiln can 
vary significantly based on the amount of LVHC gases being fired and 
whether or not the caustic scrubber is in operation. Maine identified 
the following available retrofit technologies for control of 
SO2 from lime kilns: Lime kiln operation and wet scrubbers. 
Since these controls are already in place, Maine determined that 
current controls represent BART for this unit.
    (3) NOX BART Review: NOX emissions from the lime kiln 
are currently controlled by good combustion controls and operation of 
the unit's combustion air system. The maximum modeled visibility 
impairment on a Class I area is 0.06 dv. Maine identified the following 
potential retrofit technologies for control of NOX from lime 
kilns: Combustion Air Systems controls, SNCR, SCR, LNBs, and FGR. 
However, Maine's analysis concluded there are no technically feasible 
alternatives for control of NOX from lime kilns beyond the 
measures currently employed. LNBs negatively impact the efficiency, 
energy use, and calcining capacity of a lime kiln. Post combustion 
controls, such as SCR and SNCR, are not feasible for lime kilns. The 
temperature window necessary for the SNCR process (1500-2000 [deg]F) is 
unavailable in a Kraft lime kiln. The high PM load at the exit of the 
kiln precludes the placement of the catalyst grid needed for the SCR 
process upstream of the PM control device, and the requisite 
temperature window required for this process (550-750 [deg]F) is not 
available downstream of the PM control system. Therefore, Maine 
determined that current controls represent BART for this unit.
v. EPA Assessment
    EPA finds that Maine's analyses and conclusions for the BART 
emission units located at the SD Warrant Company, Somerset facility are 
reasonable. EPA has reviewed the Maine analyses and concluded they were 
conducted in a manner consistent with EPA's BART Guidelines.
e. Verso Androscoggin
i. Background
    The Verso Androscoggin pulp mill in Jay, Maine, produces bleached 
Kraft pulp and groundwood pulp. The bleached pulp is produced in two 
separate process lines, designated ``A'' and ``B.'' Groundwood pulp is 
produced in another separate process line. Logs and wood chips are 
received in the Woodyard area, where they are stored and processed for 
eventual use in the Pulp Mill or Groundwood Mill. The Pulp Mill 
consists of two separate, parallel Kraft chemical pulping process 
lines. Pulp produced at the Verso Jay Mill is either used in the paper 
mill area or dried in the Flash Dryer for storage and/or sale.
    The Paper Mill consists of all the equipment and operations used to 
convert pulp to paper, including stock preparation, additive 
preparation, coating preparation, starch handling, finishing, storage, 
and paper machines. Non-condensable gases (NCGs) collected throughout 
the process from certain units in the Pulp Mill are sent to the lime 
kilns for combustion. The HVLC emission streams from certain other 
units are collected and sent to the Regenerative Thermal Oxidizer where 
they are incinerated. The Mill produces steam and electric power for 
mill operations with power boilers 1 and 2 and the 
waste fuel incinerator (WFI).
    There are ten BART-eligible units at Verso Jay: (1) Power boiler 
1; (2) power boiler 2; (3) waste fuel incinerator; 
(4) recovery boiler  1; (5) recovery boiler 2; (6) 
smelt tank 1; (7) smelt tank 2; (8) lime kiln A; (9) 
lime kiln B; and (10) flash dryer.
ii. Power Boilers 1 and 2
    Power boilers 1 and 2 are each rated at 680 
MMBtu/hr and began operation in 1965 and 1967, respectively. Power 
boilers 1 and 2 are licensed to fire 6 fuel 
oil, 2 fuel oil, and used oil. The license currently limits 
the sulfur content of the fuel oil to no more than 1.8%, by weight. In 
addition, each boiler is equipped with LNBs. The operation of the two 
boilers is related to whether or not and how the cogeneration plant 
(three natural gas fired turbines) at the Mill is operating. Typically, 
when the cogeneration plant is operating, power boilers 1 and 
2 do not operate. When the cogeneration plant is not 
operating, both boilers are operated; however, one boiler will 
typically carry the bulk of the load and the other boiler will be idled 
or run at a low load. There are occasions when both boilers operate at 
high load but this is not a routine operating mode.
    (1) PM BART Review: Maine found that PM10 emissions from 
power boilers 1 and 2 are low and have minimal impact 
on visibility. The maximum modeled visibility impact on a Class I area 
due to PM10 is 0.03 dv. As the boilers are subject to the 
final ``Boiler MACT'' standards (40 CFR Part 63, Subpart DDDDD) 
promulgated in 2011, Maine did not further consider additional controls 
in its BART analysis and determined that compliance with these 
standards represents BART for power boilers 1 and 2.
    (2) SO2 BART Review: Maine identified and evaluated low sulfur 
fuels, wet scrubbing, dry scrubbing, and semi-dry scrubbing as 
potential control technologies in the reduction of SO2 
emissions from power boilers 1 and 2. Dry and semi-
dry scrubbing control technologies were evaluated; however, the control 
effectiveness levels would be low (or fabric filter would need to be 
installed to collect and re-circulate the scrubbing material, and no 
applications of these technologies on fuel oil fired boilers like power 
boilers 1 and 2 were identified during research of 
potential control technologies. Low sulfur fuels and wet scrubbing 
control technologies were found to be technically feasible and were 
evaluated further. Switching to natural gas, 2 fuel oil, and 
wet scrubbing were estimated to cost between $2,200 and $3,300 per ton 
SO2 removed with a visibility improvement of 1.5 dv. 
Switching to 0.7% sulfur 6 fuel oil was estimated to cost $631 
per ton SO2 removed with a visibility improvement of 0.9 dv.
    The cost effectiveness numbers above are based on the highest 
estimated two year average of annual emissions between 2002 and 2008. 
In recent years (2008 and 2009) these boilers have been operating close 
to only 20% of the time. This would result in an actual cost 
effectiveness for wet scrubbing of between $4,920 and $7,133 per ton of 
SO2 removed. The use of low sulfur fuels or a wet scrubber 
has the potential to reduce visibility impacts from power boilers 
1 and 2 by a perceptible amount; however, there are 
significant cost differences among the three low sulfur containing 
fuels evaluated by Maine and the wet scrubber. Maine concluded that the 
use of 0.7% sulfur by weight 6 fuel oil is a feasible and 
justifiable cost at $631 per ton of SO2 reduced. The 
incremental cost of switching to natural gas from 0.7% sulfur by weight 
6 fuel oil is $7,492 per ton and the incremental cost of 
switching to wet scrubbing from 0.7% sulfur by weight 6 fuel 
is $4,811 per ton. Maine determined that these costs were not 
justifiable for an additional 0.6 dv improvement. In addition, Maine's 
low sulfur legislation will require the facility to use 0.5% sulfur by 
weight 6 oil by 2018. At that time, the price of the 0.5% 
sulfur by weight oil will be reduced due to increased supply to the 
State. Therefore, Maine determined that the use of lower sulfur (0.7% 
sulfur by weight) 6 fuel oil in place of the higher

[[Page 73972]]

sulfur (1.8% sulfur by weight) 6 fuel oil currently fired, 
represents BART for control of SO2 emissions from power 
boilers 1 and 2.
    (3) NOX BART Review: Maine identified and evaluated SCR, LNB, SNCR, 
and combustion control methods (including an overfire air (OFA) system 
and a flue gas recirculation (FGR) system) as potential control 
technologies for the reduction of NOX emissions from power 
boilers 1 and 2. SCR and SNCR control technologies 
were found to be technically feasible and were evaluated further. LNBs 
are currently installed and used on power boilers 1 and 
2, and are estimated to provide a 15% reduction in 
NOX emissions, so were not evaluated further. Combustion 
control methods were evaluated; however, none were found to be viable 
control options for power boilers 1 and 2. Maine 
found that the size and design of power boilers 1 and 
2 would provide little room for the installation of an 
overfire air system and that the application of a flue gas 
recirculation system would result in minimal reductions (7% to 15%) in 
NOX emissions. The cost effectiveness of SCR is $5,271 per 
ton NOX removed with a visibility improvement of 1.7 dv. The 
cost effectiveness of SNCR is $5,973 per ton NOX removed for 
a visibility improvement of 1.4 dv.
    The cost effectiveness numbers presented above are based on 
controlling NOX emissions from power boilers 1 and 
2 from the highest estimated two-year average annual emissions 
between 2002 and 2008. In recent years (2008 and 2009) these boilers 
have been operating close to only 20% of the time, which for example, 
would result in an actual cost effectiveness of $16,313 per ton of 
NOX removed with the installation of SCR. Although the use 
of SCR or SNCR has the potential to reduce visibility impacts by a 
perceptible amount, Maine concluded that the cost effectiveness levels 
are not economically justifiable based on the limited use of power 
boilers 1 and 2 in recent years. Therefore, Maine 
determined that the current use of LNBs represents BART for control of 
NOX emissions from power boilers 1 and 2 
and that no additional level of control is justifiable as BART.
iii. Waste Fuel Incinerator Boiler
    The waste fuel incinerator (WFI) is rated at 480 MMBtu/hr on 
biomass and 240 MMBtu/hr on oil and began operation in 1976. While the 
WFI primarily fires biomass, fuel oils (6 and 2 fuel 
oils, waste oil, and oily rags) can also be fired in the boiler. Sulfur 
dioxide and particulate matter emissions are controlled using a 
variable throat venturi scrubber and demister arrangement. When 
6 fuel oil is fired in significant amounts, caustic is used in 
the wet scrubber to meet the applicable SO2 emission limit. 
In addition, the WFI is equipped with a combustion system designed to 
ensure the optimal balance between control of NOX and 
limitation of CO and VOC.
    (1) PM BART Review: The maximum modeled visibility impact due to 
PM10 from the WFI is 0.06 dv. The WFI is subject to EPA's 
``Boiler MACT'' standards (40 CFR Part 63, Subpart DDDDD). Maine 
determined that current controls represent BART.
    (2) SO2 Bart Review: Maine identified and evaluated low sulfur 
fuels, wet scrubbing, dry scrubbing, and semi-dry scrubbing as 
potential control technologies in the reduction of SO2 
emissions from the WFI. While using low sulfur fuels is technically 
feasible, Maine believes that it is not a practically feasible option 
for the WFI based on the limited amount of fuel oil typically used in 
the boiler (less than 10% of the annual fuel oil heat input capacity). 
The WFI currently uses a water based wet scrubbing system for PM 
control with the addition of caustic to meet SO2 emission 
limits when firing 6 fuel oil in significant amounts. Dry and 
semi-dry scrubbing control technologies were not considered by Maine to 
be either practical or technically feasible for the WFI due to the fact 
that they could not find any applications of these technologies on any 
other biomass-fired grate type boilers like the WFI. Maine also states 
that removing the existing wet scrubber and replacing it with a dry or 
semi-dry scrubbing system and a new ESP and/or fabric filter would be 
costly. The only remaining viable SO2 control technology 
(adding caustic to the existing wet scrubbing system) has a cost 
effectiveness of $21,800 per ton SO2 removed with an 
expected visibility improvement of less than 0.01 dv.
    The WFI has very low baseline SO2 emissions (~50 tons 
per year) and a maximum modeled SO2 visibility impact of 
less than 0.01 dv, due to the inherent low sulfur content and 
alkalinity of the primary fuel (biomass) and the small amount of fuel 
oil used in the WFI. In addition, during the limited amount of time 
that 6 fuel oil is used to provide a significant portion of 
the heat input to the WFI, caustic is added to the wet scrubber to 
control SO2 emissions. Therefore, Maine determined that 
additional control of SO2 emissions from the WFI cannot be 
justified as BART due to the imperceptible effect it would have on 
visibility. Maine concluded that current controls represent BART for 
this unit.
    (3) NOX BART Review: Maine identified and evaluated SCR, LNB, SNCR, 
and combustion control methods (including an overfire air system and 
FGR) as potential control technologies in the reduction of 
NOX emissions from the WFI. SCR and SNCR control 
technologies were found to be technically feasible and were evaluated 
further. Because the WFI primarily fires biomass on the grate, LNBs 
would not be effective for the majority of the time that the WFI 
operates. Combustion control methods were evaluated; however, none were 
found to be viable control options for the WFI due to the limited 
NOX removal potential (X removed, with capital costs ranging from 
$3 to $7.6 million, and a resulting maximum visibility improvement of 
only 0.3 dv.
    Maine concluded that the cost effectiveness levels are not 
economically justifiable for any of the control technologies evaluated 
given the maximum visibility improvement resulting from the use of 
these technologies. Maine determined that current combustion control 
represents BART for the WFI.
iv. Recovery Boilers 1 and 2
    Recovery boilers 1 and 2 generate steam while 
regenerating chemicals used in the wood pulping process, and began 
operation in 1965 and 1976, respectively. Recovery boilers 1 
and 2 have rated processing capacities of 2.50 and 3.44 
million pounds per day of dry black liquor solids (BLS), respectively. 
Inorganic material (smelt) from the bottoms of the recovery boilers is 
used to produce green liquor, which is a solution of sodium sulfide and 
sodium carbonate salts, when it is dissolved in water or weak wash in 
the smelt dissolving tanks (1 and 2). Although the 
recovery boilers primarily fire black liquor, they also fire small 
quantities of 2 and 6 fuel oils during startup, 
shutdown, and load stabilization conditions. The facility's license 
currently limits the sulfur content of the fuel oils to no more than 
0.5%, by weight. Particulate matter emissions from both recovery 
boilers are currently controlled using an ESP.
    (1) PM BART Review: PM emissions from recovery boilers 1 
and 2 are currently controlled by an existing shared/common 
ESP. Recovery boilers

[[Page 73973]]

1 and 2 are subject to MACT standards pursuant to 40 
CFR Part 63, Subpart MM. Maine reviewed the RACT/BACT/LAER 
Clearinghouse (RBLC) and found that the current control configuration 
is the most effective control technology in use on recovery boilers and 
that there are no new, more effective technologies subsequent to the 
MACT standard that should be considered. Therefore, Maine determined 
current controls represent BART for recovery boilers 1 and 
2.
    (2) SO2 BART Review: Maine has found that SO2 emissions 
from recovery boilers 1 and 2 are variable due to 
several factors including black liquor properties (e.g., sulfidity, 
sulfur to sodium ratio, heat value, and solids content), combustion 
air, liquor firing patterns, furnace design features, and type of 
startup fuel used. Although each recovery boiler has the ability to 
utilize 2 fuel oil, 6 fuel oil, and used/waste oil 
for startup, shutdown, and load stabilizing conditions, fuel oil firing 
is not a typical operating scenario for the recovery boilers. Maine 
identified and evaluated wet scrubbing, dry scrubbing, and semi-dry 
scrubbing as potential control technologies in the reduction of 
SO2 emissions from recovery boilers 1 and 
2; however, none of these technologies were found to have been 
applied to recovery boilers. Therefore, Maine determined that existing 
combustion controls represent BART for the control of SO2 
emissions from recovery boilers 1 and 2.
    (3) NOX BART Review: Kraft recovery boilers are a unique type of 
combustion source that inherently produce low levels of NOX 
emissions. Most of the NOX emissions produced by recovery 
boilers can be attributed to fuel based NOX resulting from 
the partial oxidation of the nitrogen contained in the black liquor. 
Both recovery boilers 1 and 2 operate with a reducing 
zone in the lower part of the boiler and an oxidizing zone in the 
region of the liquor spray guns designed to provide secondary and 
tertiary staged combustion zones to complete combustion of the black 
liquor and minimize NOX emissions.
    Maine identified and evaluated SCR, LNB, SNCR, and combustion 
control methods (including the addition of a fourth level or quaternary 
air system and a flue gas recirculation system) as potential control 
technologies in the reduction of NOX emissions from recovery 
boilers 1 and 2. SCR has not been applied or 
demonstrated successfully on any recovery boilers. It is unknown how 
the unique characteristics of recovery boiler exhaust gas constituents 
would react with a SCR catalyst, so there was no further evaluation of 
this control technology. Maine's evaluation of LNB technology is that 
it is not technically feasible to use this technology in the firing of 
black liquor given its tar-like qualities and the method by which it is 
injected into the boiler and that it would have minimal results in the 
firing of fuel oils given the small amounts of fuel oils that are fired 
in the recovery boilers. Maine's evaluation of SNCR control 
technologies resulted in a finding that there have been no applications 
of this technology on recovery boilers in the United States for a 
variety of reasons, including safety concerns associated with the risk 
of a smelt/water explosion should boiler tube walls corrode and leak 
near urea injection points and risks associated with an ammonia 
handling system for the SNCR. Operational concerns associated with SNCR 
were found to include the potential formation of acidic sulfates that 
could result in corrosion and a catastrophic boiler tube failure. 
Recovery boilers 1 and 2 are currently designed and 
operated using low excess air combined with three levels of staged 
combustion to minimize NOX emissions. Additional combustion 
control methods were evaluated by Maine, however none were found to be 
viable control options for recovery boilers 1 and 2 
due to the limited amount of space in the boilers to install a fourth 
or quaternary air system and due to the technical challenges re-
circulating recovery boiler exhaust gases in a FGR system due to the 
unique characteristics of the exhaust gases. Therefore, Maine concluded 
that additional control of NOX emissions from recovery 
boilers 1 and 2 are not technically feasible and the 
existing combustion control methods represent BART for these units.
v. Smelt Tanks 1 and 2
    Smelt dissolving tank 1 is rated at 2.50 million pounds 
per day of dry BLS and began operation in 1965. Smelt dissolving tank 
2 is rated at 3.44 million pounds per day of dry BLS and began 
operation in 1975. Inorganic materials from the recovery boiler floors 
drain into smelt dissolving tanks 1 and 2 as molten 
smelt. In the smelt dissolving tanks, the smelt is mixed with weak wash 
to form green liquor which is pumped to the causticizing area. 
SO2 and PM10 emissions from smelt dissolving tank 
1 are controlled with a dual-nozzle wet cyclonic scrubber 
which utilizes an alkaline scrubbing solution and was installed in 
1983. SO2 and PM10 emissions from smelt 
dissolving tank 2 are controlled with a triple-nozzle wet 
cyclonic scrubber which utilizes an alkaline scrubbing solution and was 
installed in 1976.
    (1) PM BART Review: PM emissions from smelt dissolving tanks 
1 and 2 are currently controlled by existing wet 
cyclonic scrubbers. Smelt dissolving tanks 1 and 2 
are subject to MACT standards under 40 CFR Part 63, Subpart MM. After 
review of the RACT/BACT/LAER Clearinghouse, Maine determined that the 
current control configuration is the most current control technology in 
use on smelt dissolving tanks and represent BART for smelt dissolving 
tanks 1 and 2.
    (2) SO2 BART Review: Maine has found that SO2 emissions 
from smelt dissolving tanks 1 and 2 are dependent on 
how much sulfur carries over from the respective recovery boilers with 
the smelt. Controlled smelt-water explosions in the smelt dissolving 
tanks can create SO2 as a result of the oxidation of the 
sulfur in the smelt. SO2 emissions from both smelt 
dissolving tanks combined are very low at approximately 5 tons per 
year. Maine determined that BART for SO2 emissions from 
smelt dissolving tanks 1 and 2 is no additional 
control based on the following:
    (1) SO2 emissions from the smelt dissolving tanks during 
the BART baseline period were and are expected to continue to be 
extremely low (~5 TPY, combined); (2) the smelt dissolving tanks and 
associated scrubbers are designed and operated to minimize 
SO2 emissions; (3) SO2 emissions from the smelt 
dissolving tanks have a minimal impact on visibility (2 emissions from the smelt 
dissolving tanks would have a minimal impact on overall visibility.
    (3) NOX BART Review: Smelt Tanks 1 and 2 do not 
emit NOX.
vi. Lime Kilns A and B
    The ``A'' and ``B'' lime kilns process lime mud (calcium carbonate) 
from the causticizing area to regenerate calcium oxide. Inside the lime 
kilns, the lime mud is dried and heated to a high temperature where the 
lime mud is converted to lime. ``A'' and ``B'' lime kilns are each 
rated at an operating rate of 248 tons of calcium oxide per day and a 
heat input of 72 MMBtu/hr and began operation in 1965 and 1975, 
respectively. The lime kilns are licensed to fire 6 fuel oil, 
2 fuel oil, propane, and used/waste oil. The facility's 
license currently limits the sulfur content of the fuel oil to no more 
than 1.8%, by weight. The ``A'' and ``B'' lime kilns also serve as an 
incineration device (control device) for select sources

[[Page 73974]]

of low volume high concentration (LVHC) non-condensable gases (NCG) 
from pulping operations at the mill. Particulate matter emissions are 
controlled from the ``A'' and ``B'' lime kilns using a fixed throat 
venturi scrubber.
    (1) PM BART Review: PM10 emissions from the ``A'' and 
``B'' lime kilns consist primarily of dust entrained from the 
combustion section of the kilns. This dust consists of sodium salts, 
calcium carbonate, and calcium oxide. PM10 emissions are 
currently controlled by existing venturi scrubbers. These units are 
also subject to MACT Standards under section 112 of the CAA, and 40 CFR 
Part 63, Subpart MM. Maine reviewed the RACT/BACT/LAER Clearinghouse 
and concluded that there are two control technologies that represent 
the most stringent PM control (ESPs and venturi scrubbers). Both ESPs 
and venturi scrubbers have been used to control PM emissions from lime 
kilns and both are capable of a high level of control. Maine determined 
that use of the existing venturi scrubbers to control PM10 
emissions from the ``A'' and ``B'' represents BART for the following 
reasons: (1) The existing venturi scrubbers maintain compliance with 
the MACT emission limits; (2) the replacement of the existing venturi 
scrubbers with dry ESPs could increase SO2 emissions from 
the lime kilns when compared to use of the venturi scrubbers; (3) the 
replacement of the existing venturi scrubbers with wet ESPs would 
result in high capital costs ($1.5 million per kiln); and (4)visibility 
impacts from the lime kilns are minimal (0.03-0.04 dv) and installation 
of additional control would result in inconsequential improvement in 
visibility.
    (2) SO2 BART Review: Maine has found that a significant portion of 
the SO2 formed during the combustion process in the lime 
kilns is removed as the regenerated quicklime in the kilns functions as 
a scrubbing agent. In addition, the non-condensable gas (NCG) 
collection system is equipped with a scrubber that uses white liquor 
(sodium hydroxide or NaOH) and thus the sulfur loading from the NCGs is 
minimized. SO2 emissions from both lime kilns combined are 
very low at less than 4 tons per year primarily due to the alkalinity 
of the lime. Maine determined that BART for SO2 emissions 
from the ``A'' and ``B'' lime kilns is no additional control based on 
the following: (1) SO2 emissions from the lime kilns during 
the BART baseline period were and are expected to continue to be 
extremely low (2 due to the alkalinity of the 
lime in the process; (3) SO2 emissions from the smelt 
dissolving tanks have a minimal impact on visibility (2 emissions from the lime 
kilns would have a minimal impact on overall visibility.
    (3) NOX BART Review: Maine identified and evaluated SCR, LNB, and 
SNCR as potential NOX control technologies. Maine's 
evaluation of SCR and SNCR as potential NOX control 
technologies revealed that they have not been installed on any lime 
kilns in the pulp and paper industry, and were also found to be 
technically infeasible. Maine's research with respect to lime kilns and 
LNB technology revealed that the technology is actually a combination 
of passive combustion control measures used to minimize NOX 
formation primarily from thermal NOX and to a lesser extent 
fuel NOX. These combustion control measures include careful 
design of the fuel feed system in order to ensure proper mixing of the 
fuel with air and burner ``tuning'' or optimization which impacts fuel 
burning efficiency and overall flame length. Verso Androscoggin already 
incorporates burner ``tuning'' in the operation and maintenance of the 
``A'' and ``B'' lime kilns to optimize the relationship between 
NOX emissions and operating efficiency. Maine determined 
that the current use of LNB represents BART for control of 
NOX emissions from ``A'' and ``B'' lime kilns and that no 
additional level of control is technically feasible. Maine also notes 
in the BART analysis that existing NOX emissions from the 
``A'' and ``B'' lime kilns have a minimal impact on visibility (X emissions 
would have a minimal impact on the overall improvement to visibility.
vii. Flash Dryer
    The flash dryer is used to dry pulp for resale or for storage and 
future use on one of Verso Androscoggin's paper machines. The flash 
dryer has a rated heat input capacity of 84 MMBtu/hr and began 
operation in 1964. The flash dryer is licensed to fire 2 fuel 
oil, which contains a maximum sulfur content of 0.5%. Particulate 
matter emissions are controlled using a wet shower system and 
SO2 emissions are limited through the firing of 2 
fuel oil.
    (1) PM BART Review: Particulate matter emissions from the flash 
dryer are currently controlled by the use of a wet shower system. Maine 
concluded that the application of add-on controls and the use of 
cleaner fuels are not practical considerations for controlling PM 
emissions from the flash dryers and that with potential visibility 
impacts from the flash dryer being extremely low, any emission 
reductions would have an inconsequential impact on visibility 
improvement (less than 0.1 dv). Therefore, Maine determined that 
current controls represent BART for the flash dryer.
    (2) SO2 BART Review: The flash dryer is limited by license 
conditions to firing 2 fuel oil with a maximum sulfur content 
of 0.5%, by weight and so has relatively low SO2 emissions. Although 
Verso Androscoggin could replace the use of 2 fuel oil with 
lower sulfur containing fuels such as low sulfur (0.05%) diesel fuel or 
natural gas, the flash dryer is predicted to have peak visibility 
impacts of 0.1 deciviews or less. Therefore, Maine determined that 
current controls represent BART.
    (3) NOX BART Review: The flash dryer is not equipped 
with any NOX control equipment. NOX emissions 
from the flash dryer are primarily generated from the nitrogen 
component in the fuel oil. Verso Androscoggin currently uses good 
maintenance practices to minimize NOX emissions from the 
flash dryer. Maine's investigation of conventional NOX 
combustion controls (e.g., LNB, OFA, and FGR) lead to a finding that 
they are either unavailable for installation on the flash dryer or are 
not feasible for a combustion source as small as the flash dryer. 
Therefore, Maine determined that controls are sufficient for BART.
viii. EPA Assessment
    EPA finds that Maine's analyses and conclusions for the BART 
emission units located at the Verso Androscoggin facility are 
reasonable. EPA guidance gives the States wide latitude in the 
application of the five factors. EPA believes that Maine's approach is 
reasonable for determining that current controls are sufficient for 
recovery boilers 1 and 2, WFI, smelt tanks 1 
and 2, lime kilns A and B, the flash dryer. EPA finds, with 
respect to the power boilers 1 and 2, that Maine's 
determination that natural gas, 2 oil, or wet scrubbing 
technology are not economically justifiable, is reasonable.\15\

[[Page 73975]]

EPA also finds that Maine's determination that 6 oil with 0.7% 
sulfur content and current NOX controls represent BART is 
reasonable.\16\ EPA has reviewed the Maine analyses and concluded they 
were conducted in a manner consistent with EPA's BART Guidelines.
---------------------------------------------------------------------------

    \15\ Maine's SIP revision submittal is unclear as to whether 
Maine judged the cost effectiveness of these technologies based on 
the longer, 2002-2008, timeframe or the shorter, 2008-2009, 
timeframe. States have broad discretion in setting BART, and EPA 
finds that Maine could have reasonably concluded that even the lower 
cost of these technologies under the 2002-2008 timeframe was not 
economically justifiable given the incremental visibility benefits 
associated with the more stringent technology.
    \16\ The MANE-VU recommended limit for these types of units is 
0.5% sulfur content. However, under a state provision, 38 M.R.S.A. 
Sec.  603-A, sub-Sec.  8--that was not submitted as part of the SIP 
revision and is not currently being considered by EPA--Maine DEP is 
limited to either requiring 1% sulfur content or a 50% reduction. 
Because States have broad discretion in setting BART, EPA finds that 
requiring 0.7% sulfur content is reasonable; however it should be 
noted that under 38 M.R.S.A. Sec.  603-A, sub-Sec.  2(A), which EPA 
is proposing to approve today, these units will be required to use 
0.5% sulfur content fuel by January 1, 2018.
---------------------------------------------------------------------------

f. Red Shield Environmental, LLC
i. Background
    Red Shield operates a pulp mill in Old Town, Maine. Pulp production 
at the facility begins with wood chips entering the facility, where 
they are conveyed to, and ``cooked'' in an impregnation vessel followed 
by a digester. In the digester, white liquor is used to dissolve the 
lignin from around the wood fibers. The pulp from the digester is then 
washed in the brownstock washer system to remove residual spent cooking 
liquor. After bleaching the pulp to the desired brightness, it is the 
dried. There are two BART eligible units at the facility; recovery 
boiler 4, and the lime kiln. These units are similar to those 
already discussed above at SD Warren and Verso Androscoggin, and Maine 
similarly concluded that current controls represent BART at Red Shield 
Environmental.
ii. Recovery Boiler 4
    Recovery boiler 4, manufactured by Babcock & Wilcox, was 
originally installed in 1971. However, in June of 1987, a smelt bed 
explosion damaged the boiler. Recovery boiler 4 was repaired 
and returned to operation by December of 1987. Recovery boiler 
4 has the capability of firing black liquor, either alone or 
in combination with 6 fuel oil, and is limited to firing 2.57 
MMlbs of black liquor solids per day. The total heat input capacity of 
firing 6 fuel alone in the boiler is 375 MMBtu/hr (2500 gal/
hr). An ESP controls particulate matter from the unit.
    (1) PM BART Review: Recovery boiler 4 is equipped with an 
ESP for particulate matter, and a limit of 0.028 grains per dry 
standard cubic foot (gr/dscf) \17\ has been established pursuant to 
MACT, 40 CFR Part 63, Subpart MM. Therefore, Maine determined current 
controls were determined to represent BART.
---------------------------------------------------------------------------

    \17\ The narrative that accompanies Maine's SIP revision 
submittal lists this limit as 0.044 gr/dscf. However, the associated 
Table 10-9 BART Determination Summary for Red Shield Environmental, 
LLC of the SIP submittal and the license amendment issued by Maine 
DEP that EPA is proposing to approve into Maine's SIP lists the 
limit as 0.028 gr/dscf. Therefore this limit is the enforceable 
limit.
---------------------------------------------------------------------------

    (2) SO2 BART Review: SO2 emissions from the 
recovery boiler 4 are limited through the use of low sulfur 
(0.5% fuel sulfur content limit) as established by air emission license 
amendment A-180-71-Z-A and required by the facility's Part 70 air 
emission license (A-180-70-A-I). Therefore, Maine determined the 
current controls represent BART.
    (3) NOX BART Review: Recovery boiler 4 is 
subject to Maine's federally enforceable Chapter 138--Reasonably 
Available Control Technology for Facilities that Emit Nitrogen Oxides 
(69 FR 66748) which contains the applicable NOX ppm limit 
(150 ppm). The unit is also subject to a best practical treatment (BPT) 
NOX limit of 154.4 pounds per hour (lb/hr) when firing black 
liquor, and a 188.2 lb/hr limit when firing oil. The maximum visibility 
impact from this source on a Class I area is minimal, 0.2631 dv, 0.2070 
dv impact due to NOX. Therefore, Maine determined the 
current controls represent BART.
iii. Lime Kiln
    The lime kiln, lime mud clarifier, storage tanks, precoat filter, 
and scrubber are all part of the lime kiln system. Lime mud 
(CaCO3) from the recausticizing slaker system is processed 
back into lime (CaO) through the lime kiln system. The lime kiln was 
installed in 1974 and is controlled with a venturi scrubber system. The 
lime kiln burner has a rating of 64 MMBtu/hr and fires primarily 
6 fuel oil with a 2% sulfur content. Propane is used only for 
the pilot flame. Low volume high concentration (LVHC) gases are also 
fired in the lime kiln.
    (1) PM BART Review: The lime kiln is equipped with a venturi 
scrubber system for particulate matter, and is subject to 40 CFR Part 
63, Subpart MM, which contains an applicable PM emission limit of 0.064 
gr/dscf. However, 40 CFR Part 63, Subpart MM also allows Red Shield to 
propose an alternative PM limit (0.13 gr/dscf), which takes into 
account facility emissions from the 4 Recovery Boiler and 
4 Smelt Tank. Maine also established an applicable PM emission 
limit of 32.9 lb/hr under Maine's BPT program. Therefore, Maine 
determined current controls represent BART.
    (2) SO2 BART Review: The lime kiln is subject to Maine's 
BPT with an applicable limit of 7.1 lb/hr. Therefore, Maine determined 
that current controls represent BART.
    (3) NOX BART Review: The lime kiln is subject to Maine's 
Chapter 138 which contains the applicable NOX ppm limit (170 
ppm on a dry basis). The applicable NOX lb/hr emission limit 
is 36.0 lb/hr. The maximum visibility impact from this source on a 
Class I area is minimal, 0.1338 dv, 0.085 dv impact due to 
NOX. Therefore, Maine determined that current controls 
represent BART.
iv. EPA Assessment
    Under EPA Guidance, States have wide discretion as to how they 
assess the BART five factors. Visibility modeling indicates the maximum 
visibility impairment from the 4 recovery boiler and the lime 
kiln is 0.26 dv and 0.13 dv, respectively. The sources at Red Shield 
Environmental are similar to units at Verso Androscoggin and several 
other facilities. Maine analyzed the potential for add on controls for 
recovery boilers and lime kilns for Verso Androscoggin, finding 
additional controls for those units to be technologically infeasible. 
Based on that analysis, EPA finds that Maine's conclusion that the 
current controls are sufficient for BART is reasonable. EPA has 
reviewed the Maine analyses and concluded they were conducted in a 
manner consistent with EPA's BART Guidelines.
6. Enforceability of BART
    As noted above, some of the BART units are subject to MACT 
standards that are federally enforceable. In addition, as part of the 
Maine's December 6, 2010 Regional Haze SIP submittal, Maine DEP 
included source specific permits which detail emission limits, and 
record keeping and reporting requirements associated with the 
installation of the identified BART controls. EPA is proposing to 
approve the submitted license conditions as part of this rulemaking 
action. If finalized, as proposed, these conditions will become 
federally enforceable.

E. Long-Term Strategy

    As described in Section II. E of this action, the LTS is a 
compilation of state-specific control measures relied on by the state 
to obtain its share of emission reductions to support the RPGs 
established by Maine, New Hampshire, Vermont, and New Jersey, the 
nearby Class I area States. Maine's LTS for the

[[Page 73976]]

first implementation period addresses the emissions reductions from 
federal, state, and local controls that take effect in the State from 
the baseline period starting in 2002 until 2018. Maine participated in 
the MANE-VU regional strategy development process. As a participant, 
Maine supported a regional approach towards deciding which control 
measures to pursue for regional haze, which was based on technical 
analyses documented in the following reports: (a) The MANE-VU 
Contribution report; (b) Assessment of Reasonable Progress for Regional 
Haze in MANE-VU Class I Areas, available at www.marama.org/visibility/RPG/FinalReport/RPGFinalReport_070907.pdf pdf; c) Five-Factor Analysis of 
BART-Eligible Sources: Survey of Options for Conducting BART 
Determinations, available at www.nescaum.org/documents/bart-final-memo-06-28-07.pdf; and d) Assessment of Control Technology Options for BART-
Eligible Sources: Steam Electric Boilers, Industrial Boilers, Cement 
Plants and Paper, and Pulp Facilities, available at www.nescaum.org/documents/bart-control-assessment.pdf.
    The LTS was developed by Maine, in coordination with MANE-VU, 
identifying the emissions units within Maine that are currently likely 
have the largest impacts on visibility at nearby Class I areas, 
estimating emissions reductions for 2018, based on all controls 
required under federal and state regulations for the 2002-2018 period 
(including BART), and comparing projected visibility improvement with 
the uniform rate of progress for the nearby Class I area.
    Maine's LTS includes measures needed to achieve its share of 
emissions reductions agreed upon through the consultation process with 
MANE-VU Class I States and includes enforceable emissions limitations, 
compliance schedules, and other measures necessary to achieve the 
reasonable progress goals established by New Hampshire, Vermont, and 
New Jersey for their Class I areas.
1. Emissions Inventory for 2018 With Federal and State Control 
Requirements
    The emissions inventory used in the regional haze technical 
analyses was developed by MARAMA for MANE-VU with assistance from 
Maine. The 2018 emissions inventory was developed by projecting 2002 
emissions, and assuming emissions growth due to projected increases in 
economic activity as well as applying reductions expected from federal 
and state regulations affecting the emissions of VOC and the 
visibility-impairing pollutants NOX, PM10, 
PM2.5, and SO2. The BART guidelines direct States 
to exercise judgment in deciding whether VOC and NH3 impair 
visibility in their Class I area(s). As discussed further in Section 
IV.C.1 above, MANE-VU demonstrated that anthropogenic emissions of 
sulfates are the major contributor to PM2.5 mass and 
visibility impairment at Class I areas in the Northeast and Mid-
Atlantic region. It was also determined that the total ammonia 
emissions in the MANE-VU region are extremely small.
    MANE-VU developed emissions inventories for four inventory source 
classifications: (1) Stationary point sources, (2) stationary area 
sources, (3) off-road mobile sources, and (4) on-road mobile sources. 
The New York Department of Environmental Conservation also developed an 
inventory of biogenic emissions for the entire MANE-VU region. 
Stationary point sources are those sources that emit greater than a 
specified tonnage per year, depending on the pollutant, with data 
provided at the facility level. Stationary area sources are those 
sources whose individual emissions are relatively small, but due to the 
large number of these sources, the collective emissions from the source 
category could be significant. Off-road mobile sources are equipment 
that can move but do not use the roadways. On-road mobile source 
emissions are automobiles, trucks, and motorcycles that use the roadway 
system. The emissions from these sources are estimated by vehicle type 
and road type. Biogenic sources are natural sources like trees, crops, 
grasses, and natural decay of plants. Stationary point sources emission 
data is tracked at the facility level. For all other source types, 
emissions are summed on the county level.
    There are many federal and state control programs being implemented 
that MANE-VU and Maine anticipate will reduce emissions between the 
baseline period and 2018. Emission reductions from these control 
programs were projected to achieve substantial visibility improvement 
by 2018 at all of the MANE-VU Class I areas. To assess emissions 
reductions from ongoing air pollution control programs, BART, and 
reasonable progress measures, MANE-VU developed emissions projections 
for 2018 called ``Best and Final.'' The emissions inventory provided by 
the Maine DEP for the ``Best and Final'' 2018 projections is based on 
expected control requirements.
    Maine relied on emission reductions from the following ongoing and 
expected air pollution control programs as part of the state's long 
term strategy. Maine's EGU Regulation (Chapter 145 NOX 
Control Program) limits the NOX emission rate to 0.22 lb 
NOX/MMBtu for fossil fuel-fired units greater than 25 MW 
built before 1995 with a heat input capacity between 250 and 750 MMBtu/
hr, and also limits the NOX emission rate to 0.17 lb 
NOX/MMBtu for fossil fuel-fired units greater than 25 MW 
built before 1995 with a heat input capacity greater than 750 MMBtu/hr.
    Non-EGU point source controls in Maine include: 2-year, 4-year, 7-
year, and 10-year MACT Standards; Combustion Turbine and Reciprocating 
Internal Combustion Engine (RICE) MACT; Industrial Boiler/Process 
Heater MACT.\18\
---------------------------------------------------------------------------

    \18\ The inventory was prepared before the MACT for industrial 
Boilers and Process Heaters was vacated. Control efficiency was 
assumed to be 4 percent for SO2 and 40 percent for PM. 
The overall effects of including these reductions in the inventory 
are estimated to be minimal.
---------------------------------------------------------------------------

    On July 30, 2007, the U.S. District Court of Appeals mandated the 
vacatur and remand of the Industrial Boiler MACT Rule.\19\ This MACT 
was vacated since it was directly affected by the vacatur and remand of 
the Commercial and Industrial Solid Waste Incinerator (CISWI) 
Definition Rule. EPA proposed a new Industrial Boiler MACT rule to 
address the vacatur on June 4, 2010, (75 FR 32006) and issued a final 
rule on March 21, 2011 (76 FR 15608).
---------------------------------------------------------------------------

    \19\ NRDC v. EPA, 489F.3d 1250.
---------------------------------------------------------------------------

    Maine's modeling included emission reductions from the vacated 
Industrial Boiler MACT rule. Maine did not redo its modeling analysis 
when the rule was re-issued. However, the expected reductions in 
SO2 and PM resulting from both the vacated and revised MACT 
rule are a relatively small component of the Maine inventory. The 
expected emission reductions from the revised MACT rule are comparable 
to the modeled reductions from the vacated MACT rule. In addition, the 
new MACT rule requires compliance by 2014 and therefore the expected 
emission reductions will be achieved prior to the end of the first 
implementation period in 2018.
    Controls on area sources expected in 2018 include the following 
Maine state regulations: architectural and industrial maintenance 
coatings (06-096 CMR Chapter 151) and solvent cleaning (06-096 CMR 
Chapter 130); mobile equipment repair and refinishing (06-096 CMR 
Chapter 153); and VOC control measures for portable fuel containers 
(06-096 CMR Chapter 155) and consumer products (06-096 CMR Chapter 
152). All of these rules have been incorporated into the Maine SIP.

[[Page 73977]]

See www.epa.gov/region1/topics/air/sips/sips_me.html.
    Controls on mobile sources expected in 2018 include: Stage I vapor 
recovery systems at gasoline dispensing facility in the state and Stage 
II vapor recovery at any gasoline dispensing facility in York, 
Cumberland, and Sagadahoc counties (06-096 CMR Chapter 118); \20\ 
Federal On-Board Refueling Vapor Recovery (ORVR) Rule; Federal Tier 2 
Motor Vehicle Emissions Standards and Gasoline Sulfur Requirements; 
Federal Heavy-Duty Diesel Engine Emission Standards for Trucks and 
Buses; and Federal Emission Standards for Large Industrial Spark-
Ignition Engines and Recreation Vehicles.
---------------------------------------------------------------------------

    \20\ Maine recently revised Chapter 118 to no longer require 
Stage II vapor recovery controls as of January 1, 2012. The previous 
version of the rule, however, is still currently included in the 
Maine SIP. Maine DEP is currently developing a SIP submittal for the 
revised rule which would ensure that Clean Air Act antibacksliding 
requirements are met. The SIP submittal must provide for equivalent 
or greater reductions than under the currently approved Stage II 
program. Therefore, consideration of these reductions in the model 
is reasonable.
---------------------------------------------------------------------------

    Controls on non-road sources expected by 2018 include the following 
federal regulations: Control of Air Pollution: Determination of 
Significance for Nonroad Sources and Emission Standards for New Nonroad 
Compression Ignition Engines at or above 37 kilowatts (59 FR 31306, 
June 17, 1994); Control of Emissions of Air Pollution from Nonroad 
Diesel Engines (63 FR 56967, October 23, 1998); Control of Emissions 
from Nonroad Large Spark-Ignition Engines and Recreational Engines (67 
FR 68241, November 8, 2002); and Control of Emissions of Air Pollution 
from Nonroad Diesel Engines and Fuels (69 FR 38958, June 29, 2004).
    Tables 4 and 5 are summaries of the 2002 baseline and 2018 
estimated emissions inventories for Maine. The 2018 estimated emissions 
include emissions growth as well as emission reductions due to ongoing 
emission control strategies and reasonable progress goals.

                               Table 7--2002 Emissions Inventory Summary for Maine
                                                 [Tons per year]
----------------------------------------------------------------------------------------------------------------
                                                   NH3        NOX        PM10      PM2.5       SO2        VOC
----------------------------------------------------------------------------------------------------------------
Mobile........................................      1,468     54,687      1,239        934      1,804     23,037
Nonroad.......................................         11      9,820      1,437      1,329        917     31,144
EGU Point.....................................        145      7,831      1,169        888      9,299        842
Non-EGU Point.................................        700     12,108      6,120      4,899     14,412      4,477
Area..........................................      8,747      7,360    168,953     32,774     13,149    100,621
Biogenics.....................................  .........      2,018  .........  .........  .........    600,205
                                               -----------------------------------------------------------------
    Totals....................................     11,071     93,824    178,919     40,825     39,581    760,327
----------------------------------------------------------------------------------------------------------------

                               Table 8--2018 Emission Inventory Summary for Maine
                                                 [Tons per year]
----------------------------------------------------------------------------------------------------------------
                                                   NH3        NOX        PM10      PM2.5       SO2        VOC
----------------------------------------------------------------------------------------------------------------
Mobile........................................      1,715     12,828        272        266        894     10,414
Nonroad.......................................         15      6,543      1,086        978         82     21,988
EGU Point.....................................        139      1,827        296        279       \21\         53
                                                                                                6,806
Non-EGU Point.................................        859     14,137      7,477      5,922     13,082      5,708
Area..........................................     12,312      7,036     57,411     18,877      1,127     90,866
Biogenics.....................................  .........      2,018  .........  .........  .........    600,205
                                               -----------------------------------------------------------------
    Totals....................................     15,041     44,390       \22\     26,321     21,991    729,235
                                                                         66,542
----------------------------------------------------------------------------------------------------------------

2. Modeling to Support the LTS and Determine Visibility Improvement for 
Uniform Rate of Progress
    MANE-VU performed modeling for the regional haze LTS for the 11 
Mid-Atlantic and Northeast States and the District of Columbia. The 
modeling analysis is a complex technical evaluation that began with 
selection of the modeling system. MANE-VU used the following modeling 
system:
---------------------------------------------------------------------------

    \21\ The 2018 Final Modeling Inventory SO2 emissions 
estimates for the EGU sector includes adjustments to the EGU sector, 
including: (1) Assessing the implementation of BART at eight BART-
eligible units, including Maine's Wyman Station; (2) implementation 
of the MANE-VU EGU strategy; (3) increases in SO2 
emissions to estimate the effect of emissions trading under the CAIR 
program; and (4) emissions increases in the MANE-VU region to 
reflect state's best estimates that some sources predicted by the 
IPM model to be closed would continue to operates, and information 
about where and when emission controls would be installed. The net 
result of these adjustments was an increase in SO2 
emissions from EGUs in Maine.
    \22\ An adjustment factor was applied during the processing of 
emissions data to restate fugitive particulate matter emissions. 
Grid models have been found to overestimate fugitive dust impacts 
when compared with ambient samples; therefore, an adjustment is 
typically applied to account for the removal of particles by 
vegetation and other terrain features. The summary emissions for 
PM10 in Table 8 reflect this adjustment. A comparable 
adjustment was not made to the PM10 value listed in Table 
7.
---------------------------------------------------------------------------

     Meteorological Model: The Fifth-Generation Pennsylvania 
State University/National Center for Atmospheric Research (NCAR) 
Mesoscale Meteorological Model (MM5) version 3.6 is a nonhydrostatic, 
prognostic meteorological model routinely used for urban- and regional-
scale photochemical, PM2.5, and regional haze regulatory 
modeling studies.
     Emissions Model: The Sparse Matrix Operator Kernel 
Emissions (SMOKE) version 2.1 modeling system is an emissions modeling 
system that generates hourly gridded speciated emission inputs of 
mobile, non-road mobile, area, point, fire, and biogenic emission 
sources for photochemical grid models.
     Air Quality Model: The EPA's Models-3/Community Multiscale 
Air Quality (CMAQ) version 4.5.1 is a photochemical grid model capable 
of addressing ozone, PM, visibility and acid deposition at a regional 
scale.
     Air Quality Model: The Regional Model for Aerosols and 
Deposition

[[Page 73978]]

(REMSAD) is a Eulerian grid model that was primarily used to determine 
the attribution of sulfate species in the Eastern US via the species-
tagging scheme.
     Air Quality Model: The California Puff Model (CALPUFF), 
version 5 is a non-steady-state Lagrangian puff model used to access 
the contribution of individual States' emissions to sulfate levels at 
selected Class I receptor sites.
    CMAQ modeling of regional haze in the MANE-VU region for 2002 and 
2018 was carried out on a grid of 12x12 kilometer (km) cells that 
covers the 11 MANE-VU States (Connecticut, Delaware, Maine, Maryland, 
Massachusetts, New Hampshire, New Jersey, New York, Pennsylvania, Rhode 
Island, and Vermont) and the District of Columbia and States adjacent 
to them. This grid is nested within a larger national CMAQ modeling 
grid of 36x36 km grid cells that covers the continental United States, 
portions of Canada and Mexico, and portions of the Atlantic and Pacific 
Oceans along the east and west coasts. Selection of a representative 
period of meteorology is crucial for evaluating baseline air quality 
conditions and projecting future changes in air quality due to changes 
in emissions of visibility-impairing pollutants. MANE-VU conducted an 
in-depth analysis which resulted in the selection of the entire year of 
2002 (January 1-December 31) as the best period of meteorology 
available for conducting the CMAQ modeling. The MANE-VU States' 
modeling was developed consistent with EPA's Guidance on the Use of 
Models and Other Analyses for Demonstrating Attainment of Air Quality 
Goals for Ozone, PM2.5, and Regional Haze, April 2007 (EPA-454/B-07-
002), available at www.epa.gov/scram001/guidance/guide/final-03-p.m.-rh-guidance.pdf, and EPA document, Emissions Inventory Guidance for 
Implementation of Ozone and Particulate Matter National Ambient Air 
Quality Standards (NAAQS) and Regional Haze Regulations, August 2005 
and updated November 2005 (EPA-454/R-05-001), available at www.epa.gov/ttnchie1/eidocs/eiguid/index.html [hereinafter EPA's Modeling 
Guidance].
    MANE-VU examined the model performance of the regional modeling for 
the areas of interest before determining whether the CMAQ model results 
were suitable for use in the regional haze assessment of the LTS and 
for use in the modeling assessment. The modeling assessment predicts 
future levels of emissions and visibility impairment used to support 
the LTS and to compare predicted, modeled visibility levels with those 
on the uniform rate of progress. In keeping with the objective of the 
CMAQ modeling platform, the air quality model performance was evaluated 
using graphical and statistical assessments based on measured ozone, 
fine particles, and acid deposition from various monitoring networks 
and databases for the 2002 base year. MANE-VU used a diverse set of 
statistical parameters from the EPA's Modeling Guidance to stress and 
examine the model and modeling inputs. Once MANE-VU determined the 
model performance to be acceptable, MANE-VU used the model to assess 
the 2018 RPGs using the current and future year air quality modeling 
predictions, and compared the RPGs to the uniform rate of progress.
    In accordance with 40 CFR 51.308(d)(3), the Maine DEP provided the 
appropriate supporting documentation for all required analyses used to 
determine the State's LTS. The technical analyses and modeling used to 
develop the glide path and to support the LTS are consistent with EPA's 
RHR, and interim and final EPA Modeling Guidance. EPA finds the MANE-VU 
technical modeling to support the LTS and determine visibility 
improvement for the uniform rate of progress acceptable because the 
modeling system was chosen and used according to EPA Modeling Guidance. 
EPA agrees with the MANE-VU model performance procedures and results, 
and that the CMAQ is an appropriate tool for the regional haze 
assessments for the Maine LTS and regional haze SIP.
3. Meeting the MANE-VU ``Ask''
    Maine in cooperation with the MANE-VU States developed the MANE-VU 
``Ask'' to provide for reasonable progress towards achieving natural 
visibility at the MANE-VU Class I areas. The ``Ask'' included: (a) 
Timely implementation of BART requirements; (b) a 90 percent reduction 
in SO2 emissions from each of the EGU stacks identified by 
MANE-VU comprising a total of 167 stacks; (c) adoption of a low sulfur 
fuel oil strategy; and (d) continued evaluation of other control 
measures to reduce SO2 and NOX emissions.
a. Timely Implementation of BART
    The Maine BART determinations are discussed in section IV.D. In the 
modeling to demonstrate the sufficiency of the LTS to achieve the RPGs, 
Maine assumed a 1,442 ton per year reduction in SO2 from 
SAPPI Somerset Power Boiler 1 due to BART control. Maine later 
determined that this unit was not BART eligible due to federally 
enforceable operation restrictions. However, Maine demonstrated that 
the SO2 emissions reductions assumed in the modeling were 
reasonable since an additional, federally enforceable Title V license 
condition limits the amount of time boiler 1 can be used to 
incinerate total reduced sulfur gases. This limit compensates for the 
initial assumption of 1,442 ton per year reduction in SO2.
b. Ninety Percent Reduction in SO2 Emissions From Each of 
the Electric Generating Unit (EGU) Stacks Identified by MANE-VU 
Comprising a Total of 167 Stacks
    Maine has one EGU stack identified by MANE-VU as a top contributor 
to visibility impairment in any of the MANE-VU Class I areas, FPL 
Energy Wyman Station boiler 4.
    Boiler 4 is a peaking unit, and operated at an average 
annual capacity factor of less than 10 percent between 2002 and 2009, 
with annual SO2 emissions of 1,170 tons in 2002.
    Although FGD through the use of a wet, semi-dry or dry scrubber is 
technically feasible, this technology is cost prohibitive due to the 
low-capacity factor of this unit. In lieu of requiring add-on controls, 
Maine will be utilizing its low-sulfur fuels program meet the ``Ask'' 
at this unit. The Maine Low Sulfur Fuel Program requires the use of 
low-sulfur fuel containing no more than 0.5% sulfur beginning January 
1, 2018, providing an 84 percent reduction in SO2 emissions 
from its baseline emissions based on the use of 3.0% sulfur fuel.
c. Maine Low Sulfur Fuel Oil Strategy
    The MANE-VU low sulfur fuel oil strategy includes two phases. Phase 
I of the strategy requires the reduction of sulfur in distillate oil to 
0.05% sulfur by weight (500 parts per million (ppm)) by no later than 
2014. Phase II requires reductions of sulfur in 4 residual oil 
to 0.25% sulfur by weight by no later than 2018; in 6 residual 
oil to 0.5% sulfur by weight by no later than 2018; and a further 
reduction in the sulfur content of distillate oil to 15 ppm by 2018.
    The Maine Low Sulfur Oil Program, as established in statute at 38 
M.R.S.A. Sec.  603-A, sub-Sec.  2, instituted the following 
restrictions on fuel sulfur content for residual (4, 
5, and 6) and distillate oil:
    (1) Beginning January 1, 2018; a person may not use residual oil 
with a sulfur content greater than 0.5% by weight;
    (2) Beginning January 1, 2016, a person may not use distillate oil 
with a sulfur content greater than 0.005% by weight; and

[[Page 73979]]

    (3) Beginning January 1, 2018, a person may not use distillate oil 
with a sulfur content greater than 0.0015% by weight.
    In addition to the low sulfur requirements for distillate and 
residual oil, the program contains two elements not included in the 
MANE-VU Low Sulfur Oil Strategy. These elements are an exemption from 
the low sulfur content limits for sources using distillate fuel for 
manufacturing purposes and an equivalent alternative sulfur reduction 
program. Neither element is included in Maine's implementation plan 
submittal or approved by EPA.
    Maine DEP does not believe that the low sulfur content limit 
exemption for manufacturing purposes will have a significant impact on 
the emission reductions afforded by this strategy for 2018 and beyond. 
While the exemption allows the continued use of high-sulfur \23\ 
distillate oil at several manufacturing facilities, there are 
structural impediments to the actual use of these fuels. First, since 
there is only a limited potential market for high-sulfur distillate 
\24\ the Maine DEP believes that this fuel will not be readily 
available, and will likely be more expensive than the more widely used 
15 ppm distillate. Distributors and wholesalers of distillate fuels 
have noted that supplying high-sulfur distillate to a limited market 
introduces additional costs to their industry in the form of segregated 
storage and transportation/delivery systems, since even incidental 
contamination (co-mingling) can lead to non-compliance issues.\25\
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    \23\ Containing 2,000-5,000 ppm sulfur.
    \24\ All other users of distillate (diesel) fuel in Maine will 
be subject to the 15 ppm sulfur limits (including general use and 
space heating at manufacturing facilities).
    \25\ For example, only 7 gallons of a 5,000 ppm sulfur fuel 
added to 7,500 gallons of ULSD would raise the sulfur content by 5.0 
ppm.
---------------------------------------------------------------------------

    Recognizing the potential for incidental contamination of ULSD, 
segregated storage and transportation/delivery systems are probably the 
only mechanisms that can assure compliance with federal and state ULSD 
requirements for the petroleum marketing industry. Given the low 
demand, and additional storage, transportation and delivery costs, 
Maine DEP does not believe that high sulfur distillate fuel will be 
widely used by the manufacturing sector in 2018 and later.\26\
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    \26\ As noted above, Maine believes that future (2018) use of 
distillate fuel by the manufacturing sector will be limited due to 
cost and compliance concerns. Nevertheless, projected 2018 
SO2 emissions for Maine have been adjusted to address 
this exemption, and its impact on non-EGU point source emissions.
---------------------------------------------------------------------------

d. Continued Evaluation of Other Control Measures To Reduce 
SO2 and NOX Emissions
    While Maine DEP continues to evaluate other control measures to 
reduce SO2 and NOX emission, Maine has adopted a 
program to reduce wood smoke emissions from outdoor wood and pellet 
boilers.
    Maine's Control of Emissions From Outdoor Wood Boilers Rule (06-096 
CMR 150) includes EPA's recommended Phase I particulate emission limit 
of 0.60 lbs/MMBtu/hr heat input as the standard for new outdoor wood-
fired hydronic heaters (OWHH), also known as outdoor wood boilers, sold 
in Maine beginning April 1, 2008. Beginning April 1, 2010 new OWHH sold 
in Maine were required to meet a more stringent particulate emission 
standard of 0.32 lbs/MMBtu heat output (Phase II). The rule also 
establishes setback, stack height, particulate emission limits, and 
fuel requirements for outdoor wood boilers. Chapter 150 was 
subsequently amended to control the sale, installation, use, and siting 
of outdoor wood boilers that combust biomass pellets as fuel. Maine has 
submitted this rule to EPA for incorporation as part of the Regional 
Haze SIP.
    Maine did not include emission reductions which result from the 
promulgation of the outdoor wood boilers rule in the visibility 
modeling to ensure reasonable progress. However, Maine is including 
this program in its regional Haze SIP as a SIP enhancement, or 
strengthening measure. EPA finds that Maine has sufficiently addressed 
the MANE-VU ``Ask'' by means of Maine's Low Sulfur Fuel oil strategy, 
control on Wyman Unit 4, the submitted BART determinations, 
and the outdoor wood boiler control strategy.
4. Additional Considerations for the LTS
    40 CFR 51.308(d)(3)(v) requires States to consider the following 
factors in developing the long term strategy:
    a. Emission reductions due to ongoing air pollution control 
programs, including measures to address reasonably attributable 
visibility impairment;
    b. Measures to mitigate the impacts of construction activities;
    c. Emission limitations and schedules for compliance to achieve the 
reasonable progress goal;
    d. Source retirement and replacement schedules;
    e. Smoke management techniques for agricultural and forestry 
management purposes including plans as currently exist within the State 
for these purposes;
    f. Enforceability of emissions limitations and control measures; 
and
    g. The anticipated net effect on visibility due to projected 
changes in point area, and mobile source emissions over the period 
addressed by the long-term strategy.
a. Emission Reductions Including RAVI
    No source in Maine has been identified as subject to RAVI. An 
exhaustive list of Maine's ongoing air pollution control programs is 
included in section IV.E.1.
b. Construction Activities
    The Regional Haze Rule requires Maine to consider measures to 
mitigate the impacts of construction activities on regional haze. MANE-
VU's consideration of control measures for construction activities is 
documented in ``Technical Support Document on Measures To Mitigate the 
Visibility Impacts of Construction Activities in the MANE-VU Region, 
Draft, October 20, 2006.''\27\
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    \27\ ``Technical Support Document on Measures to Mitigate the 
Visibility Impacts of Construction Activities in the MANE-VU Region, 
Draft, October 20, 2006'' has been provided as part of the docket to 
this proposed rulemaking.
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    The construction industry is already subject to requirements for 
controlling pollutants that contribute to visibility impairment. For 
example, federal regulations require the reduction of SO2 
emissions from construction vehicles. At the state level, Maine 
currently regulates emissions of fugitive dust through Maine's Chapter 
101, Visible Emissions rules, which establishes opacity limits for 
emissions from several categories of air contaminant sources, including 
fugitive emissions from construction activities. This rule has been 
incorporated into the Maine SIP. See www.epa.gov/region1/topics/air/sips/me/2003_ME_ch101.pdf.
    MANE-VU's Contribution Assessment found that, from a regional haze 
perspective, crustal material generally does not play a major role. On 
the 20 percent best-visibility days during the 2000-2004 baseline 
period, crustal material accounted for 6 to 11 percent of the particle-
related light extinction at the MANE-VU Class I Areas. On the 20 
percent worst-visibility days, however, the ratio was reduced to 2 to 3 
percent. Furthermore, the crustal fraction is largely made up of 
pollutants of natural origin (e.g., soil or sea salt) that are not 
targeted under the Regional

[[Page 73980]]

Haze Rule. Nevertheless, the crustal fraction at any given location can 
be heavily influenced by the proximity of construction activities; and 
construction activities occurring in the immediate vicinity of MANE-VU 
Class I area could have a noticeable effect on visibility.
    For this regional haze SIP, Maine concluded that its current 
regulations are currently sufficient to mitigate the impacts of 
construction activities. Any future deliberations on potential control 
measures for construction activities and the possible implementation 
will be documented in the first regional haze SIP progress report in 
2012. EPA has determined that Maine has adequately addressed measures 
to mitigate the impacts of construction activities.
c. Emission Limitations and Schedules for Compliance To Achieve the RPG
    In addition to the existing CAA control requirements discussed in 
section IV.E.1, Maine has adopted a low sulfur fuel oil strategy 
consistent with the MANE-VU ``Ask.'' The compliance date for Phase I 
will be in 2016 and the compliance date for Phase II will be in 2018.
d. Source Retirement and Replacement Schedule
    Section 40 CFR 51.308(d)(3)(v)(D) of the Regional Haze Rule 
requires Maine to consider source retirement and replacement schedules 
in developing the long term strategy. Source retirement and replacement 
were considered in developing the 2018 emissions. EPA has determined 
that Maine has satisfactorily considered source retirement and 
replacement schedules as part of the LTS.
e. Smoke Management Techniques
    The Regional Haze Rule requires States to consider smoke management 
techniques related to agricultural and forestry management in 
developing the long-term strategy. MANE-VU's analysis of smoke 
management in the context of regional haze is documented in ``Technical 
Support Document on Agricultural and Smoke Management in the MANE-VU 
Region, September 1, 2006.'' \28\
---------------------------------------------------------------------------

    \28\ ``Technical Support Document on Agricultural and Smoke 
Management in the MANE-VU Region, September 1, 2006'' has been 
included as part of the docket to this proposed rulemaking.
---------------------------------------------------------------------------

    Maine does not currently have a Smoke Management Program (SMP). 
However, SMPs are required only when smoke impacts from fires managed 
for resources benefits contribute significantly to regional haze. The 
emissions inventory presented in the above-cited document indicates 
that agricultural, managed and prescribed burning emissions are very 
minor; the inventory estimates that, in Maine, those emissions from 
those source categories totaled 7.8 tons of PM10, 6.7 tons 
of PM2.5 and 0.5 tons of SO2 in 2002, which 
constitute 0.08%, 0.2% and 0.006% of the total inventory for these 
pollutants, respectively.
    Source apportionment results show that wood smoke is a moderate 
contributor to visibility impairment at some Class I areas in the MANE-
VU region; however, smoke is not a large contributor to haze in MANE-VU 
Class I areas on either the 20% best or 20% worst visibility days. 
Moreover, most of the wood smoke is attributable to residential wood 
combustion. Therefore, it is unlikely that fires for agricultural or 
forestry management cause large impacts on visibility in any of the 
Class I areas in the MANE-VU region. On rare occasions, smoke from 
major fires degrades air quality and visibility in the MANE-VU area. 
However, these fires are generally unwanted wildfires that are not 
subject to SMPs. Therefore, an SMP is not required for Maine. EPA 
agrees that it is not necessary for Maine to have an Agricultural and 
Forestry Smoke Management Plan to address visibility impairment at this 
time.
f. Enforceability of Emission Limitations and Control Measures
    All emission limitations included as part of Maine's Regional Haze 
SIP are either currently federally enforceable or will become federally 
enforceable if this action is finalized as proposed.
g. The Anticipated Net Effect on Visibility
    MANE-VU used the best and final emission inventory to model 
progress expected toward the goal of natural visibility conditions for 
the first regional haze planning period. All of the MANE-VU Class I 
areas are expected to achieve greater progress toward the natural 
visibility goal than the uniform rate of progress, or the progress 
expected by extrapolating a trend line from current visibility 
conditions to natural visibility conditions.\29\
---------------------------------------------------------------------------

    \29\ Projected visibility improvements for each MANE-VU Class I 
area can be found in the NESCAUM document dated May 13, 2008, ``2018 
Visibility Projections'' (www.nescaum.org/documents/2018-visibility-projections-final-05-13-08.pdf/).
---------------------------------------------------------------------------

    In summary, EPA is proposing to find that Maine has adequately 
addressed the LTS regional haze requirements.

F. Consultation With States and Federal Land Managers

    On May 10, 2006, the MANE-VU State Air Directors adopted the Inter-
RPO State/Tribal and FLM Consultation Framework that documented the 
consultation process within the context of regional phase planning, and 
was intended to create greater certainty and understanding among RPOs. 
MANE-VU States held ten consultation meetings and/or conference calls 
from March 1, 2007 through March 21, 2008. In addition to MANE-VU 
members attending these meetings and conference calls, participants 
from the Visibility Improvement State and Tribal Association of the 
Southeast (VISTAS) RPO, Midwest RPO, and the relevant Federal Land 
Managers were also in attendance. In addition to the conference calls 
and meeting, the FLMs were given the opportunity to review and comment 
on each of the technical documents developed by MANE-VU.
    On May 27, 2010, Maine submitted a draft Regional Haze SIP to the 
relevant FLMs for review and comment pursuant to 40 CFR 51.308(i)(2). 
The FLMs provided comments on the draft Regional Haze SIP in accordance 
with 40 CFR 51.308(i)(3). The comments received from the FLMs were 
addressed and incorporated in Maine's SIP revision. Most of the 
comments were requests for additional detail as to various aspects of 
the SIP. These comments and Maine's response to comments can be found 
in the docket for this proposed rulemaking.
    On August 12, 2010, Maine published a notice of agency rulemaking--
proposal. This initiated a 30-day comment period and the opportunity to 
request a public hearing. Maine DEP received comments from EPA, the 
United States Department of Fish and Wildlife Service, the United 
States Department of Agriculture, and Florida Power and Light Company. 
Maine's response to comments is included as an attachment to the SIP 
submittal.
    To address the requirement for continuing consultation procedures 
with the FLMs under 40 CFR 51.308(i)(4), Maine commits in their SIP to 
ongoing consultation with the FLMs on Regional Haze issues throughout 
the implementation.
    EPA is proposing to find that Maine has addressed the requirements 
for consultation with States impacting Maine's Class I areas and with 
the Federal Land Managers.

G. Monitoring Strategy and Other Implementation Plan Requirements

    Section 51.308(d)(4) of the Regional Haze Rule requires a 
monitoring strategy

[[Page 73981]]

for measuring, characterizing, and reporting regional haze visibility 
impairment that is representative of all mandatory Class I Areas within 
the State of Maine. The monitoring strategy relies upon participation 
in the IMPROVE network.
    The State of Maine participates in the IMPROVE network, and will 
evaluate the monitoring network periodically and make those changes 
needed to be able to assess whether reasonable progress goals are being 
achieved in each of Maine's mandatory Class I Areas. In its SIP 
submittal, Maine is committing to continued support of the IMPROVE 
network at Acadia National Park and Moosehorn National Wildlife Refuge.
    40 CFR 51.308(d)(4)(i) requires States to establish additional 
monitoring sites or equipment as needed to assess whether reasonable 
progress goals are being achieved toward visibility improvement at 
mandatory Class I areas. At this time, the current monitors are 
sufficient to make this assessment.
    In its SIP submittal, Maine commits to meet the requirements under 
40 CFR 51.308(d)(4)(iv) to report to EPA visibility data for each of 
Maine's Class I Areas annually.
    The Regional Haze Rule (40 CFR 51.308(d)(4)(vi)) requires the 
inclusion of other monitoring elements, including reporting, 
recordkeeping, and other measures, necessary to assess and report 
visibility. While the Maine DEP has concluded that the current IMPROVE 
network provides sufficient data to adequately measure and report 
progress toward the goals set for MANE-VU Class I sites to which the 
State contributes, the State has also found additional monitoring 
information useful to assess visibility and fine particle pollution in 
the region in the past. Examples of these data include results from the 
MANE-VU Regional Aerosol Intensive Network (RAIN), which provides 
continuous, speciated information on rural aerosol characteristics and 
visibility parameters; the EPA Clean Air Status and Trends Network 
(CASTNET), which has provided complementary rural fine particle 
speciation data at non-class I sites; the EPA Speciation Trends Network 
(STN), which provides speciated, urban fine particle data to help 
develop a comprehensive picture of local and regional sources; state-
operated rural and urban speciation sites using IMPROVE or STN methods; 
and the Supersites program, which has provided information through 
special studies that generally expands our understanding of the 
processes that control fine particle formation and transport in the 
region. Maine plans to continue to utilize these and other data--as 
they are available and fiscal realities allow--to improve their 
understanding of visibility impairment and to document progress toward 
our reasonable progress goals under the Regional Haze Rule.

H. Periodic SIP Revisions and Five-Year Progress Reports

    Consistent with the requirements of 40 CFR 51.308(g), Maine has 
committed to submitting a report on reasonable progress (in the form of 
a SIP revision) to the EPA every five years following the initial 
submittal of its regional haze SIP. The reasonable progress report will 
evaluate the progress made towards the RPGs for the MANE-VU Class I 
areas, located in Maine, New Hampshire, Vermont, and New Jersey.
    Section 40 CFR 51.308(f) requires the Maine DEP to submit periodic 
revisions to its Regional Haze SIP by July 31, 2018, and every ten 
years thereafter. Maine DEP acknowledges and agrees to comply with this 
schedule.
    Pursuant to 40 CFR 51.308(d)(4)(v), Maine DEP will also make 
periodic updates to the Maine emissions inventory. Maine DEP plans to 
complete these updates to coincide with the progress reports. Actual 
emissions will be compared to projected modeled emissions in the 
progress reports.
    Lastly, pursuant to 40 CFR 51.308(h), Maine DEP will submit a 
determination of adequacy of its regional haze SIP revision whenever a 
progress report is submitted. Maine's regional haze SIP states that, 
depending on the findings of its five-year review, Maine will take one 
or more of the following actions at that time, whichever actions are 
appropriate or necessary:
     If Maine determines that the existing State Implementation 
Plan requires no further substantive revision in order to achieve 
established goals for visibility improvement and emissions reductions, 
Maine DEP will provide to the EPA Administrator a negative declaration 
that further revision of the existing plan is not needed.
     If Maine determines that its implementation plan is or may 
be inadequate to ensure reasonable progress as a result of emissions 
from sources in one or more other state(s) which participated in the 
regional planning process, Maine will provide notification to the EPA 
Administrator and to those other state(s). Maine will also collaborate 
with the other state(s) through the regional planning process for the 
purpose of developing additional strategies to address any such 
deficiencies in Maine's plan.
     If Maine determines that its implementation plan is or may 
be inadequate to ensure reasonable progress as a result of emissions 
from sources in another country, Maine will provide notification, along 
with available information, to the EPA Administrator.
     If Maine determines that the implementation plan is or may 
be inadequate to ensure reasonable progress as a result of emissions 
from sources within the state, Maine will revise its implementation 
plan to address the plan's deficiencies within one year from this 
determination.

V. What action is EPA proposing to take?

    EPA is proposing to approve of Maine's December 9, 2010 SIP 
revision as meeting the applicable implementing regulations found in 40 
CFR 51.308. EPA is also proposing to approve the following license 
conditions and incorporate them into the SIP: Conditions (16) A, B, G, 
and H of license amendment A-406-77-3-M for Katahdin Paper Company 
issued on July 8, 2009; license amendment A-214-77-9-M for Rumford 
Paper Company issued on January 8, 2010; license amendment A-22-77-5-M 
for Verso Bucksport, LLC issued November 2, 2010; license amendment A-
214-77-2-M for Woodland Pulp, LLC (formerly Domtar) issued November 2, 
2010; license amendment A-388-77-2-M for FPL Energy Wyman, LLC & Wyman 
IV, LLC issued November 2, 2010; license amendment A-19-77-5-M for S. 
D. Warren Company issued November 2, 2010; license amendment A-203-77-
11-M for Verso Androscoggin LLC issued November 2, 2010; and license 
amendment A-180-77-1-A for Red Shield Environmental LLC issued November 
29, 2007.
    EPA is proposing to approve Maine's low sulfur fuel oil 
legislation, 38 MRSA Sec.  603-A, sub-Sec.  2(A), and to incorporate 
this legislation into the Maine SIP. Furthermore, EPA is also proposing 
to approve the following Maine state regulation and incorporate it into 
the SIP: Maine Chapter 150, Control of Emissions from Outdoor Wood 
Boilers.

VI. Statutory and Executive Order Reviews

    Under the Clean Air Act, the Administrator is required to approve a 
SIP submission that complies with the provisions of the Act and 
applicable Federal regulations. 42 U.S.C. 7410(k); 40 CFR 52.02(a). 
Thus, in reviewing SIP submissions, EPA's role is to approve state 
choices, provided that they meet the criteria of the Clean Air Act.

[[Page 73982]]

Accordingly, this proposed action merely approves state law as meeting 
Federal requirements and does not impose additional requirements beyond 
those imposed by state law. For that reason, this proposed action:
     Is not a ``significant regulatory action'' subject to 
review by the Office of Management and Budget under Executive Order 
12866 (58 FR 51735, October 4, 1993);
     Does not impose an information collection burden under the 
provisions of the Paperwork Reduction Act (44 U.S.C. 3501 et seq.);
     Is certified as not having a significant economic impact 
on a substantial number of small entities under the Regulatory 
Flexibility Act (5 U.S.C. 601 et seq.);
     Does not contain any unfunded mandate or significantly or 
uniquely affect small governments, as described in the Unfunded 
Mandates Reform Act of 1995 (Pub. L. 104-4);
     Does not have Federalism implications as specified in 
Executive Order 13132 (64 FR 43255, August 10, 1999);
     Is not an economically significant regulatory action based 
on health or safety risks subject to Executive Order 13045 (62 FR 
19885, April 23, 1997);
     Is not a significant regulatory action subject to 
Executive Order 13211 (66 FR 28355, May 22, 2001);
     Is not subject to requirements of Section 12(d) of the 
National Technology Transfer and Advancement Act of 1995 (15 U.S.C. 272 
note) because application of those requirements would be inconsistent 
with the Clean Air Act; and
     Does not provide EPA with the discretionary authority to 
address, as appropriate, disproportionate human health or environmental 
effects, using practicable and legally permissible methods, under 
Executive Order 12898 (59 FR 7629, February 16, 1994).
    In addition, this rule does not have Tribal implications as 
specified by Executive Order 13175 (65 FR 67249, November 9, 2000), 
because the SIP is not approved to apply in Indian country located in 
the state, and EPA notes that it will not impose substantial direct 
costs on Tribal governments or preempt Tribal law.

List of Subjects in 40 CFR Part 52

    Environmental protection, Air pollution control, Carbon monoxide, 
Incorporation by reference, Intergovernmental relations, Lead, Nitrogen 
dioxide, Ozone, Particulate matter, Reporting and recordkeeping 
requirements, Sulfur oxides, Volatile organic compounds.

    Authority: 42 U.S.C. 7401 et seq.

    Dated: November 15, 2011.
Ira W. Leighton,
Acting Regional Administrator, EPA New England.
[FR Doc. 2011-30650 Filed 11-28-11; 8:45 am]
BILLING CODE 6560-50-P
```