### 33022 Federal Register / Vol. 77, No. 107 / Monday, June 4, 2012 / Proposed Rules

**ENVIRONMENTAL PROTECTION AGENCY** 

**40 CFR Part 52**

**[EPA–R08–OAR–2012–0026, FRL–9678–9]**

**Approval, Disapproval and Promulgation of Implementation Plans;**  **State of Wyoming; Regional Haze State Implementation Plan; Federal**  **Implementation Plan for Regional Haze**

**AGENCY :**  Environmental Protection Agency.

**ACTION :**  Proposed rule.

**SUMMARY :**  EPA is proposing to partially approve and partially disapprove approve a State Implementation Plan (SIP) revision submitted by the State of Wyoming on January 12, 2011, that addresses regional haze. This SIP revision was submitted to address the requirements of the Clean Air Act (CAA or ‘‘the Act’’) and our rules that require states to prevent any future and remedy any existing anthropogenic 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. EPA is taking this action pursuant to section 110 of the CAA.

EPA is proposing a Federal Implementation Plan (FIP) to address the deficiencies identified in our proposed partial disapproval of Wyoming’s regional haze SIP. In lieu of this proposed FIP, or a portion thereof, we propose approval of a SIP revision if the State submits such a revision and the revision matches the terms of our proposed FIP.

**DATES :**  Comments: Written comments must be received at the address below on or before August 3, 2012. Public Hearings: A public hearing for this proposal is scheduled to be held on Tuesday, June 26, 2012, at the Hershchler Building, Room B–63, 122 W. 25th St., Cheyenne, Wyoming 82002. Another public hearing is scheduled to be held on Thursday, June 28, 2012, at Western Wyoming Community College, Room 1005, 2500 College Drive, Rock Springs, Wyoming 82901. The public hearings will be held from 1 p.m. until 5 p.m., and again from 6 p.m. until 8 p.m.

**ADDRESSES :**  Submit your comments, identified by Docket ID No. EPA–R08– OAR–2012–0026, by one of the following methods: • http://www.regulations.gov. Follow the on-line instructions for submitting

comments.

• Email: r8airrulemakings@epa.gov.

• Fax: (303) 312–6064 (please alert the individual listed in the **FOR FURTHER**

**INFORMATION CONTACT** if you are faxing comments).

• Mail: Carl Daly, Director, Air Program, Environmental Protection Agency (EPA), Region 8, Mailcode 8P– AR, 1595 Wynkoop Street, Denver, Colorado 80202–1129.

• Hand Delivery: Carl Daly, Director, Air Program, Environmental Protection Agency (EPA), Region 8, Mailcode 8P– AR, 1595 Wynkoop, Denver, Colorado 80202–1129. Such deliveries are only accepted Monday through Friday, 8 a.m. to 4:30 p.m., excluding Federal holidays. Special arrangements should be made for deliveries of boxed information.

Instructions: Direct your comments to Docket ID No. EPA–R08–OAR–2012– 0026. 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 information that you consider to be CBI or otherwise protected through http:// www.regulations.gov or email. 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. For additional instructions on submitting comments, go to Section I. General Information of the

**SUPPLEMENTARY INFORMATION** section of this document. Docket: All documents in the docket are listed in the http:// www.regulations.gov index. Although listed in the index, some information is not publicly available, e.g., CBI or other information whose disclosure is restricted by statute. Certain other material, such as copyrighted material, will be publicly available only in hard copy. Publicly-available docket materials are available either electronically in http:// www.regulations.gov or in hard copy at the Air Program, Environmental Protection Agency (EPA), Region 8, Mailcode 8P–AR, 1595 Wynkoop, Denver, Colorado 80202–1129. EPA requests that if at all possible, you contact the individual listed in the **FOR**

**FURTHER INFORMATION CONTACT** section to view the hard copy of the docket. You may view the hard copy of the docket Monday through Friday, 8 a.m. to 4 p.m., excluding Federal holidays.

**FOR FURTHER INFORMATION CONTACT :**  Laurel Dygowski, Air Program, U.S. Environmental Protection Agency, Region 8, Mailcode 8P–AR, 1595 Wynkoop, Denver, Colorado 80202– 1129, (303) 312–6144, dygowski.laurel@epa.gov.

**SUPPLEMENTARY INFORMATION :** 

Definitions

For the purpose of this document, we are giving meaning to certain words or initials as follows:

i. The words or initials Act or CAA mean or refer to the Clean Air Act, unless the context indicates otherwise.

ii. The initials AFRC mean or refer to airfuel ratio controls.

iii. The initials BART mean or refer to Best Available Retrofit Technology.

iv. The initials CAMx mean or refer to Comprehensive Air Quality Model.

v. The initials CMAQ mean or refer to Community Multi-Scale Air Quality modeling system.

vi. The initials CEMS mean or refer to continuous emission monitoring systems.

vii. The initials EC mean or refer to elemental carbon.

viii. The initials EGUs mean or refer to Electric Generating Units.

ix. The initials EGR mean or refer to exhaust gas recirculation.

x. The words EPA, we, us or our mean or refer to the United States Environmental Protection Agency.

xi. The initials ESP mean or refer to electrostatic precipitator.

xii. The initials FGC mean or refer to flue gas conditioning.

xiii. The initials FGD mean or refer to flue gas desulfurization.

xiv. The initials FGR mean or refer to external flue gas recirculation.

xv. The initials FIP mean or refer to Federal Implementation Plan.

xvi. The initials FLMs mean or refer to Federal Land Managers.


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xvii. The initials FS mean or refer to the U.S. Forest Service.

xviii. The initials IMPROVE mean or refer to Interagency Monitoring of Protected Visual Environments monitoring network.

xix. The initials IWAQM mean or refer to Interagency Workgroup on Air Quality Modeling.

xx. The initials LEC mean or refer to lowemission combustion.

xxi. The initials LNB mean or refer to low NO X burner.

xxii. The initials LTS mean or refer to the long-term strategy.

xxiii. The initials MW mean or refer to megawatts.

xxiv. The initials NH 3 mean or refer to ammonia.

xxv. The initials NO X mean or refer to nitrogen oxides.

xxvi. The initials NPS mean or refer to National Park Service.

xxvii. The initials OC mean or refer to organic carbon.

xxviii. The initials OFA mean or refer to overfire air.

xxix. The initials PM 2.5 mean or refer to particulate matter with an aerodynamic diameter of less than 2.5 micrometers.

xxx. The initials PM 10 mean or refer to particulate matter with an aerodynamic diameter of less than 10 micrometers.

xxxi. The initials PSAT mean or refer to Particle Source Apportionment Technology.

xxxii. The initials PSD mean or refer to Prevention of Signification Deterioration.

xxxiii. The initials RAVI mean or refer to Reasonably Attributable Visibility Impairment.

xxxiv. The initials RHR mean or refer to the Regional Haze Rule.

xxxv. The initials RMC mean or refer to the Regional Modeling Center at the University of California Riverside.

xxxvi. The initials RPGs mean or refer to Reasonable Progress Goals.

xxxvii. The initials RPOs mean or refer to regional planning organizations.

xxxviii. The initials SCR mean or refer to selective catalytic reduction.

xxxix. The initials SIP mean or refer to State Implementation Plan.

xl. The initials SNCR mean or refer to selective non-catalytic reduction.

xli. The initials SO 2 mean or refer to sulfur dioxide.

xlii. The initials SOFA mean or refer to separated overfire air.

xliii. The initials TSD mean or refer to Technical Support Document.

xliv. The initials ULNB mean or refer to ultra-low NO X burners.

xlv. The initials URP mean or refer to Uniform Rate of Progress.

xlvi. The initials VOC mean or refer to volatile organic compounds.

xlvii. The initials WAQSR mean or refer to Wyoming Air Quality Standards and Regulations.

xlviii. The initials WEP mean or refer to Weighted Emissions Potential.

xlix. The initials WRAP mean or refer to the Western Regional Air Partnership.

l. The words Wyoming and State mean the State of Wyoming. Table of Contents

I. General Information

A. What should I consider as I prepare my

comments for EPA? II. Overview of Proposed Actions III. SIP and FIP Background IV. Background

A. Regional Haze B. Requirements of the CAA and EPA’s

Regional Haze Rule (RHR) C. Roles of Agencies in Addressing

Regional Haze V. Requirements for the Regional Haze SIPs

A. The CAA and the Regional Haze Rule B. Determination of Baseline, Natural, and

Current Visibility Conditions C. Determination of Reasonable Progress

Goals D. Best Available Retrofit Technology E. Long-Term Strategy F. Coordinating Regional Haze and

Reasonably Attributable Visibility Impairment G. Monitoring Strategy and Other

Implementation Plan Requirements H. Consultation With States and Federal

Land Managers (FLMs) VI. EPA’s Evaluation of Wyoming’s Regional Haze SIP A. Affected Class I Areas B. Baseline Visibility, Natural Visibility,

and Uniform Rate of Progress C. BART Determinations 1. BART-Eligible Sources 2. Sources Subject-to-BART a. Modeling Methodology b. Contribution Threshold c. Sources Identified by Wyoming as

Subject-to-BART 3. BART Determinations and Federally

Enforceable Limits a. Visibility Improvement Modeling b. Summary of BART Determinations and

Federally Enforceable Limits i. FMC Westvaco—Units NS–1A and NS–

1B ii. General Chemical Green River—Boilers

C and D iii. Basin Electric Laramie River Station—

Units 1–3 iv. PacifiCorp Dave Johnston—Units 3 and

4 v. PacifiCorp Jim Bridger Units 1–4 vi. PacifiCorp Naughton Units 1–3 vii. PacifiCorp Wyodak—Unit 1 D. Reasonable Progress Requirements 1. Visibility Impairing Pollutants and

Sources 2. Four-Factor Analyses a. Stationary Sources b. Summary of Reasonable Progress

Determinations and Limits i. Oil and Gas Area Sources ii. Mountain Cement Company Laramie

Plant—Kiln 3. Reasonable Progress Goals E. Long Term Strategy 1. Emission Inventories 2. Consultation and Emissions Reductions

for Other States’ Class I Areas 3. Mandatory Long-Term Strategy

Requirements a. Reductions Due to Ongoing Air Pollution

Programs b. Measures to Mitigate the Impacts of

Construction Activities c. Smoke Management d. Emission Limitations and Schedules for

Compliance e. Source Retirement and Replacement

Schedules f. Enforceability of Wyoming’s Measures g. Anticipated Net Effect on Visibility Due

to Projected Changes4. Our Conclusions on Wyoming’s LongTerm Strategy F. Coordination of RAVI and Regional Haze

Rule Requirements G. Monitoring Strategy and Other

Implementation Plan Requirements H. Consultation With FLMs I. Periodic SIP Revisions and 5-Year

Progress Reports VII. Federal Implementation Plan

A. Disapproval of the State’s NO X BART

Determinations and Federal Implementation Plan for NO X BART Determinations and Limits 1. Disapproval of the State’s Basin Electric

Laramie River Units 1–3 NO X BART Determination and FIP to Address NO X BART 2. Disapproval of the State’s PacifiCorp

Dave Johnston Unit 3 NO X BART Determination and FIP to Address NO X BART 3. Disapproval of the State’s PacifiCorp Jim

Bridger Unit 1 and 2 NO X BART Determination and FIP to Address NO X BART 4. Proposals in the Alternative for

PacifiCorp Jim Bridger Units 1, 2, 3, and 4 NO X BART 5. Disapproval of the State’s PacifiCorp

Wyodak Unit 1 NO X BART Determination and FIP to Address NO X BART B. Disapproval of the State’s NO X

Reasonable Progress Determinations and Federal Implementation Plan for NO X Reasonable Progress Determinations and Limits 1. PacifiCorp Dave Johnston—Units 1 and

2 C. Reasonable Progress Goals D. Federal Monitoring, Recordkeeping, and

Reporting Requirements E. Federal Implementation Plan for the

Long-Term Strategy F. Federal Implementation Plan for

Coordination of RAVI and Regional Haze Long-Term Strategy VIII. EPA’s Proposed Action IX. Statutory and Executive Order Reviews

I. General Information
A. What should I consider as I prepare my comments for EPA?

1. Submitting CBI. Do not submit CBI to EPA through http:// www.regulations.gov or email. Clearly mark the part or all of the information that you claim to be CBI. For CBI information in a disk or CD–ROM that you mail to EPA, mark the outside of the disk or CD–ROM as CBI and then identify electronically within the disk or CD–ROM the specific information that is claimed as CBI. In addition to one complete version of the comment that


### 33024 Federal Register / Vol. 77, No. 107 / Monday, June 4, 2012 / Proposed Rules

1 Visual range is the greatest distance, in kilometers or miles, at which a dark object can be viewed against the sky.

2 Areas designated as mandatory Class I Federal areas consist of national parks exceeding 6000 acres, wilderness areas and national memorial parks exceeding 5000 acres, and all international parks that were in existence on August 7, 1977. 42 U.S.C. includes information claimed as CBI, a copy of the comment that does not contain the information claimed as CBI must be submitted for inclusion in the public docket. Information so marked will not be disclosed except in accordance with procedures set forth in 40 CFR part 2.

2. Tips for Preparing Your Comments. When submitting comments, remember

to:

a. Identify the rulemaking by docket number and other identifying information (subject heading, Federal Register date and page number).

b. Follow directions—The agency may ask you to respond to specific questions or organize comments by referencing a Code of Federal Regulations (CFR) part or section number.

c. Explain why you agree or disagree; suggest alternatives and substitute language for your requested changes.

d. Describe any assumptions and provide any technical information and/ or data that you used.

e. If you estimate potential costs or burdens, explain how you arrived at your estimate in sufficient detail to allow for it to be reproduced.

f. Provide specific examples to illustrate your concerns, and suggest alternatives.

g. Explain your views as clearly as possible, avoiding the use of profanity or personal threats.

h. Make sure to submit your comments by the comment period deadline identified.
II. Overview of Proposed Actions

EPA is proposing to partially approve and partially disapprove a regional haze SIP revision submitted by the State of Wyoming on January 12, 2011. Specifically, we are proposing to disapprove the following:

• The State’s nitrogen oxides (NO X) best available retrofit technology (BART) determinations for PacifiCorp Dave Johnston Unit 3, PacifiCorp Jim Bridger Units 1 and 2, PacifiCorp Wyodak Unit 1, and Basin Electric Laramie River Units 1, 2, and 3.

• The State’s NO X reasonable progress determination for PacifiCorp Dave Johnston Units 1 and 2.

• Wyoming’s Reasonable Progress Goals (RPGs).

• The State’s monitoring, recordkeeping, and reporting requirements in Chapter 6.4 of the SIP.

• Portions of the State’s long-term strategy (LTS) that rely on or reflect other aspects of the regional haze SIP.

• The State’s SIP because it does not contain the necessary provisions to meet the requirements for the coordination of the review of the reasonably attributable visibility impairment (RAVI) and the regional haze LTS.

We are proposing to approve the remaining aspects of the State’s January 12, 2011, SIP submittal. We are also seeking comment on two alternative proposals related to the State’s NO X BART determination for PacifiCorp Jim Bridger Units 1 and 2.

We are proposing the promulgation of a FIP to address the deficiencies in the Wyoming regional haze SIP that we have identified in this proposal. The proposed FIP includes the following elements:

• NO X BART determinations and limits for PacifiCorp Dave Johnston Unit 3, PacifiCorp Jim Bridger Units 1 and 2, PacifiCorp Wyodak Unit 1, and Basin Electric Laramie River Units 1, 2, and 3.

• NO X reasonable progress determination and limits for PacifiCorp Dave Johnston Units 1 and 2.

• RPGs consistent with the SIP limits proposed for approval and the proposed FIP limits.

• Monitoring, recordkeeping, and reporting requirements applicable to all BART and reasonable progress sources for which there is a SIP or FIP emissions limit.

• LTS elements pertaining to emission limits and compliance schedules for the proposed BART and reasonable progress FIP emission limits.

• Provisions to ensure the coordination of the RAVI and regional haze LTS.

In lieu of our proposed FIP, or a portion thereof, we would propose approval of a SIP revision if the State submits such a revision and the revision matches the terms of our proposed FIP. We encourage the State to submit a SIP revision to replace the FIP, either before or after our final action.
III. SIP and FIP Background

The CAA requires each state to develop plans to meet various air quality requirements, including protection of visibility. CAA sections 110(a), 169A, and 169B. The plans developed by a state are referred to as SIPs. A state must submit its SIPs and SIP revisions to us for approval. Once approved, a SIP is enforceable by EPA and citizens under the CAA, also known as being federally enforceable. If a state fails to make a required SIP submittal or if we find that a state’s required submittal is incomplete or unapprovable, then we must promulgate a FIP to fill this regulatory gap. CAA section 110(c)(1). As discussed elsewhere in this notice, we are proposing to disapprove aspects of Wyoming’s regional haze SIP. We are proposing FIPs to address the deficiencies in Wyoming’s regional haze SIP. IV. Background A. Regional Haze

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 (PM 2.5 ) (e.g., sulfates, nitrates, organic carbon (OC), elemental carbon (EC), and soil dust), and their precursors ( e.g., sulfur dioxide (SO 2), NO X , and in some cases, ammonia (NH 3 ) and volatile organic compounds (VOC)). Fine particle precursors react in the atmosphere to form PM 2.5 , which impairs visibility by scattering and absorbing light. Visibility impairment reduces the clarity, color, and visible distance that one can see. PM 2.5 can also cause serious health effects and mortality in humans and contributes to environmental effects such as acid deposition and eutrophication.

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 1 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. Requirements of the CAA and EPA’s Regional Haze Rule (RHR)

In section 169A 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 2 which impairment


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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.’’ 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.’’

3 EPA’s regional haze regulations require subsequent updates to the regional haze SIPs. 40 CFR 51.308(g)–(i). 4 The preamble to the RHR provides additional details about the dv. 64 FR 35714, 35725 (July 1, 1999). 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.’’ 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.

Congress added section 169B to the CAA in 1990 to address regional haze issues. EPA promulgated a rule to address regional haze on July 1, 1999. 64 FR 35714 (July 1, 1999), codified at 40 CFR part 51, subpart P. The RHR 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 III of this preamble. The requirement to submit a regional haze SIP applies to all 50 states, the District of Columbia and the Virgin Islands. 40 CFR 51.308(b) requires states to submit the first implementation plan addressing regional haze visibility impairment no later than December 17,

2007. 3

Few states submitted a regional haze SIP prior to the December 17, 2007 deadline, and on January 15, 2009, EPA found that 37 states (including Colorado), the District of Columbia, and the Virgin Islands, had failed to submit SIPs addressing the regional haze requirements. 74 FR 2392. Once EPA has found that a state has failed to make a required submission, EPA is required to promulgate a FIP within two years unless the state submits a SIP and the Agency approves it within the two-year period. CAA § 110(c)(1). C. Roles of Agencies in Addressing Regional Haze

Successful implementation of theregional haze program will require longterm 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 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 particulate matter (PM) and other pollutants leading to regional haze.

The Western Regional Air Partnership (WRAP) 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 western United States. WRAP member state governments include: Alaska, Arizona, California, Colorado, Idaho, Montana, New Mexico, North Dakota, Oregon, South Dakota, Utah, Washington, and Wyoming. Tribal members include Campo Band of Kumeyaay Indians, Confederated Salish and Kootenai Tribes, Cortina Indian Rancheria, Hopi Tribe, Hualapai Nation of the Grand Canyon, Native Village of Shungnak, Nez Perce Tribe, Northern Cheyenne Tribe, Pueblo of Acoma, Pueblo of San Felipe, and Shoshone-Bannock Tribes of Fort Hall. V. Requirements for Regional Haze SIPs

The following is a summary of the requirements of the RHR. See 40 CFR 51.308 for further detail regarding the requirements of the rule.
A. The CAA and the Regional Haze Rule

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 BART 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 as the principal metric or unit for expressing visibility. See 70 FR 39104, 39118. This visibility metric expresses uniform changes in the degree of haze in terms of common increments across the entire range of visibility conditions, from pristine to extremely hazy conditions. Visibility expressed in deciviews is determined by using air quality measurements to estimate light extinction and then transforming the value of light extinction using a logarithm function. The deciview is a more useful measure for tracking progress in improving visibility than light extinction itself 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. 4

The deciview is used in expressing RPGs (which are interim visibility goals towards meeting the national visibility goal), defining baseline, current, and natural conditions, and tracking 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 anthropogenic air pollution by reducing anthropogenic emissions that cause regional haze. The national goal is a return to natural conditions, i.e., anthropogenic sources of air pollution would no longer impair visibility in Class I areas.


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5 Guidance for Estimating Natural Visibility Conditions Under the Regional Haze Rule, September 2003, EPA–454/B–03–005, available at http://www.epa.gov/ttncaaa1/t1/memoranda/ RegionalHaze

_envcurhr

_gd.pdf, (hereinafter referred to as ‘‘our 2003 Natural Visibility Guidance’’); and Guidance for Tracking Progress Under the Regional Haze Rule, September 2003, EPA–454/B–03–004, available at http://www.epa. gov/ttncaaa1/t1/memoranda/rh

_ tpurhr

_gd.pdf, (hereinafter referred to as our ‘‘2003 Tracking Progress Guidance’’). 6 The set of ‘‘major stationary sources’’ potentially subject-to-BART is listed in CAA section 169A(g)(7).

7 BART-eligible sources are those sources that have the potential to emit 250 tons or more of a visibility-impairing air pollutant, were not in To track changes in visibility over time at each of the 156 Class I areas covered by the visibility program (40 CFR 81.401–437), and as part of the process for determining reasonable progress, states must calculate the degree of existing visibility impairment at each Class I area at the time of each regional haze SIP submittal and periodically review progress every five years midway through each 10-year implementation 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 purpose 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. We have provided guidance to states regarding how to calculate baseline, natural and current visibility conditions. 5

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 visibility impairment for the 20 percent least impaired days and 20 percent most impaired days for each calendar year from 2000 to 2004. Using monitoring data for 2000 through 2004, states are required to calculate the average degree of visibility impairment for each Class I area, 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

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 two RPGs (i.e., two distinct goals, one for the ‘‘best’’ and one for the ‘‘worst’’ days) for every Class I area for each (approximately) 10-year implementation period. See 40 CFR 51.308(d), (f). 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 visibility conditions. 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 . Id.

In establishing RPGs, states are required to consider the following factors established in section 169A of the CAA and in our RHR at 40 CFR 51.308(d)(1)(i)(A): (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. 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’’ (URP) or the ‘‘glidepath’’) and the emission reduction measures needed to achieve that rate of progress over the 10-year period of the SIP. Uniform progress towards achievement of natural conditions by 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 state’s Class I areas. 40 CFR 51.308(d)(1)(iv). In determining whether a state’s goals for visibility improvement provide for reasonable progress toward natural visibility conditions, EPA is required to evaluate the demonstrations developed by the state pursuant to paragraphs 40 CFR 51.308(d)(1)(i) and (d)(1)(ii). 40 CFR 51.308(d)(1)(iii). D. Best Available Retrofit Technology

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, section 169A(b)(2)(A) of 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 major stationary sources 6 built between 1962 and 1977 procure, install, and operate the ‘‘Best Available Retrofit Technology’’ as determined by the state. Under the RHR, states are directed to conduct BART determinations for such ‘‘BART-eligible’’ 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.

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. 70 FR 39104. In making a BART 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. Regardless of source size or type, a state must meet the requirements of the CAA and our regulations for selection of BART, and the state’s BART analysis and determination must be reasonable in light of the overarching purpose of the regional haze program.

The process of establishing BART emission limitations can be logically broken down into three steps: First, states identify those sources which meet the definition of ‘‘BART-eligible source’’ set forth in 40 CFR 51.301; 7 second,


### 33027 Federal Register / Vol. 77, No. 107 / Monday, June 4, 2012 / Proposed Rules

operation prior to August 7, 1962, but were in existence on August 7, 1977, and whose operations fall within one or more of 26 specifically listed source categories. 40 CFR 51.301. states determine which of such sources ‘‘emits any air pollutant which may reasonably be anticipated to cause or contribute to any impairment of visibility in any such area’’ (a source which fits this description is ‘‘subject to BART’’); and third, for each source subject-to-BART, states then identify the best available type and level of control for reducing emissions.

States must address all visibilityimpairing pollutants emitted by a source in the BART determination process. The most significant visibility impairing pollutants are SO 2 , NO X , and PM. EPA has stated that states should use their best judgment in determining whether VOC or NH 3 compounds impair visibility in Class I areas.

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 deciview. 40 CFR part 51, appendix Y, section III.A.1.

In their SIPs, states must identify the sources that are subject-to-BART and document their BART control determination analyses for such sources. In making their BART determinations, section 169A(g)(2) of the CAA requires that states consider the following factors when evaluating potential control technologies: (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.

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. CAA section 169(g)(4) and 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. See CAA section 110(a). As noted above, the RHR allows states to implement an alternative program in lieu of BART so long as the alternative program can be demonstrated to achieve greater reasonable progress toward the national visibility goal than would BART.

E. Long-Term Strategy

Consistent with the requirement in section 169A(b) of the CAA that states include in their regional haze SIP a 10 to 15 year strategy for making reasonable progress, section 51.308(d)(3) of the RHR requires that states include a LTS in their regional haze SIPs. The LTS is the compilation of all control measures a state will use during the implementation period of the specific SIP submittal to meet 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. Id. at (d)(3)(ii). 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 visibilityimpairment in developing their longterm strategy, including stationary, minor, mobile, and area sources. At a minimum, states must describe how each of the following seven factors listed below are 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; and (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

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 40 CFR 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 RAVI and regional haze, 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 review 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, i.e., review and use of monitoring data from the network. The monitoring strategy is due with the first


### 33028 Federal Register / Vol. 77, No. 107 / Monday, June 4, 2012 / Proposed Rules

8 The IMPROVE program is a cooperative measurement effort governed by a steering committee composed of representatives from Federal agencies (including representatives from EPA and the FLMs) and regional planning organizations. 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 anthropogenic 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. 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.

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 requirement to evaluate sources for BART applies only to the first regional haze SIP. Facilities subject-to-BART must continue to comply with the BART provisions of section 51.308(e), as noted above. 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.

VI. EPA’s Evaluation of Wyoming’s Regional Haze SIP

A. Affected Class I Areas

Pursuant to 40 CFR 51.308(d), the State identified seven mandatory Class I areas in Wyoming: Grand Teton National Park, Yellowstone National Park, Bridger Wilderness, Fitzpatrick Wilderness, North Absaroka Wilderness, Teton Wilderness, and Washakie Wilderness.

B. Baseline Visibility, Natural Visibility, and Uniform Rate of Progress

As required by 40 CFR 51.308(d)(2), Wyoming provided baseline visibility, natural visibility, and the URP for each Class I area in the State. Natural background visibility, as defined in our 2003 Natural Visibility Guidance, is estimated by calculating the expected light extinction using default estimates of natural concentrations of fine particle components adjusted by site-specific estimates of humidity. This calculation uses the IMPROVE equation, which is a formula for estimating light extinction from the estimated natural concentrations of fine particle components (or from components measured by the IMPROVE monitors). As documented in our 2003 Natural Visibility Guidance, EPA allows states to use ‘‘refined’’ or alternative approaches to this guidance to estimate the values that characterize the natural visibility conditions of Class I areas.

One alternative approach is to develop and justify the use of alternative estimates of natural concentrations of fine particle components. Another alternative is to use the ‘‘new IMPROVE equation’’ that was adopted for use by the IMPROVE Steering Committee in December 2005. 8 The purpose of this refinement to the ‘‘old IMPROVE equation’’ is to provide more accurate estimates of the various factors that affect the calculation of light extinction.

Wyoming used the new IMPROVE equation to calculate natural conditions and baseline visibility. The natural condition for each Class I area represents the visibility goal expressed in deciviews for the 20% worst days and the 20% best days that would exist if there were only naturally occurring visibility impairment. In accordance with 40 CFR 51.308(d)(2)(iii), the State calculated natural visibility conditions based on available monitoring information and appropriate data analysis techniques and in accordance with our 2003 Natural Visibility Guidance. The State also calculated the number of deciviews by which baseline conditions exceed natural conditions at each of its Class I areas to meet the requirements of 40 CFR 51.308(d)(2)(iv)(A).

Wyoming established the baseline visibility for the best and worst visibility days for each Class I area based on data from the IMPROVE monitoring sites. Each IMPROVE monitor collects particulate concentration data which are converted into reconstructed light extinction through a complex calculation using the IMPROVE equation (see Chapter 13 of the SIP for more information on reconstructed light extinction and the IMPROVE equation). Per 40 CFR 51.308(d)(2)(i), the State calculated baseline visibility using a five-year average (2000 to 2004) of IMPROVE data for both the 20% best and 20% worst days. The State’s baseline calculations were made in accordance with our 2003 Tracking Progress Guidance.

Pursuant to 40 CFR 51.308(d)(1)(i)(B), the State calculated the URP for each of its Class I areas. For the 20% worst days, the URP is the calculation of the deciview reduction needed to achieve natural conditions by 2064. For the 20% worst days, the State calculated the URP


### 33029 Federal Register / Vol. 77, No. 107 / Monday, June 4, 2012 / Proposed Rules

9 Wyoming has elected to submit its RH SIP pursuant to the requirements of 40 CFR 51.309. For states electing to submit under section 309, States do not have to do a BART analysis for SO 2 . SO 2 controls are included in the backstop trading program under 40 CFR 51.309(d)(4). 10 Note that our reference to CALPUFF encompasses the entire CALPUFF modeling system, which includes the CALMET, CALPUFF, and CALPOST models and other pre and post processors. The different versions of CALPUFF have corresponding versions of CALMET, CALPOST, etc. which may not be compatible with previous versions (e.g., the output from a newer version of CALMET may not be compatible with an older version of CALPUFF). The different versions of the CALPUFF modeling system are available from the model developer at http://www.src.com/ verio/download/download.htm. in deciviews per year using the following formula: URP = [Baseline Condition

¥ Natural Condition]/60 years. In order to determine the uniform progress needed by 2018 to be on the path to achieving natural visibility conditions by 2064, the State multiplied the URP by the 14 years in the first planning period (2004–2018).

Table 1 shows the baseline visibility, natural conditions, and URP for each of the Class I areas. As indicated by the table, some Class I areas share a single monitor because of the proximity of the areas to each other.



### TABLE 

### 1—BASELINE 

### V ISIBILITY 

### , N ATURAL 

### C ONDITIONS



### , AND 

### URP FOR 

### WYOMING 

### C LASS 

### I A REAS

20% Worst days 20% Best days

Wyoming class I areas Monitor

name 2000–2004 Baseline (deciview) 2018 URP (deciview) Reduction needed to

reach 2018 URP

(delta deciview) 2064 Natural conditions (deciview) Delta baseline— 2064 natural

conditions 2000–2004 Baseline (deciview)

Yellowstone National Park

Grand Teton National Park Teton Wilderness. YELL2 ... 11.8 10.5 1.3 6.44 5.36 2 .58

North Absaroka Wilderness

Washakie Wilderness. NOABI ... 11.5 10.4 1.1 6.83 4.67 2 .0

Bridger Wilderness

Fitzpatrick Wilderness. BRID1 .... 11.1 10.0 1.1 6.45 4.65 2 .1

We have reviewed Wyoming’s baseline visibility, natural conditions, and URP. We find they have been calculated correctly and are proposing to approve them.

C. BART Determinations

BART is an element of Wyoming’s LTS for the first implementation period. As discussed in more detail in section VI.D of this notice, the BART evaluation process consists of three components:(1) An identification of all the BARTeligible sources; (2) an assessment of whether those BART-eligible sources are in fact subject-to-BART; and (3) a determination of any BART controls. Wyoming addressed these steps as follows: 1. BART Eligible Sources

The first step of a BART evaluation is to identify all the BART-eligible sources within the state’s boundaries. Wyoming identified the BART-eligible sources in Wyoming by utilizing the approach set out in the BART Guidelines (70 FR 39158). This approach provides three criteria for identifying BART-eligible sources: (1) One or more emission units at the facility fit within one of the 26 categories listed in the BART Guidelines; (2) the emission unit or units began operation on or after August 6, 1962, and were in existence on August 6, 1977; and (3) combinedpotential emissions of any visibilityimpairing pollutant from the units that meet the criteria in (1) and (2) are 250 tons or more per year. Wyoming reviewed source permits and emission data from 2001–2003 to identify facilities in the BART source categories with potential emissions of 250 tons per year or more for any visibility-impairing pollutant from any unit or units that were in existence on August 7, 1977 and began operation on or after August 7, 1962. The BART Guidelines direct states to address SO 2 , 9 NO X , and direct PM (including both coarse particulate matter (PM 10) and PM 2.5 ) emissions as visibility-impairing pollutants and to exercise their ‘‘best judgment to determine whether VOC or NH 3 emissions from a source are likely to have an impact on visibility in an area.’’ (70 FR 39162).

The State analyzed the emissions from VOC and NH 3 from sources in the State and eliminated them from further consideration for BART controls. The State evaluated the BART-eligible sources and determined emissions of VOC and NH 3 were negligible. Thus, the State has eliminated VOC and NH 3 from further consideration for BART controls.

We have reviewed this information and propose to accept this determination.

The State determined the following were BART-eligible sources: PacifiCorp Jim Bridger, P4 Production, PacifiCorp Naughton, OCI Wyoming, FMC Granger, Dyno Nobel, FMC Westvaco, Sinclair Casper Refinery, Basin Electric Laramie River, Black Hills Neil Simpson 1, PacifiCorp Wyodak, Sinclair—Sinclair Refinery, PacifiCorp Dave Johnston, and General Chemical Green River. We have reviewed this information and propose to accept this determination.
2. Sources Subject-to-BART

The second step of the BARTevaluation is to identify those BARTeligible sources that may reasonably be anticipated to cause or contribute to any visibility impairment at any Class I area,i.e., those sources that are subject-toBART. The BART Guidelines allow States to consider exempting some BART-eligible sources from further BART review because they may not reasonably be anticipated to cause or contribute to any visibility impairment in a Class I area. Consistent with the BART Guidelines, Wyoming performeddispersion modeling on the BARTeligible sources to assess the extent of their contribution to visibility impairment at surrounding Class I areas.
a. Modeling Methodology

The BART Guidelines provide that states may use the CALPUFF 10 modeling system or another appropriate model to predict the visibility impacts from a single source on a Class I area and to, therefore, determine whether an individual source is anticipated to cause


### 33030 Federal Register / Vol. 77, No. 107 / Monday, June 4, 2012 / Proposed Rules

11 The State of Wyoming performed a refined CALPUFF visibility modeling analysis for the two BART-eligible units at the FMC Wyoming Granger Facility and demonstrated that the predicted 98th percentile impacts at Bridger Wilderness Area and Fitzpatrick Wilderness Area would be below 0.5 dv for all meteorological periods modeled. This modeling used higher-resolution meteorological data as compared to the data used by the State for the initial screening modeling that identified the facility as subject-to-BART.

12 CALPUFF modeling results, which provide the maximum change in visibility are summarized in the WY BART Screening Analysis Results and the WY BART Screening Analysis Results DV Frequency, which can also be found in Chapter 6 of the State’s TSD.

13 See our BART Guidelines, Section III.A.3. or contribute to impairment of visibility in Class I areas, i.e., ‘‘is subject to BART.’’ The Guidelines state that CALPUFF is the best regulatory modeling application currently available for predicting a single source’s contribution to visibility impairment (70 FR 39162).

The BART Guidelines also recommend that States develop a modeling protocol for making individual source attributions, and suggest that states may want to consult with EPA and their RPO to address any issues prior to modeling. Wyoming used the CALPUFF model for Wyoming BART sources in accordance with a protocol it developed titled BART Air Modeling Protocol Individual Source Visibility Impairment Analysis, March 2006, which was approved by EPA and is included in Chapter 6 of the State’s TSD. The Wyoming protocol follows recommendations for long-range transport described in appendix W to 40 CFR part 51, Guideline on Air Quality Models, and in EPA’s Interagency Workgroup on Air Quality Modeling (IWAQM) Phase 2 Summary Report and Recommendations for Modeling Long-Range Transport Impacts as recommended by the BART Guidelines. (40 CFR part 51, appendix Y, section III.A.3). To determine if each BART-eligible source has a significant impact on visibility, Wyoming used the CALPUFF model to estimate daily visibility impacts above estimated natural conditions at each Class I area within 300 km of any BART-eligible facility, based on maximum actual 24-hour emissions over a three year period (2001–2003). b. Contribution Threshold For States using modeling to determine the applicability of BART to single sources, the BART Guidelines note that the first step is to set a contribution threshold to assess whether the impact of a single source is sufficient to cause or contribute to visibility impairment at a Class I area. The BART Guidelines state that, ‘‘[a] single source that is responsible for a 1.0 deciview change or more should be considered to ‘cause’ visibility impairment.’’ (70 FR 39104, 39161). The BART Guidelines also state that ‘‘the appropriate threshold for determining whether a source contributes to visibility impairment may reasonably differ across States,’’ but, ‘‘[a]s a general matter, any threshold that you use for determining whether a source ‘‘contributes’’ to visibility impairment should not be higher than 0.5 deciviews.’’ Id. Further, in setting a contribution threshold, States should ‘‘consider the number of emissions sources affecting the Class I areas at issue and the magnitude of the individual sources’ impacts.’’ The Guidelines affirm that States are free to use a lower threshold if they conclude that the location of a large number of BART-eligible sources in proximity to a Class I area justifies this approach.

Wyoming used a contribution threshold of 0.5 deciviews fordetermining which sources are subjectto-BART. By using a contribution threshold of 0.5 deciviews, Wyomingexempted seven of the fourteen BARTeligible sources in the State from further review under the BART requirements. Based on the modeling results, the State determined that P4 Production, FMC Granger, 11 and OCI Wyoming had an impact of .07 deciview, 0.39 deciview, and 0.07 deciview, respectively, at Bridger Wilderness. Black Hills Neil Simpson 1, Sinclair Casper Refinery, and Sinclair—Sinclair Refinery have an impact of 0.27 deciview, 0.06 deciview, and 0.12 deciview, respectively, at Wind Cave. Dyno-Nobel had an impact of 0.22 deciview at Rocky Mountain National Park. These sources’ modeled visibility impacts fell below the State’s threshold of 0.5 deciview and were determined not to be subject-to-BART. 12 Given the relatively limited impact on visibility from these seven sources, we propose to agree with Wyoming that 0.5 deciviews is a reasonable threshold for determining whether its BART-eligible sources are subject-to-BART.

Because our recommended modeling approach already incorporates choices that tend to lower peak daily visibility impact values, 13 our BART Guidelines state that a State should compare the 98th percentile (as opposed to the 90th or lower percentile) of CALPUFF modeling results against the ‘‘contribution’’ threshold established by the State for purposes of determining BART applicability. Wyoming used a 98th percentile comparison that we find appropriate. Further explanation on use of the 98th versus 90th percentile value is provided at 70 FR 39121.

c. Sources Identified by Wyoming as Subject-to-BART

Table 2 shows the sources identified by the State as subject-to-BART and the results of the CALPUFF modeling.



### TABLE 

### 2—WYOMING 

### S UBJECT



### -TO 

### -BART S OURCES AND 

### CALPUFF M ODELING 

### R ESULTS

Facility name Subject-to-BART units State modeling results—98th

percentile delta-deciview

PacifiCorp—Jim Bridger ..................................................................... Units 1–4 ........................... ........................................... 3 .1 Basin Electric—Laramie River ............................................................ Units 1, 2 and 3 ....................... ..................................... 3 .68 PacifiCorp—Dave Johnston ............................................................... Units 3 and 4 ........................... ..................................... 3 .30 PacifiCorp—Naughton ........................................................................ Units 1–3 ........................... ........................................... 4 .36 PacifiCorp—Wyodak ........................................................................... Unit 1 ............................. ............................................... 1 .66 FMC—Westvaco ................................................................................. Units NS–1A and NS–1B ............. ................................ 1 .3 General Chemical—Green River ........................................................ Boilers C and D ............................ ................................ 1 .36


### 33031 Federal Register / Vol. 77, No. 107 / Monday, June 4, 2012 / Proposed Rules

14 Per the BART Guidelines, States must use CALPUFF, or other appropriate dispersion model to determine the visibility improvement expected at a Class I area from the potential BART control technology applied to the source. 70 FR 39170.

15 A summary of EPA’s modeling methodology and results can be found in the docket under EPA BART and RP Modeling for Wyoming Sources.

16 The cumulative visibility impact will be higher than the 98th percentile impact that is shown in the BART summary tables. We are proposing to approve theState’s determination of the subject-toBART sources. 3. BART Determinations and Federally Enforceable Limits

The third step of a BART evaluation is to perform the BART analysis. The BART Guidelines (70 FR 39164) describe the BART analysis as consisting of the following five steps:

• Step 1: Identify All Available Retrofit Control Technologies;

• Step 2: Eliminate Technically Infeasible Options;

• Step 3: Evaluate Control Effectiveness of Remaining Control Technologies;

• Step 4: Evaluate Impacts and Document the Results; and

• Step 5: Evaluate Visibility Impacts. In determining BART, the State must consider the five statutory factors in section 169A of the CAA: (1) The costsof compliance; (2) the energy and nonair 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. See also 40 CFR 51.308(e)(1)(ii)(A). The five-factor analysis occurs during steps 4 and 5 of the BART analysis.

We find that Wyoming considered all five steps above in its BART determinations, but we find that its consideration of visibility improvement was inadequate, as explained below.
a. Visibility Improvement Modeling

The BART Guidelines provide that states may use the CALPUFF modeling system or another appropriate model to determine the visibility improvement expected at a Class I area from potential BART control technologies applied to the source. The BART Guidelines also recommend that states develop a modeling protocol for modeling visibility improvement, and suggest that states may want to consult with EPA and their RPO to address any issues prior to modeling. Wyoming developed a modeling protocol titled BART Air Modeling Protocol Individual Source Visibility Assessments for BART Control Analyses, September 2006, for sources to use when they performed their BART analysis (see Chapter 6 of the State’s TSD). The Wyoming protocol follows recommendations for long-range transport described in appendix W to 40 CFR part 51, Guideline on Air Quality Models, and in EPA’s Interagency Workgroup on Air Quality Modeling (IWAQM) Phase 2 Summary Report and Recommendations for Modeling Long Range Transport Impacts, as recommended by the BART Guidelines (40 CFR part 51, appendix Y, section III.D.5).

For the subject-to-BART PacifiCorp sources, the State’s analyses provide visibility improvement modeling results that combine the visibility improvement from NO X , PM, and SO 2 control options. 14 From the State’s modeling results, EPA could not ascertain what the visibility improvement would be from an individual NO X or PM control option. For Basin Electric’s Laramie River Station, the State did not provide the visibility improvement for the SNCR control option or for PM controls. While we are able to propose approval of the State’s PM BART determinations without having additional visibility improvement modeling for PM controls, as discussed below, additional visibility improvement modeling to address the NO X BART controls was needed and subsequently performed by EPA. 15 b. Summary of BART Determinations and Federally Enforceable Limits

For the subject-to-BART sources, the State provided BART analyses, as well as additional technical information and materials, in Attachment A to the SIP. Chapter 6 of the SIP provides a summary of the five-factor analyses. As noted above, EPA performed the NO X visibility improvement modeling for the control technology options analyzed for the subject-to-BART PacifiCorp

sources. 16 EPA also performed modeling for the visibility improvement SNCR for Basin Electric Laramie River Units 1, 2, and 3. In addition, Wyoming did not provide control efficiencies in their BART analysis for PM and NO X BART controls for the PacifiCorp sources nor did the State provide analysis for NO X BART controls for Basin Electric Laramie River Units 1, 2, and 3. Therefore, EPA calculated the control efficiencies shown for the PM and NO X BART controls for the PacifiCorp sources and NO X BART controls for Basin Electric from the emission reductions reported by Wyoming in Chapter 6.5 and Appendix A of their SIP.

EPA is proposing to approve the State’s BART determinations for the following: NO X and PM BART for FMC Westvaco Unit NS–1A and NS–1B; NO X and PM BART for General Chemical Green River Boiler C and Boiler D; PM BART for Basin Electric Laramie River Units 1, 2, and 3; PM BART for PacifiCorp Dave Johnston Unit 3; NO X and PM BART for PacifiCorp Dave Johnston Unit 4; PM BART for PacifiCorp Jim Bridger Unit 1 and Unit 2; NO X and PM BART (including LTS controls) for PacifiCorp Jim Bridger Unit 3 and Unit 4; NO X and PM BART for PacifiCorp Naughton Units 1, 2, and 3; PM BART for PacifiCorp Wyodak Unit 1. A summary of the BART determination for each source is provided below.

EPA is proposing to disapprove the State’s NO X BART determinations, and we are proposing to issue a BART FIP, for the following units: PacifiCorp Dave Johnston Unit 3; PacifiCorp Jim Bridger Units 1 and 2; PacifiCorp Wyodak Unit 1; and Basin Electric Laramie River Units 1, 2, and 3. EPA’s rationale for disapproving the State’s BART determinations for these units, as well as EPA’s BART FIP determinations and emission limits can be found in section VII.A of this notice.

i. FMC Westvaco—Units NS–1A and NS–1B Background

FMC’s Westvaco facility is a trona mine and sodium products plant located in Sweetwater County, Wyoming. FMC Westvaco has two existing coal-fired boilers, Unit NS–1A and Unit NS–1B, that are subject to BART. Unit NS–1A and Unit NS–1B each have a design heat input rate of 887 MMBtu/hr and wereconstructed in 1975. They are both wallfired, wet-bottom boilers burning subbituminous coal. The State’s BART determination can be found in Chapter 6.5.2 and Attachment A of the SIP.

NO X BART Determination

Units NS–1A and NS–1B are currently controlled with combustion air control with a permit limit of 0.7 lb/MMBtu (3- hour rolling average). The State determined that low NO X burners (LNBs) and overfired air (OFA), LNBs and OFA with selective non-catalytic reduction (SNCR), and LNBs and OFA with selective catalytic reduction (SCR) were technically feasible for reducing NO X emissions at Unit NS–1A and NS– 1B. The State did not identify any technically infeasible options. The State did not identify any energy or non-air quality environmental impacts that would preclude the selection of any of the controls evaluated, and there are no remaining-useful-life issues for this


### 33032 Federal Register / Vol. 77, No. 107 / Monday, June 4, 2012 / Proposed Rules

17 Incremental cost effectiveness for each option is the difference in total annual costs between that option and the next most stringent option, divided by the difference in emissions, after controls have been applied, between those two control options. source. A summary of the State’s NO X BART analysis and the visibility impacts is provided in Table 3. Baseline NO X emissions are 2,719.5 tpy for each unit based on a heat input rate of 887 MMBtu/hr and 8,760 hours of operation

per year.



### TABLE 

### 3—S UMMARY OF 

### FMC W ESTVACO 

### U NIT 

### NS–1A AND 

### U NIT 

### NS–1B NO X 

### BART A NALYSIS 

### *

Control technology Control efficiency (%) Emission rate (lb/MMBtu) (30-day rolling

average) Emission reduction

(tpy) Annualized costs Average cost effectiveness ($/ton) Visibility improvement (Delta dv for the maximum 98th percentile impact at Bridger Wilderness

Area)

LNB + SOFA .................... 50 0.35 1,359.7 $413,145 $304 0.13 LNB + SOFA + SNCR ..... 70 0.21 1,903.6 1,281,851 673 0.19 LNB + SOFA + SCR ........ 85 0.10 2,331.0 1,281,851 3,493 0.24

* This table reflects the costs and visibility improvements per boiler.

Incremental cost effectiveness for the controls evaluated is as follows: LNB plus SOFA and SNCR: $1,597/ton, and LNB plus SOFA and SCR: $16,051/

ton. 17

Based on its consideration of the five factors, the State determined that LNBs plus OFA are reasonable for BART. The State determined that the other control options were not reasonable based on the cost effectiveness and associated visibility improvement. The State has determined that NO X BART emission limits for FMC Westvaco Unit NS–1A and Unit MS–1B are 0.35 lb/MMBtu (30- day rolling average), 284 lb/hr (30-day rolling average), and 1,244 tpy.

We agree with the State’s conclusions, and we are proposing to approve its NO X BART determinations for FMC Westvaco Unit NS–1A and Unit NS–1B.

PM BART Determination

Unit NS–1A and Unit NS–1B are currently controlled for PM emissions by electrostatic precipitators (ESPs). The units currently have a PM emission limit of 0.05 lb/MMBtu. The State determined that fabric filters on the wet scrubber, addition of an ESP downstream of the wet scrubber, and replacement of the ESPs with fabric filters were technically feasible control options. The State did not identify any energy or non-air quality environmental impacts that would preclude the selection of any of the controlsevaluated, and there are no remaininguseful-life issues for this source. A summary of the State’s PM BART analysis is provided in Table 4 below. Baseline PM emissions are 197 tpy for each unit based on a heat input rate of 887 MMBtu/hr and 8,760 hours of operation per year.



### TABLE 

### 4—S UMMARY OF 

### FMC W ESTVACO 

### U NIT 

### NS–1A AND 

### U NIT 

### NS–1B PM BART A NALYSIS 

### *

Control technology Control efficiency (%) Emission rate (lb/MMBtu) (30-day rolling

average) Emission reduction

(tpy) Annualized costs Average cost effectiveness ($/ton)

Fabric Filter on Wet Scrubber ....................... 21.4 0 .04 41.7 $1,791,364 $42,948 ESP after Wet Scrubber ................................ 63.3 0 .019 123.3 3,507,617 28,448 Replace ESP with Fabric Filter ...................... 71.3 0 .015 138.8 4,116,036 29,654

* This table reflects the costs and visibility improvements per boiler.

Given the high cost of controls, which are higher than what EPA, or other states have considered reasonable for PM, FMC did not evaluate the visibility improvement that would result from the PM controls evaluated. Previous visibility modeling analyses from the source indicate that the contribution in visibility degradation from PM is minor when compared to the contributing effects of NO X and SO 2 . Results from FMC’s visibility modeling screening and analysis confirm this conclusion and are discussed in further detail within the comprehensive visibility analysis included as part of FMC’s BART application (see Attachment A to the SIP). The State agreed with FMC’s conclusions and did not require FMC to perform additional visibility analyses for the PM control options.

The State determined that the current ESP control was reasonable for PM BART. The State rejected other controls as being reasonable for BART because of the high cost effectiveness. The State has determined that the PM BART emission limits for FMC Westvaco Unit NS–1A and NS–1B are 0.05 lb/MMBtu, 45.0 lb/hr, and 197 tpy.

We agree with the State’s conclusions, and we are proposing to approve its PM BART determinations for FMC Westvaco Unit NS–1A and Unit NS–1B. ii. General Chemical Green River— Boilers C and D

General Chemical Green River is a trona mine and sodium products plant.General Chemical’s two existing coalfired boilers, C and D, are co-located at the facility power plant. Both boilers burn low sulfur bituminous coal, and they supply power and process steam to mining and ore processing operations. Both boilers are tangentially fired using in-line coal pulverizers. The firing rate for Boiler C is 534 MMBtu/hr and 880 MMBtu/hr for Boiler D. The State’s BART determination can be found in Chapter 6.5.3 and Attachment A of the
SIP.


### 33033 Federal Register / Vol. 77, No. 107 / Monday, June 4, 2012 / Proposed Rules

NO X BART Determination

Boiler C and Boiler D are currently controlled with LNBs plus OFA with a permit limit of 0.7 lb/MMBtu (3-hour rolling average). On August 7, 2009, the State issued a BART permit to General Chemical that required the source to meet a NO X emission limit of 0.32 lb/ MMBtu (30-day rolling average) for Boiler C and Boiler D. The State assumed the source could meet this emission limit with the installation and operation of new LNBs with the existing OFA. Upon further investigation, the source determined it could not meet a limit of 0.32 lbs/MMBtu with new LNBs and the existing OFA.

In response to the additional information from the source, the State reexamined its BART determination for Boiler C and D. The State determined that installing SOFA in addition to the existing LNBs and OFA could achieve an emission limit of 0.28 lb/MMBtu. Since SOFA in conjunction with the existing NO X controls could achieve better emission reductions than new LNBs plus OFA, the State eliminated the latter from further consideration in the BART analysis. The State determined SNCR and SCR were also technically feasible. The State did not identify any technically infeasible options.

The State did not identify any energy or non-air quality environmental impacts that would preclude the selection of any of the controlsevaluated, and there are no remaininguseful-life issues for this source. A summary of the State’s NO X BART analysis and visibility impacts is provided in Tables 5 and 6 below. Baseline NO X emissions are 1,167 tpy for Boiler C and 1,816 tpy for Boiler D based on an average of 2001–2003 actual emissions.



### TABLE 

### 5—S UMMARY OF 

### G ENERAL 

### C HEMICAL

### —G REEN 

### R IVER 

### B OILER 

### C NO X 

### BART A NALYSIS

Control technology Control efficiency (%) Emission rate (lb/MMBtu) (30-day rolling

average) Emission reduction

(tpy) Annualized costs Average cost effectiveness ($/ton) Visibility improvement (Delta dv for the maximum 98th percentile impact at Bridger Wilderness Area)

Existing LNBs with SOFA 44 0.28 512 $757,711 $1,480 0.05 SNCR ............................... 50 0.35 584 1,433,720 2,455 0.08 SCR .................................. 80 0.14 934 2,434,809 2,607 0.14

Incremental cost effectiveness for the control technologies evaluated is as follows: SNCR: $4,782/ton, and SCR: $3,156/ton.



### TABLE 

### 6—S UMMARY OF 

### G ENERAL 

### C HEMICAL

### —G REEN 

### R IVER 

### B OILER 

### D NO X 

### BART A NALYSIS

Control technology Control efficiency (%) Emission rate (lb/MMBtu) (30-day rolling

average) Emission reduction

(tpy) Annualized costs Average cost effectiveness ($/ton) Visibility improvement (Delta dv for the maximum 98th percentile impact at Bridger Wilderness Area)

Existing LNBs with SOFA 41 0.28 737 $943,549 $1,280 0.07 SNCR ............................... 50 0.35 908 1,486,581 3,176 0.12 SCR .................................. 80 0.14 1,453 3,399,266 3,510 0.17

Incremental cost effectiveness for the control technologies evaluated is as follows: SNCR: $2,913/ton, and SCR: $4,342/ton.

Based on its consideration of the five factors, the State determined that NO X BART is the existing LNBs with new SOFA, or a comparable performing technology. The State determined that SNCR and SCR were not reasonable based on the high cost effectiveness and low visibility improvement. The State determined the NO X BART emission limits for General Chemical Green River Boiler C are 0.28 lb/MMBtu (30-day rolling average), 149.5 lb/hr (30-day rolling average) and 654.9 tpy, and that the NO X BART emission limits for Boiler D are 0.28 lb/MMBtu (30-day rolling average), 246.4 lb/hr (30-day rolling average) and 1,079.2 tpy. We agree with the State’s conclusions, and we are proposing to approve its NO X BART determinations for General Chemical Green River—Boiler C and D.

PM BART Determination

Boiler C and D are currently controlled by ESPs with a permit limit of 50 lb/hr and 80 lb/hr, respectively. General Chemical addressed PM emissions through an abbreviated analysis by using PM BART information from FMC Westvaco, as discussed above. The facilities are similar in size and located about ten miles apart. Baseline PM emissions for Boiler C are 98 tpy and 161 tpy for Boiler D based on the average of 2001–2003 actual emissions. As discussed above, visibility modeling screening and analyses for FMC Westvaco indicate that the contribution in visibility degradation from PM for a source comparable to Boiler C and Boiler D is minor. Additionally, costs for controlling PM from similar boilers are high as indicated by FMC analysis for
Westvaco.

The State accepted General Chemical’s abbreviated PM BART analysis. The State determined that the current ESP control was reasonable for PM BART. The State rejected other controls as being reasonable for BART because of the high cost effectiveness. The State determined that the PM BART emission limits for Boiler C are 0.09 lb/ MMBtu, 50 lb/hr, and 219 tpy, and that the PM BART emissions limits for Boiler D are 0.09 lb/MMBtu, 80 lb/hr, and 350.4 tpy.


### 33034 Federal Register / Vol. 77, No. 107 / Monday, June 4, 2012 / Proposed Rules

We agree with the State’s conclusions, and we are proposing to approve its PM BART determination for General Chemical Green River Boiler C and D.

iii. Basin Electric Laramie River Station—Units 1–3

Basin Electric Laramie River Station is located in Platte County, Wyoming. Laramie River Station is comprised of three 550-MW dry-bottom, wall-fired boilers (Units 1, 2, and 3) burning subbituminous coal for a total net generating capacity of 1,650 MW. All three units are subject-to-BART. The State’s BART determination can be found in Chapter 6.5.8 and Attachment A of the SIP (The NOx BART analysis is discussed in section VII.A of this notice).

PM BART Determination

Laramie River Units 1, 2, and 3 are currently controlled with ESPs with a permit limit of 0.03 lb/MMBtu. The State determined that fabric filters were technically feasible for Unit 3 but not Units 1 and 2. Units 1 and 2 are controlled with wet flue gas desulfurization and fabric filters cannot be used downstream of such a system. The State determined that flue gas treatment and GE Max-9 hybrid were technically infeasible for all three units. Thus, the only technically feasible control option for PM is fabric filters on Unit 3.

The State did not identify any energy or non-air quality environmental impacts that would preclude the selection of any of the controlsevaluated, and there are no remaininguseful-life issues for this source. A summary of the State’s PM BART analysis for Unit 3 is provided in Table 7 below. Baseline PM emissions are 716 tpy for the unit based on 2001–2003 actual emissions.



### TABLE 

### 7—S UMMARY OF 

### BASIN 

### E LECTRIC 

### LARAMIE 

### R IVER 

### U NIT 

### 3 PM BART A NALYSIS

Control technology Control efficiency (%) Emission rate (lb/MMBtu) (30-day rolling

average) Emission reduction

(tpy) Annualized costs Average cost effectiveness ($/ton)

Fabric Filter—Peak Rate for Lost Generating

Costs ............................................................ 50 0.015 358 $194,809,000 $54,707Fabric Filter Non-Peak Rate for Lost Generating Costs ................................................... 50 0.015 358 134,934,000 40,156

The State did not provide visibility improvement modeling for fabric filters, but EPA is proposing to conclude this is reasonable based on the high cost effectiveness of fabric filters at each of the units, which is higher than EPA or other state have considered reasonable for PM BART.

Based on its consideration of the five factors, the State determined that the current ESPs are reasonable for PM BART, as fabric filters on Unit 3 are not cost-effective and there are no other technically feasible controls for Units 1 and 2. The State determined the PM BART emission limits for Laramie River Unit 1 and Unit 2 are 0.03 lb/MMBtu, 193 lb/hr, and 844 tpy, and the PM BART emission limits for Laramie River Unit 3 are 0.03 lb/MMBtu, 198 lb/hr, and 867 tpy.

We agree with the State’s conclusions, and we are proposing to approve its PM BART determination for Basin Electric Laramie River Units 1, 2, and 3. iv. PacifiCorp Dave Johnston—Units 3 and 4 Background

PacifiCorp Dave Johnston power plant is located in Converse County, Wyoming. Dave Johnston Power Plant is comprised of four units burning pulverized subbituminous Powder River Basin coal. Units 3 and 4 are the only units subject-to-BART. Dave Johnston Unit 3 is a nominal 230-MW pulverized coal-fired boiler that commenced service in 1964. It is equipped with burners in a cell configuration. Dave Johnston Unit 4 is a nominal 330-MW pulverized coal-fired boiler that commenced service in 1972. It is a tangential-fired boiler. The State’s BART analysis can be found in Chapter 6.5.5 and Appendix A of the SIP (The NO X BART determination for Dave Johnston Unit 3 is discussed in section VII.A of this notice). NO X BART Determination for Unit 4

Unit 4 is currently controlled with LNBs that were placed in operation in 1976. The State determined LNBs with advanced OFA, LNBs with advanced OFA and SNCR, and LNBs with advanced OFA and SCR were technically feasible for controlling NO X emissions for Unit 4. The State did not identify any technically infeasible controls.

The State did not identify any energy or non-air quality environmental impacts that would preclude the selection of any of the controlsevaluated, and there are no remaininguseful-life issues for this source. Baseline NO X emissions are 8,566 tpy for Unit 4 based on unit heat input rate of 2,500 MMBtu/hr and 7,884 hours of operation. A summary of the State’s NO X BART analysis and the visibility impacts is provided in Table 8 below.



### TABLE 

### 8—S UMMARY OF 

### D AVE 

### J OHNSTON 

### U NIT 

### 4 NO X 

### BART A NALYSIS

Control technology Control efficiency (%) Emission rate (lb/MMBtu) (30-day rolling

average) Emission reduction

(tpy) Annualized costs Average cost effectiveness ($/ton) Visibility improvement (delta deciview for the maximum 98th percentile impact

at Wind Cave National Park)

LNB with advanced OFA 71.7 0.15 6,142 $841,527 $137 0.71 New LNB with advanced

OFA and SNCR ............ 77.4 0.12 6,626 $2,141,786 $323 0.80
LNB with advanced OFA

and SCR ....................... 86.8 0.07 7,435 $16,430,528 $2,210 0.97


### 33035 Federal Register / Vol. 77, No. 107 / Monday, June 4, 2012 / Proposed Rules

18 Unit 4 has different modeling results as the stack parameters used in the modeling are different enough from Units 1-3 to yield different modeled results. Incremental costs for the controls evaluated are as follows: New LNB with advanced OFA and SNCR: $2,686/ton; and LNB with advanced OFA and SCR: $17,662/ton.

Based on its consideration of the five factors, the State determined LNBs with advanced OFA was reasonable for NO X BART for Dave Johnston Unit 4. The State determined the NO X BART emission limits for Unit 4 are 0.15 lb/ MMBtu (30-day rolling average), 615 lb/ hr (30-day rolling average), and 2,694 tpy.

We find it is reasonable for the State to eliminate higher performing control options (i.e., LNBs with advanced OFA plus SNCR and LNBs with advanced OFA plus SCR). The incremental cost effectiveness of achieving 0.07 lb/ MMBTU with SCR over achieving 0.15 lb/MMBTU with LNBs is $17,662, with a 0.26 delta deciview visibility improvement. The incremental cost effectiveness of SNCR over LNBs is $2,686 with an incremental visibility improvement of 0.09.

Based on our examination of the State’s costs estimates, emission reductions, and the predicted visibility improvement, we agree with the State’s conclusions, and we are proposing to approve its NO X BART determination for PacifiCorp Dave Johnston Unit 4. PM BART Determination Units 3 and 4 are currently controlled with fabric filters installed in 2008 with an emission limit of 0.015 lb/MMBtu. The State determined that fabric filters represent the most stringent PM control technology and that 0.015 lb/MMBtu represents the most stringent emission limit. Consistent with the BART Guidelines, the State did not provide a five-factor analysis because the State determined BART to be the most stringent control technology and limit (70 FR 39165). The State determined that the PM BART emission limits for Unit 3 are 0.015 lb/MMBtu, 42.1 lb/hr, and 184 tpy and the PM BART emission limits for Unit 4 are 0.015 lb/MMBtu (30-day rolling average), 61.5 lb/hr, and 269 tpy.

We agree with the State’s conclusions, and we are proposing to approve its PM BART determination for Dave Johnston Units 3 and 4.
v. PacifiCorp Jim Bridger—Units 1–4 Background

PacifiCorp’s Jim Bridger Power Plant is located in Sweetwater County, Wyoming. Jim Bridger is comprised of four identically sized nominal 530 MW tangentially fired boilers burning pulverized coal for a total net generating capacity of 2,120 MW. Jim Bridger Unit 1 was placed in service in 1974, Unit 2 in 1975, Unit 3 in 1976, and Unit 4 in 1979. The State’s BART determination can be found in Chapter 6.5.4 and Appendix A of the SIP (The NO X BART determination for Jim Bridger Units 1 and 2 is discussed in section VII.A of this notice).

NO X BART Determination for Jim Bridger Units 3 and 4

PacifiCorp Jim Bridger Units 3 and 4 are equipped with early generation LNBs with a permit limit of 0.70 lb/ MMBtu (3-hour fixed). The State determined that LNBs with SOFA, LNBs with SOFA plus SNCR, and LNBs with SOFA plus SCR were technically feasible for controlling NO X emissions. The State did not identify any technically infeasible options.

The State did not identify any energy or non-air quality environmental impacts that would preclude the selection of any of the controlsevaluated, and there are no remaininguseful-life issues for this source. Baseline NO X emissions are 10,643 tons for both units based on unit heat input rate of 6,000 MMBtu/hr and 7,884 hours of operation. A summary of the State’s NO X BART analysis and the visibility impacts is provided in Table 9 below.



### TABLE 

### 9—S UMMARY OF 

### J IM 

### B RIDGER 

### U NITS 

### 3 AND 

### 4 NO X 

### BART A NALYSIS

### —C OSTS PER 

### B OILER

Control technology Control efficiency (%) Emission rate (lb/MMBtu) (30-day rolling

average) Emission reduction (tpy) Annualized costs Average cost effectiveness ($/ton) Visibility improvement (delta deciview for the maximum 98th percentile impact

at Mt. Zirkel Wilderness)-units 3/4 18

LNB with SOFA ................ 42.2 0.26 4,493 $1,144,969 $255 0.41/0.47 New LNB with SOFA and

SNCR ........................... 55.6 0.20 5,913 2,710.801 459 0.53/0.62 LNB with SOFA and SCR 84.4 0.07 8,987 20,296,400 2,258 0.80/0.82

Incremental cost effectiveness for the control evaluated is as follows: New LNB with SOFA and SNCR: $1,103/ton, and LNB with SOFA and SCR: $5,721/

ton.

The State determined the cost of compliance was high for SCR. The State determined that LNBs with SOFA were reasonable for NO X BART for Jim Bridger Units 3 and 4. The State determined the NO X BART emission limits for Jim Bridger Units 3 and 4 are 0.26 lb/MMBtu (30-day rolling average), 1,560 lb/hr (30-day average), and 6,833 tpy. The State is requiring PacifiCorp to install additional controls under its LTS. The State determined that based on the cost of compliance and visibility improvement presented by PacifiCorp in the BART applications for Jim Bridger Units 3 and 4 and taking into consideration the logistical challenge of managing multiple pollution control installations within the regulatory time allotted for installation of BART by the RHR, additional controls would be required under the LTS but not BART (see Chapter 8.3.3 of the SIP). With respect to Jim Bridger Units 3 and 4, the State has required PacifiCorp to install SCR, or other NO X control systems, to achieve an emission limit or otherwise reduce NO X emissions to achieve a 0.07 lb/MMBtu 30-day rolling average NO X emissions rate. PacifiCorp is required to meet the 0.07 lb/MMBtu emission rate on Unit 3 prior to December 31, 2015 and on Unit 4 prior to December 31,

2016.

EPA does not agree with the State’s conclusion that a limit of 0.26 lb/ MMBtu is reasonable for BART for Jim Bridger Units 3 and 4, which can be achieved with the installation and


### 33036 Federal Register / Vol. 77, No. 107 / Monday, June 4, 2012 / Proposed Rules

19 Wyoming determined that LNBs with OFA and SCR was BART for Naughton Unit 3. The cost effectiveness of SCR for Naughton Unit 3 is $2,830 with 1 deciview of visibility improvement. 20 The cumulative 3-year averaged visibility improvement from new LNB with separated OFA, upgraded wet FGD, and FGC for enhanced ESP with FGC (Post-Control Scenario 1) across the three Class I areas achieved with LNB and separated OFA, upgraded wet FGD, and adding a polishing fabric filter (Post-Control Scenario 2) was 0.095 delta dv from Unit 1, 0.090 delta dv from Unit 2, 0.089 delta dv from Unit 3 and 0.025 delta dv from Unit 4. operation on LNBs with SOFA. In particular, the cost effectiveness values for LNBs with SOFA plus SCR at each unit is $2,258 with approximately 0.80 delta deciview visibility improvement. The cost effectiveness values are reasonable and the visibility improvement significant for LNBs with SOFA plus SCR. In addition, the costs are within the range that Wyoming, other states, and we have considered reasonable in the BART context. 19 LNBs with SOFA plus SCR would result in an additional reduction of 4,474 tpy of NO X emissions at each unit. This difference is substantial. We find that it was unreasonable for the State not to determine that LNBs with SOFA plus SCR was NO X BART for Jim Bridger Units 3 and 4.

Based on our examination of the State’s costs estimates, emission reductions, and the predicted visibility improvement, we propose to find it reasonable that NOx BART for Jim Bridger Units 3 and 4 is LNBs with SOFA plus SCR at an emission limit of 0.07 lb/MMBtu. Though we do not agree with the State’s BART determination, the State is requiring PacifiCorp to install controls as part of the LTS that are equivalent to what EPA’s is proposing to determine is reasonable for BART. The State is requiring PacifiCorp to install the LTS controls within the timeline that BART controls would have to be installed pursuant to 40 CFR 51.308(e)(iv). Thus, we are proposing to approve the State’s compliance schedule and emission limit of 0.07 lb/ MMBtu for Jim Bridger Units 3 and 4 as meeting the BART requirements. PM BART Determination for Jim Bridger Units 1–4

Units 1, 2, 3, and 4 are currently controlled for PM with ESPs and flue gas conditioning (FGC). The current permit limit for all four units is 0.03 lb/ MMBtu. The State determined that fabric filters were technically feasible for controlling PM emissions. The State did not identify any technically infeasible controls. The State did not identify any energy or non-air quality environmental impacts that would preclude the selection of any of the controls evaluated, and there are no remaining-useful-life issues for this source. A summary of the State’s PM BART analyses for Units 1–4 is provided in Table 10 below. Baseline PM emissions are 1,064 tpy for Unit 1, 1,750 tpy for Unit 2, 1,348 tpy for Unit 3, and 710 tpy for Unit 4 based on unit heat input rate of 6,000 MMBtu/hr and 7,884 hours of operation per year.



### TABLE 

### 10—S UMMARY OF 

### PACIFI 

### C ORP 

### J IM 

### B RIDGER 

### U NITS 

### 1–4 P



### . M 

### . BART A NALYSIS

Control technology Control efficiency (%) Emission rate (lb/MMBtu) (30-day rolling

average) Emission reduction

(tpy) Annualized costs Average cost effectiveness ($/ton)

Fabric Filter—Unit 1 ......................................... 66.6 0.015 709 $6,367,118 $8,980 Fabric Filter—Unit 2 ......................................... 79.7 0.015 1,395 6,357,658 4,557 Fabric Filter—Unit 3 ......................................... 73.7 0.015 993 6,337,434 6,382 Fabric Filter—Unit 4 ......................................... 50 0.015 355 6,367,118 17,936

The State did not provide visibility improvement modeling for fabric filters, but EPA is proposing to conclude this is reasonable based on the high cost effectiveness of fabric filters at each of the units. In addition, we anticipate that the visibility improvement that would result from lowering the limit from 0.03 lb/MMBtu to 0.015 lb/MMBtu would be insignificant based on the State’s analysis. 20

Based on its consideration of the fivefactors, the State determined the current ESPs with FGC were reasonable for BART. The State determined that fabric filters were not reasonable based on the high cost effectiveness. The State determined that the PM BART emission limits for Jim Bridger Units 1 through 4 are 0.03 lb/MMBtu, 180 lb/hr, and 788 tpy.

We agree with the State’s conclusions, and we are proposing approve its PM BART determination for Jim Bridger
Units 1–4. vi. PacifiCorp Naughton Units 1–3

PacifiCorp Naughton is located in Lincoln County, Wyoming. Naughton is comprised of three pulverized coal-fired units with a total net generating capacity of 700 MW. Naughton Unit 1 generates a nominal 160 MW and commenced operation in 1963. Naughton Unit 2 generates a nominal 210 MW and commenced operation in 1968. Naughton Unit 3 generates a nominal 330 MW and commenced operation in 1971. All three boilers are tangentially fired boilers. The State’s BART determination can be found in Chapter 6.5.6 and Appendix A of the SIP.

NO X BART Determination

Naughton Unit 1 and Unit 2 are currently controlled for NO X emissions with good combustion practices with NO X emission limits of 0.75 lb/MMBtu (3-hour block) and 0.58 lb/MMBtu (annual). Naughton Unit 3 is currently controlled with LNBs with OFA with permit limits of 0.75 lb/MMBtu (93-hour block) and 0.58 lb/MMBtu (annual). The State determined that LNBs with OFA, LNBs with OFA and SNCR, and LNBs with OFA and SCR were all technically feasible for controlling NO X emissions from Unit 1 and Unit 2. The State determined that tuning the existing LNBs, existing LNBs with OFA and SNCR, and existing LNBs with OFA and SCR were all technically feasible for controlling NO X emissions from Unit 3. The State did not identify any technically infeasible options.

The State did not identify any energy or non-air quality environmental impacts that would preclude the selection of any of the controlsevaluated, and there no remaininguseful-life issues for this source. A summary of the State’s NO X BART analyses for Units 1–3 is provided in Tables 11, 12, and 13 below. Baseline NOx emissions are 4,230 tpy for Unit 1, 5,109 tpy for Unit 2, and 6,563 tpy for Unit 3 based on the unit heat input rate


### 33037 Federal Register / Vol. 77, No. 107 / Monday, June 4, 2012 / Proposed Rules

of 3,700 MMBtu/hr and 7,884 hours of operation per year.



### TABLE 

### 11—S UMMARY OF 

### N AUGHTON 

### U NIT 

### 1 NO X 

### BART A NALYSIS

Control technology Control efficiency (%) Emission rate (lb/MMBtu) (30-day rolling

average) Emission reduction

(tpy) Annualized costs Average cost effectiveness ($/ton) Visibility improvement (Delta deciview) (Delta deciview for the maximum 98th percentile Impact at Bridger Wilderness Area)

LNBs with OFA ................ 55.2 0.26 2,334 $993,248 $426 0.79 LNBs with OFA and

SNCR ........................... 63.8 0.21 2,699 1,972,363 731 0.80 LNBs with OFA and SCR 87.9 0.07 3,720 10,231,210 2,750 1.07

Incremental cost effectiveness for the controls evaluated are as follows: LNBs with OFA and SNCR: $2,683/ton, and LNBs with OFA and SCR: $8,089/ton.



### TABLE 

### 12—S UMMARY OF 

### N AUGHTON 

### U NIT 

### 2 NO X 

### BART A NALYSIS

Control technology Control efficiency (%) Emission rate (lb/MMBtu) (30-day rolling

average) Emission reduction

(tpy) Annualized costs Cost effectiveness ($/ton) Visibility improvement (Delta deciview) (Delta deciview for the maximum 98th percentile Impact at Bridger Wilderness Area)

LNBs with OFA ................ 51.9 0.26 2,649 $945,683 $357 0.70 LNBs with OFA and

SNCR ........................... 61.1 0.21 3,122 2,260,957 724 0.74 LNBs with OFA and SCR 87 0.07 4,447 12,664,919 2,848 1.10

Incremental cost effectiveness for the controls evaluated are as follows: LNBs with OFA and SNCR: $2,781/ton, and LNBs with OFA and SCR: $7,852/ton.



### TABLE 

### 13—S UMMARY OF 

### N AUGHTON 

### U NIT 

### 3 NO X 

### BART A NALYSIS

Control technology Control efficiency (%) Emission rate (lb/MMBtu) (30-day rolling

average) Emission reduction

(tpy) Annualized costs Average cost effectiveness ($/ton) Visibility improvement (Delta dv for the maximum 98th percentile impact at Bridger Wilderness Area)

Tuning Existing LNBs ...... 17.8 0.37 1,167 $95,130 $82 0.25 Existing LNBs with OFA

and SNCR .................... 33.3 0.30 2,188 1,916,039 876 0.46 Existing LNB with OFA

and SCR ....................... 84.4 0.07 5,542 15,682,702 2,830 1.00

Incremental cost effectiveness for the controls evaluated are as follows: LNBs with OFA and SNCR: $1,783; and LNBs with OFA and SCR: $4,105.

Based on its consideration of the five factors, the State determined LNBs with OFA was reasonable for NO X BART for Unit 1 and Unit 2. The State determined SNCR and SCR were not reasonable based on the high cost effectiveness and associated visibility improvement. The State determined the NO X BART emission limits for Naughton Unit 1 are 0.26 lb/MMBtu (30-day rolling average), 481 lb/hr (30-day rolling average), and 2,107 tpy, and the NO X BART emission limits for Naughton Unit 2 are 0.26 lb/ MMBtu (30-day rolling average), 624 lb/ hr (30-day rolling average), and 2,733 tpy. Based on its consideration of the five factors, the State determined that the existing LNBs with OFA plus SCR was NO X BART for Unit 3. The State determined the NO X BART emission limits for Naughton Unit 3 are 0.07 lb/ MMBtu (30-day rolling average), 259 lb/ hr (30-day rolling average), and 1,134 tpy. We find it is reasonable for the State to eliminate higher performing control options for Units 1 and 2 (i.e., LNBs with advanced OFA plus SNCR and LNBs with advanced OFA plus SCR. The incremental cost effectiveness of LNBs with OFA plus SCR over LNBs with OFA is approximately $8,000 for each unit. The incremental cost effectiveness of LNBs with OFA plus SNCR over LNBs with OFA is approximately $2,700 for each unit, with incremental visibility improvement of 0.01 delta deciviews at


### 33038 Federal Register / Vol. 77, No. 107 / Monday, June 4, 2012 / Proposed Rules

Unit 1 and 0.04 delta deciviews at Unit 2.

Based on our examination of the State’s costs estimates, emission reductions, and the predicted visibility improvement, we agree with the State’s conclusions, and we are proposing to approve the State’s NO X BART determinations for PacifiCorp Naughton Units 1, 2, and 3.

PM BART Determination

Units 1 and 2 are currently controlled for PM with ESPs and FGC. The current permit limit for Units 1 and 2 is 0.04 lb/ MMBtu. Unit 3 is required by permit to install fabric filters for both Units by 2014 with a permit limit of 0.15 lb/ MMBtu. The State determined that fabric filters were technically feasible for controlling PM emissions for Units 1 and 2. The State did not identify any technically infeasible controls. The State determined that a fabric filter on Unit 3 represents the most stringent PM control technology and that 0.015 lb/ MMBtu represents the most stringent emission limit. Consistent with the BART Guidelines, the State did not provide a full five-factor analysis because the State determined BART to be the most stringent control technology and limit.

The State did not identify any energy or non-air quality environmental impacts that would preclude the selection of any of the controlsevaluated, and there are no remaininguseful-life issues for this source. A summary of the State’s PM BART analyses for Units 1 and 2 is provided in Table 14 below. Baseline emissions for Unit 1 are 409 tpy and 605 tpy for Unit 2 based on unit heat input rate of 1,850 MMBtu/hr and 7,884 hours of operation per year.



### TABLE 

### 14—S UMMARY OF 

### PACIFI 

### C ORP 

### N AUGHTON 

### U NIT 

### 1 AND 

### U NIT 

### 2 PM BART A NALYSIS

Control technology Control Efficiency (%) Emission Rate (lb/MMBtu) (30-day rolling

Average) Emission Reduction

(tpy) Annualized Costs Average Cost Effectiveness ($/ton)

Fabric Filter—Unit 1 ......................................... 73.2 0.015 299 $3,436,594 $11,494 Fabric Filter—Unit 2 ......................................... 76.6 0.015 464 4,101,705 8,848

The State did not provide visibility improvement modeling for fabric filters, but EPA is proposing to conclude this is reasonable based on the high cost effectiveness of fabric filters at each of the units, which is higher than EPA or other State have considered reasonable for PM BART.

Based on its consideration of the five factors, the State determined that the existing ESPs with FGC were reasonable for PM BART for Units 1 and 2. The State determined that fabric filters were not reasonable based on the high cost effectiveness. The State determined that the PM BART emission limits for Naughton Unit 1 are 0.04 lb/MMBtu, 74 lb/hr, and 324 tpy and the PM BART emission limits for Naughton Unit 2 are 0.04 lb/MMBtu, 96 lb/hr, and 421 tpy. The State determined the PM BART emission limits for Naughton Unit 3 are 0.015 lb/MMBtu, 56 lb/hr, and 243 tpy.

We agree with the State’s conclusions, and we are proposing to approve its BART determination for Naughton Units 1, 2, and 3.
vii. PacifiCorp Wyodak—Unit 1 Background

PacifiCorp Wyodak Power Plant is located in Campbell County, Wyoming. Wyodak Power Plant is comprised of one coal-fired boiler, Unit 1, burning pulverized sub-bituminous Powder River Basin coal for a total net generating capacity of a nominal 335MW. Wyodak’s boiler commenced service in 1978. The State’s BART determination can be found in Chapter 6.5.7 and Appendix A of the SIP (The NO X BART analysis for Wyodak Unit 1 is discussed in Section VII.A of this notice).

PM BART Determination

Wyodak Unit 1 is currently controlled with fabric filters with an emission limit of 0.015 lb/MMBtu (30-day rolling average). The State determined that fabric filters on Wyodak Unit 1 represent the most stringent PM control technology and that 0.015 lb/MMBtu represents the most stringent emission limit. Consistent with the BART Guidelines, the State did not provide a full five-factor analysis because the State determined BART to be the most stringent control technology and limit. The State determined the PM BART emission limits for Wyodak Unit 1 are 0.015 lb/MMBtu, 71.0 lb/hr, and 308.8 tpy.

We agree with the State’s conclusions, and we are proposing to approve its PM BART determination for Wyodak Unit 1. D. Reasonable Progress Requirements

In order to establish RPGs for its Class I areas, and to determine the controls needed for the LTS, Wyoming followed the process established in the RHR. Wyoming identified sources (other than BART sources) and source categories in Wyoming that are major contributors to visibility impairment and considered whether these sources should be controlled based on a consideration of the factors identified in the CAA and EPA’s regulations (see CAA 169A(g)(1) and 40 CFR 51.308(d)(1)(i)(A)). Wyoming then identified the anticipated visibility improvement in 2018 in all its Class I areas using the WRAP Community Multi-Scale Air Quality (CMAQ) modeling results. 1. Visibility Impairing Pollutants and Sources

In order to determine the significant sources contributing to haze in Wyoming’s Class I areas, Wyoming relied upon two source apportionment analysis techniques developed by the WRAP. The first technique was regional modeling using the Comprehensive Air Quality Model (CAMx) and the PM Source Apportionment Technology (PSAT) tool, used for the attribution for sulfate and nitrate sources only. The second technique was the Weighted Emissions Potential (WEP) tool, used for attribution of sources of OC, EC, PM 2.5 , and PM 10 . The WEP tool is based on emissions and residence time, not modeling and looks at all sources throughout the modeling domain.

PSAT uses the CAMx air qualitymodel to simulate nitrate-sulfateammonia chemistry and apply this chemistry to a system of tracers or ‘‘tags’’ to track the chemical transformations, transport, and removal of NO X and SO 2 . These two pollutants are important because they tend to originate from anthropogenic sources. Therefore, the results from this analysis can be useful in determining contributing sources that may be controllable, both in-state and in neighboring states.

WEP is a screening tool that helps to identify source regions that have the potential to contribute to haze formation at specific Class I areas. Unlike PSAT,


### 33039 Federal Register / Vol. 77, No. 107 / Monday, June 4, 2012 / Proposed Rules

21 Extinction and species contribution to total particulate extinction taken from IMPROVE data (http://vista.cira.colostate.edu/dev/web/Annual SummaryDev/Composition.aspx). IMPROVE data for NOABI based on available data for 2002–2004. Contribution of sulfate and nitrate based on PSAT; OC, EC, PM 2.5 , and PM 10 contribution based on WEP as taken from the WRAP TSS (http://vista.cira. colostate.edu/tss/ ). 22 OD denotes Outside Domain; ID denotes Idaho, MT denotes Montana, CAN denotes Canada, UT denotes Utah, WA denotes Washington, WY denotes Wyoming, CA denotes California, and OR denotes Oregon. this method does not account for chemistry or deposition. The WEP combines emissions inventories, wind patterns, and residence times of air masses over each area where emissions occur, to estimate the percent contribution of different pollutants. Like PSAT, the WEP tool compares baseline values (2000–2004) to 2018 values, to show the improvement expected by 2018 for OC, EC, PM 2.5 , and PM 10 . More information on the WRAP modeling methodologies is available in the document Technical Support Document for Technical Products Prepared by the Western Regional Air Partnership (WRAP) in Support of Western Regional Haze Plans in the Supporting and Related Materials section of the docket. Table 15 shows Wyoming’s contribution to extinction at its own Class I areas.



### TABLE 

### 15—WYOMING 

### S OURCES 

### E XTINCTION 

### C ONTRIBUTION 

### 2000–2004 FOR 

### 20% WORST 

### D AYS 21

Class I Area Pollutant Species Extinction (Mm

¥ 1 ) Species Contribution to Total Particulate Extinction (%) WyomingSources Contribution to Species Extinction (%)

Yellowstone National Park, Grand Teton National Park,

Teton Wilderness. Sulfate .................... 4 .3 16 .7 5.9

Nitrate .................... 1 .8 7 .0 4.7 OC ......................... 13 .5 52 .4 72.6 EC .......................... 2 .5 9 .7 66.8 Fine PM ................. 1 .0 3 .9 24.0 Coarse PM ............. 2 .6 10 .1 20.0 Sea Salt ................. 0 .02 0 .08 ............................ North Absaroka Wilderness, Washakie Wilderness ................ Sulfate .................... 4 .9 20 .7 5.6 Nitrate .................... 1 .6 6 .8 8.2 OC ......................... 11 .6 48 .9 44.6 EC .......................... 1 .9 8 .0 39.5 Fine PM ................. 0 .8 3 .4 14.0 Coarse PM ............. 2 .9 12 .2 12.1 Sea Salt ................. .............................. 0 .04 ............................ Bridger Wilderness, Fitzpatrick Wilderness ............................. Sulfate .................... 5 .0 22 .2 15.4 Nitrate .................... 1 .4 6 .2 19.4 OC ......................... 10 .5 46 .6 58.5 EC .......................... 2 .0 8 .9 51.0 Fine PM ................. 1 .1 4 .9 30.3 Coarse PM ............. 2 .5 11 .1 27.4 Sea Salt ................. 0 .04 0 .2 ............................

Table 16 shows influences from sources both inside and outside of Wyoming per the PSAT modeling for 2018. As indicated, the outside domain (OD) region is the highest contributor to sulfate and nitrate at all Wyoming Class I areas. The outside domain region represents the concentration of pollutants at the boundaries of the modeling domain. Depending on meteorology and the type of pollutant (particularly sulfate), these emissions can be transported great distances from regions such as Canada, Mexico, and the Pacific Ocean. Wyoming is the second highest contributor of particulate sulfate and nitrate at Bridger and Fitzpatrick Wilderness areas, but is a lesser contributor at the other Class I areas.



### TABLE 

### 16—PSAT S OURCE 

### R EGION 

### A PPORTIONMENT FOR 

### 20% WORST 

### D AYS 22

Class I Area 2018 Sulfate PSAT 2018 Nitrate PSAT

Yellowstone National Park, Grand Teton National

Park, Teton Wilderness. Region ............. % Contribution OD 46.5 ID 8.1 WY 5.8 CAN 5.4 OR 4.6 OD 31.3 ID 28.2 WA 9.4 UT 7.4 OR 7.0 North Absaroka Wilderness, Washakie Wilderness ... Region ............. % Contribution OD 50.1 CAN 12.5 MT 6.5 ID 5.7 WY 5.5 OD 30.7 ID 16.7 MT 14.8 CAN 11.5 WY 8.2 Bridger Wilderness, Fitzpatrick Wilderness ................ Region ............. % Contribution OD 31.1 WY 15.3 ID 7.6 UT 5.9 CAN 5.1 OD 21.8 WY 19.3 UT 15.6 ID 10.6 CA 6.8

Tables 17 shows the WEP contribution for EC, OC, PM 2.5 , and PM 10 .


### 33040 Federal Register / Vol. 77, No. 107 / Monday, June 4, 2012 / Proposed Rules

23 The State submitted a January 12, 2011 SIP submittal to address the requirements under 40 CFR 51.309, with the exception of the 40 CFR 51.309(g) requirements addressed in this SIP submittal. 

### TABLE 

### 17—WEP S OURCE 

### CATEGORY 

### C ONTRIBUTION FOR 

### 20% WORST 

### D AYS

Class I Area Point Area Mobile Anthropogenic Fires Natural Fires and Biogenic

**OC**

Yellowstone National Park, Grand Teton National

Park, Teton Wilderness ............................................ 0 .408 3.892 1 .636 8 .303 85 .764 North Absaroka Wilderness, Washakie Wilderness .... 0 .661 9.449 2 .844 11 .881 75 .159 Bridger Wilderness, Fitzpatrick Wilderness ................. 0 .984 7.552 3 .28 7 .644 80 .543

**EC**

Yellowstone National Park, Grand Teton National

Park, Teton Wilderness ............................................ 0 .243 2.628 13 .659 5 .51 77 .958 North Absaroka Wilderness, Washakie Wilderness .... 0 .386 5.755 23 .253 7 .054 63 .55 Bridger Wilderness, Fitzpatrick Wilderness ................. 0 .54 4.509 25 .65 4 .105 65 .195

**PM** 2.5

Yellowstone National Park, Grand Teton National

Park, Teton Wilderness ............................................ 5 .565 70.463 0 .086 5 .469 18 .411 North Absaroka Wilderness, Washakie Wilderness .... 3 .491 86.311 0 .171 3 .334 6 .691 Bridger Wilderness, Fitzpatrick Wilderness ................. 16 .311 69.195 0 .081 3 .618 10 .785

**PM** 10

Yellowstone National Park, Grand Teton National

Park, Teton Wilderness ............................................ 2 .655 83.939 0 .363 0 .717 12 .316 North Absaroka Wilderness, Washakie Wilderness .... 2 .066 93.197 0 .213 0 .313 4 .206 Bridger Wilderness, Fitzpatrick Wilderness ................. 6 .775 84.157 0 .477 0 .353 8 .23

Table 17 shows that EC, OC, PM 2.5 and PM 10 emissions come mainly from sources such as natural fire, windblown dust, and road dust. To select the sources that would undergo the required four factor analysis, Wyoming looked at State emission inventory data in conjunction with the source apportionment information discussed above (a summary of the State’s emission inventory can be found in section VI.E.1 of this notice). After evaluating this information, the State determined that stationary source emissions of NO X and SO 2 were reasonable to evaluate for purposes of reasonable progress controls. The State also determined that emissions of NO X from oil and gas development should be analyzed for purposes of reasonable progress. Since emissions of OC, EC,
PM 2.5 , and PM 10 come from mainly uncontrollable sources, the State determined it was reasonable to not evaluate these pollutants for reasonable progress controls. The State submitted a January 12, 2011, SIP that addresses sources of SO 2 . 23 Thus, the State evaluated emissions of the remaining pollutant, NO X , for reasonable progress in this SIP. 2. Four Factor Analysis In determining the measures necessary to make reasonable progress, States must take into account the following four factors and demonstrate how they were taken into consideration in selecting reasonable progress goals for a Class I area:

• Costs of Compliance;

• Time Necessary for Compliance;

• Energy and Non-air Quality Environmental Impacts of Compliance; and

• Remaining Useful Life of any Potentially Affected Sources.

CAA § 169A(g)(1) and 40 CFR 308(d)(1)(i)(A).

The State performed a four factor analysis for each of the reasonable progress sources pursuant to 40 CFR 51.308(d)(1)(i)(A).

a. Stationary Sources

The State used a reasonable progress screening methodology termed ‘‘Q/d’’ to determine which stationary sources would be candidates for controls under reasonable progress. Q/d is a calculated ratio where Q represents (in this case) the NO X emission rate in tpy of the source divided by the distance in kilometers of the point source from the nearest Class I area, denoted by ‘‘d.’’ The State used the maximum permitted emission rate for each source to determine the tpy of NO X it used in the Q/d calculation. The State determined that a Q/d value of 10 is reasonable for determining which sources the State should consider for reasonable progress controls, since this value yielded sources of concern similar in magnitude to sources subject-to-BART.

The State determined there were three units with a Q/d of greater than 10 that are not already being controlled under BART and the State completed a reasonable progress analysis for each of the sources. The sources are PacifiCorp Dave Johnson Unit 1 and Unit 2 and Mountain Cement Company Laramie Plant kiln. Dave Johnston Units 1 and 2 is addressed as part of our FIP in section VII.B of this notice. In addition, as previously mentioned, the State considered reasonable controls on oil and gas development sources.
b. Summary of Reasonable Progress Determinations and Limits

For the subject-to-reasonable progress sources, the State provided analyses that took into consideration the four factors as required by section 169A(g)(1) of the CAA and 40 CFR 51.308(d)(1)(i)(A). For the stationary sources, the State relied on the analysis found in Supplementary Information for Four-Factor Analyses for Selected Individual Facilities in Wyoming, May 6, 2009, Revised Draft Report Prepared by EC/R Incorporated. For oil and gas sources, the State relied on the analysis found in Supplementary Information for Four Factor Analyses by WRAP States, May 4, 2009 (Corrected 4/


### 33041 Federal Register / Vol. 77, No. 107 / Monday, June 4, 2012 / Proposed Rules

20/10) Revised Draft Report Prepared by EC/R Incorporated (for a complete copy of the reports see Chapter 7 of the State’s TSD). The analyses considered EPA’s BART Guidelines as relevant to their reasonable progress evaluations, as well as EPA’s Guidance for Setting Reasonable Progress Goals Under the Regional Haze Program.

In this action, EPA is proposing to approve the reasonable progress NO X determinations submitted by the State for oil and gas sources and for Mountain Cement Company Laramie Plant kiln. EPA is proposing to disapprove the State’s reasonable progress determinations and proposing to issue a reasonable progress determination NO X FIP for PacifiCorp Dave Johnston Unit 1 and Unit 2. EPA’s rationale for disapproving the State’s reasonable progress determination for these units, as well as EPA’s reasonable progress FIP determination, can be found in section VII.B of this notice.

A summary of the reasonable progress analysis and determination for each source/source category that we are proposing to approve is provided below.

i. Oil and Gas Area Sources Background

Oil and gas exploration and production is occurring in numerous areas in Wyoming. The sources associated with oil and gas production mainly emit NO X and VOCs; in this context, the State considered NO X . Oil and gas production and exploration includes operation, maintenance, and servicing of production properties, including transportation to and from sites. EC/R evaluated reasonable progress control technologies for common sources in the oil and gas industry including compressor engines, turbines, process heaters, and drilling rig engines. The State’s NO X reasonable progress determination for oil and gas sources can be found in Chapter 7.3.5 of the SIP.

NO X Reasonable Progress Determination

For compressor engines, potential control options identified by the State include air-fuel ratio controls (AFRC), ignition timing retard, low-emission combustion (LEC) retrofit, SCR, SNCR, and replacement with electric motors. The State evaluated several control technologies for drilling rig engines including ignition timing retard, exhaust gas recirculation (EGR), SCR, replacement of Tier 2 engines with Tier 4 engines, and diesel oxidation catalyst. Potential controls for turbines identified by the State include water or steam injection, LNBs, SCR, and water or steam injection with SCR. NO X emission control technologies identified by the State for process heaters include LNBs, ultra-low NO X burners (ULNBs), LNBs with flue gas recirculation (FGR), SNCR, SCR, and LNBs installed in conjunction with SCR.

NO X emissions vary based on the equipment and fuel source. Emissions from individual natural gas-fired turbines at production operations can be as high as 877 tpy of NO X , while emissions from individual natural gas turbines at exploration operations can reach 131 tpy of NO X . Individual gas reciprocating engines have comparable NO X emissions with up to 700 tpy at production operations and 210 tpy at exploration operations. Diesel engine emissions can approach 46 tpy for production operations and 10 tpy for exploration operations.

Table 18 provides a summary of the reasonable progress NO X analysis for oil and gas sources. Both the capital and annual costs for each technology is dependent on the engine size or on the process throughput; therefore, for most of the control technologies listed in Table 18, the State has provided cost estimate ranges. The lower end of the cost/ton estimates represent the cost per unit for larger or higher production units, while the higher end of the cost/ ton estimates represent the cost per unit for the smaller or lower production units.



### TABLE 

### 18—S UMMARY OF 

### R EASONABLE 

### P ROGRESS 

### NO X 

### A NALYSIS FOR 

### O IL AND 

### G AS 

### E XPLORATION AND 

### P RODUCTION 

### E QUIPMENT

Source Type Control Technology EstimatedControl Efficiency (%) Pollutant Controlled Estimated Capital Cost

($/unit) Annual Cost ($/year/unit) Units Cost Effectiveness ($/ton)

Compressor Engines ........ AFRC ................................ Ignition timing retard ......... 10–40 15–30 NO X

......... NO X

......... 5.3–42 N/A 0.9–6.8 1–3 hp ............. hp ............ 68–2,500 42–1,200 LEC retrofit ....................... 80–90 NO X ......... 120–820 30–210 hp ............ 320–2,500 SCR .................................. 90 NO X ......... 100–450 40–270 hp ............ 870–31,000 SNCR ............................... 90–99 NOX ......... 17–35 3–6 hp ............ 16–36 Replacement with electric

motors. 100 NO X ......... 120–140 38–44 hp ............ 100–4,700

Drilling Rig Engines and

Other Engines. Ignition timing retard ......... EGR .................................. SCR .................................. 15–30 40 80–95 NO X

......... NO X

......... NO X

......... 16–120 100 100–2,000 14–66 26–67 40–1,200 hp ............ hp ............ hp ............ 1,000–2,200 780–2,000 3,000–7,700Replacement of Tier 2 engines with Tier 4. 87 NO X ......... 125 20 hp ............ 900–2,400

Turbines ............................ Water or steam injection .. 68–80 NO X ......... 4.4–16 2–5 1000 BTU 560–3,100 LNB ................................... 68–84 NOX ......... 8–22 2.7–8.5 1000 BTU 2,000–10,000 SCR .................................. 90 NO X ......... 13–34 5.1–13 1000 BTU 1,000–6,700 Water or steam injection

with SCR. 93–96 NOX ......... 13–34 5.1–13 1000 BTU 1,000–6,700

Process Heaters ............... LNB ................................... ULNB ................................ 40 75–85 NO X

......... NO X

......... 3.8–7.6 4.0–13 0.41–0.81 0.43–1.3 1000 BTU 1000 BTU 2,100–2,800 1,500–2,000 LNB and FGR ................... 48 NO X

......... 16 1.7 1000 BTU 2,600 SNCR ............................... 60 NO X ......... 10–22 1.1–2.4 1000 BTU 4,700–5,200 SCR .................................. 70–90 NOX ......... 33–48 3.7–5.6 1000 BTU 2,900–6,700 LNB and SCR ................... 70–90 NO X ......... 37–55 4–6.3 1000 BTU 2,900–6,300


### 33042 Federal Register / Vol. 77, No. 107 / Monday, June 4, 2012 / Proposed Rules

24 For all reasonable progress sources, the time necessary to develop regulations is not a consideration under the time necessary for compliance factor. If regulations are needed to implement reasonable progress controls, the State must develop them as part of the regional haze SIP.

25 Oil and gas sources are regulated by the State as part of its minor source BACT requirements in Wyoming Air Quality Standards and Regulations Chapter 6, Section 2.

26 A negative annual cost is given because cement kilns receive a credit for the biosolids tipping fee paid by facilities providing the biosolids to the cement plant. For the purposes of this analysis, the tipping fee is $5.00/ton.

27 Cost effectiveness figures for the CemStar SM process were not available for dry kilns. 28 Cost effectiveness figures for LoTOx TM were not available for dry kilns.

29 Capital and annual costs for SNCR have only been costed for preheater and precalcnier kilns. Only cost effectiveness figures were available for dry kilns. Wyoming states that it would need up to two years to develop the necessary regulations to control oil and gas

sources. 24 The State estimated that companies would require a year to procure the necessary capital to purchase the control equipment. The time required to design, fabricate, and install control technologies will vary based on the control technology selected and other factors.

The State determined that no additional controls for oil and gas sources were reasonable at this time. The State concluded that emissions from large stationary sources processing oil and gas in the WRAP region have been well quantified over the years, while smaller exploration and production sources that the State is evaluating for reasonable progress have not had the same degree of emission inventory development. The State points out that understanding the sources and volume of emissions at oil and gas production sites is necessary to recognizing the impact that these emissions have on visibility.

To better understand the emissions from stationary and mobile equipment operated as part of oil and gas field operations, the WRAP has been working on developing an emission inventory to more fully characterize the oil and gas field operations emissions. The WRAP’s development of a more comprehensive emission inventory is still in process (as of the date of the State’s SIP submittal). The State determined it cannot complete the evaluation of oil and gas on visibility until the WRAP emission inventory study has been completed.

The State points out that in the case of compressor engines, many facilities have already installed control equipment. 25 For lean burn engines, oxidation catalysts are commonly installed, while SNCR with AFRC are commonly installed for rich burn engines. The State also points out that regulating drill rig engines can be problematic since drill rig engines are, for the most part, considered mobile sources and emission limits for mobile sources are set by the Federal government under section 202 of the CAA.

We disagree with the State’s reasoning for not adopting reasonable progress controls for oil and gas sources. If the State determined that additional information was needed to potentially control oil and gas sources, the State should have developed the information. While we disagree with the State’s reasoning for not requiring any controls under reasonable progress, we are proposing to approve the State’s conclusion that no additional NO X controls are warranted for this planning period. As shown by the four factor analyses, the most reasonable controls are for compressor engines, which the State already controls through its minor source BACT requirements (see above). In addition, while the costs of some controls are within the range of cost effectiveness values Wyoming, other states, and we have considered as reasonable in the BART context, they are not so low that we are prepared to disapprove the State’s conclusion in the reasonable progress context.

We are proposing to approve the State’s reasonable progress determination for oil and gas sources.

ii. Mountain Cement Company Laramie Plant—Kiln Background

The Mountain Cement Company Laramie Plant cement kiln is a long dry kiln with a capacity of 1,500 tons of clinker per day. Assuming the plant runs 365 days of the year, the result is 547,500 tpy of clinker.

NO X Reasonable Progress Determination

The kiln is currently uncontrolled for NO X emissions. The State determined that indirect and direct firing of LNBs, biosolid injection, NOxOUT SM

, CemSTAR SM , LoTOx TM , SCR, SNCR (using urea), and SNCR (using ammonia) were technically feasible for controlling NO X emissions from the kiln. The State did not identify any technically infeasible controls.

The State did not identify any energy or non-air quality environmental impacts that would preclude the selection of any of the controlsevaluated, and there are no remaininguseful-life issues for this source. A summary of the State’s NO X reasonable progress analyses for the kiln is provided in Table 19 below. Baseline NO X emissions for the kiln are 524 tpy based on 2002 actual emissions.



### TABLE 

### 19—S UMMARY OF 

### M OUNTAIN 

### C EMENT 

### C OMPANY 

### K ILN 

### NO X 

### R EASONABLE 

### P ROGRESS 

### A NALYSIS

Control Technology Control Efficiency (%) Emission Reduction (tpy) Annualized Costs Cost Effectiveness ($/ton)

LNB (indirect) ........................................................................... 30–40 157–210 $205,000 $6,568–4,910 LNB (direct) .............................................................................. 40 210 449,000 13,853 Biosolid Injection 26

.................................................................. 50 262

¥ 127,000 1,324 NOxOUT SM

............................................................................. 35 183 507,000 8,023 CemSTAR SM 27

....................................................................... 20–60 105–314 Unknown Unknown LoTOxTM 28

.............................................................................. 80–90 419–472 Unknown Unknown SCR ......................................................................................... 80 419 7,553,000 82,535 SNCR (urea) 29

........................................................................ 35 183 Unknown 1,223 SNCR (ammonia) .................................................................... 35 183 Unknown 1,223

The State estimated that it could potentially take seven years to install control equipment on the kiln. This estimate includes the two years that will be necessary for the State to implement new regulations and the one-year Mountain Cement will likely need to obtain the necessary capital for the purchase of new emission control technology. The State estimates the total time necessary for compliance will vary based on the control technology selected. For example, the State predicts that one and a half years will be required to design, fabricate, and install


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30 States must consider the four factors as listed above but can also take into account other relevant factors for the reasonable progress sources identified (see EPA’s Guidance for Setting Reasonable Progress Goals under the Regional Haze Program, (‘‘EPA’s Reasonable Progress Guidance’’), p. 2–3, July 1, 2007). SCR or SNCR technology, while over two and a half years will be required to design, fabricate, and install LoTOx TM technology.

The State determined no controls were reasonable for reasonable progress for Mountain Cement Company LaramiePlant kiln. The State cited that the fourfactor analysis was limited, in that no guidance was provided by EPA for identifying significant sources and EPA did not establish contribution to visibility impairment thresholds (a potential fifth factor for reasonable progress determinations). 30 The State further claims that the State cannot, per Wyoming Statute 35–11–202, establish emission control requirements except through State rule or regulation. Furthermore, the Wyoming statute requires the State to consider the character and degree of injury of the emissions involved. In this case, the State claims it would need to have visibility modeling that assessed the degree of injury caused by the emissions, which the State does not have. The State believes it has taken a strong and reasonable first step in identifying potential contributors to visibility impairment, and that the next step of creating an appropriate rule or regulation will be accomplished in the next SIP revision.

We disagree with the State’s reasoning for not adopting reasonable progress controls for Mountain Cement Company Laramie Plant kiln. If the State determined that it needed to adopt a rule or perform modeling to adequately assess and, if warranted, require reasonable progress controls, the State should have completed these steps before it submitted its regional haze SIP. The RHR does not allow for commitments to potentially implement strategies at some later date that are identified under reasonable progress or for the State to take credit for such commitments. Nor does it allow the State to consider the time to promulgate regulations as part of the time for compliance. While we disagree with the State’s reasoning for not requiring any controls under reasonable progress, we are proposing to approve the State’s conclusion that no additional NO X controls are warranted for this planning period. While the costs of some controls (i.e., biosolid injection and SNCR) are within the range of cost effectiveness values Wyoming, other states, and we have considered as reasonable in the BART context, they are not so low that we are prepared to disapprove the State’s conclusion in the reasonable progress context. In addition, these controls afford relatively modest emission reductions. 3. Reasonable Progress Goals

40 CFR 51.308(d)(1) requires states to ‘‘establish goals’’ (in deciviews) that provide for reasonable progress towards achieving natural visibility conditions for each Class I area of the State. These RPGs are interim goals that must provide for incremental visibility improvement for the most impaired visibility days, and ensure no degradation for the least impaired visibility days. The RPGs for the first planning period are goals for the year

2018.

Wyoming relied on WRAP modeling to establish its RPGs for 2018. The primary tool WRAP relied upon for modeling regional haze improvements by 2018, and for estimating Wyoming’s RPGs, was the CMAQ model. The CMAQ model was used to estimate 2018 visibility conditions in Wyoming and all western Class I areas, based on application of anticipated regional haze strategies in the various states’ regional haze plans, including assumed controls on BART sources.

The Regional Modeling Center (RMC) at the University of California Riverside conducted the CMAQ modeling under the oversight of the WRAP Modeling Forum. The RMC developed air quality modeling inputs including annual meteorology and emissions inventories for: (1) A 2002 actual emissions base case; (2) a planning case to represent the 2000–2004 regional haze baseline period using averages for key emissions categories; and (3) a 2018 base case of projected emissions determined using factors known at the end of 2005. All emission inventories were spatially and temporally allocated using the Sparse Matrix Operator Kernel Emissions (SMOKE) modeling system. Each of these inventories underwent a number of revisions throughout the development process to arrive at the final versions used in CMAQ modeling.

The photochemical modeling of regional haze for the WRAP states for 2002 and 2018 was conducted on the 36-km resolution national regional planning organization domain that covered the continental United States, portions of Canada and Mexico, and portions of the Atlantic and Pacific Oceans along the east and west coasts. The RMC 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 2002 modeling efforts were used to evaluate air quality/visibility modeling for a historical episode, in this case, for calendar year 2002, to demonstrate the suitability of the modeling systems for subsequent planning, sensitivity, and emissions control strategy modeling. Model performance evaluation compares output from model simulations with ambient air quality data for the same time period to determine whether model performance is sufficiently accurate to justify using the model to simulate future conditions. Once the RMC determined that model performance was acceptable, it used the model to determine the 2018 RPGs using the current and future year air quality modeling predictions, and compared the RPGs to the uniform rate of progress. A more detailed description of the CMAQ modeling performed for the WRAP can be found in the Chapter 5 of the State’s TSD.

The State determined that the WRAP 2018 projections represent significant visibility improvement and reasonable progress toward natural visibility based upon the State’s consideration of the factors required for BART and reasonable progress. The State adopted the WRAPs 2018 projections as their RPG for each Class I area. Table 20 shows the URP and the 2018 RPGs adopted by the State.


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31 The methods WRAP used to develop these emission inventories are described in more detail in Technical Support Document for Technical Products Prepared by the Western Regional Air Partnership (WRAP) in Support of Western Regional Haze Plans in the Supporting and Related Materials section of the docket. 

### TABLE 

### 20—WYOMING 

### ’ S 

### URP AND 

### RPG S FOR 

### 2018

Wyoming Class I Areas 20% Worst Days 20% Best Days

2000–2004

Baseline (deciview) 2018 URP (deciview) Reduction Needed to Reach URP Goal (Delta deciview) 2018 CMAQ Modeling Projection— State’s RPG 2000–2004 Baseline (deciview) 2018 CMAQ Modeling Projection (deciview)

Yellowstone National Park, Grand Teton

National, Park Teton Wilderness ......... 11.8 10.5 0.7 11.2 2.6 2.4 North Absaroka Wilderness, Washakie

Wilderness ............................................ 11.5 10.4 0.6 11.0 2.0 2.0Bridger Wilderness, Fitzpatrick Wilderness ...................................................... 11.1 10.0 0.6 10.6 2.1 2.0

Table 20 shows that the State’s regional haze SIP is providing forimprovement in visibility for the mostimpaired days for the period ending in 2018 and allows for no degradation in visibility for the least-impaired days.

Table 20 also shows that Wyoming is not meeting the URP to meet natural visibility conditions by 2064. In this case, 40 CFR 51.308(d)(1)(ii) requires the State to demonstrate, based on the four factors in 51.308(d)(1)(i)(A), that the RPGs established in this SIP are reasonable for this planning period and that achieving the URP in this planning period is not reasonable. In its demonstration, the State cited many reasons why meeting the URP was not reasonable, including the following. First, emissions from natural sources greatly affect the State’s ability to meet the 2018 URP. As discussed earlier, WEP data shows that emissions of OC, EC, PM 2.5 , and PM 10 come mainly from natural or non-anthropogenic sources, such as natural wildfire and windblown dust. The State has little or no control over OC, EC, PM 2.5 , and PM 10 emissions associated with natural fire and windblown dust. Second, emissions from sources outside the WRAP modeling domain also affect the State’s ability to meet the 2018 URP. Sources outside of the modeling domain are the single largest source region contributor to sulfate and nitrate at the State’s Class I areas. These sources are not under the control of Wyoming or the surrounding

states.

Since the State is not meeting the URP, the State is required by 40 CFR 51.308(d)(1)(ii) to assess the number of years it would take to reach natural conditions if visibility improvement continues at the current rate of progress. The State has calculated the year and the length of time to reach natural visibility as follows: Yellowstone National Park, Grand Teton National Park, and Teton Wilderness: 2130 (126 years); North Absaroka Wilderness and Washakie Wilderness: 2136 (132 years); and Bridger Wilderness and Fitzpatrick Wilderness: 2165 (161 years).

EPA disagrees with the State’s assessment that, based on the factors in 40 CFR 51.308(d)(1)(i)(a), all reasonable controls were implemented by the State for this first planning period of the regional haze program. In particular, as discussed in section VII.B.i below, we find unreasonable the State’s determination to not impose controls at PacifiCorp Dave Johnston Units 1 and 2. As a result, EPA is proposing to disapprove the State’s RPGs, and because we are proposing to disapprove Wyoming’s RPGs, we are also proposing a FIP to replace them. See discussion in section VII.C below.

E. Long Term Strategy

1. Emission Inventories

Section 51.308(d)(3)(iii) requires that Wyoming document the technical basis, including modeling, monitoring, and emissions information, on which it relied to determine its apportionment of emission reduction obligations necessary for achieving reasonable progress in each mandatory Class I Federal area it affects. Wyoming must identify the baseline emissions inventory on which its strategies are based. 40 CFR 51.308(d)(3)(iv) requires that Wyoming identify all anthropogenic sources of visibility impairment it considered in developing its LTS strategy. This includes major and minor stationary sources, mobile sources, and area sources.

In order to meet these requirements, Wyoming relied on the emission inventory developed by the WRAP. The State has provided an emission inventory for SO 2 , NO X , VOC, OC, EC, PM 2.5 , PM 10 , and NH 3 . The inventory provides the baseline year 2002 emissions and provides projections of future emissions in 2018 based on expected controls, growth, and other factors. The following are the inventory source categories identified by the State: Point, area, on-road mobile, off-road mobile, anthropogenic fire, natural fire, road dust, fugitive dust, area source oil and gas, and biogenic emissions. The emission inventories developed by the WRAP were calculated using best available data and approved EPA methods. 31 Following is a summary of the emission inventory for each pollutant by source.

SO 2

Sulfur dioxide emissions come primarily from coal combustion at EGUs, but smaller amounts come from natural gas combustion, mobile sources and wood combustion.



### TABLE 

### 21—WYOMING 

### SO 2 

### E MISSIONS

### —2002 AND 

### 2018

Source Category Baseline 2002 Future 2018 Percent Change

Point .......................................................................................................................... ............................... 119,717 96,809

¥ 19 Area ........................................................................................................................... .............................. 16,689 23,093 38


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TABLE 

### 21—WYOMING 

### SO 2 

### E MISSIONS

### —2002 AND 

### 2018—Continued

Source Category Baseline 2002 Future 2018 Percent Change

On-Road Mobile ................................................................................................................. ...................... 959 81

¥ 92 Off-Road Mobile ................................................................................................................ ....................... 5,866 65

¥ 99 Oil & Gas ...................................................................................................................... ........................... 150 3

¥ 98 Road Dust ...................................................................................................................... .......................... 0 0 0 Fugitive Dust .................................................................................................................. .......................... 0 0 0 Windblown Dust ................................................................................................................. ...................... 0 0 0 Anthropogenic Fire ............................................................................................................. ..................... 173 109

¥ 37 Natural Fire ................................................................................................................... ........................... 2,286 2,286 0 Biogenic ....................................................................................................................... ............................ 0 0 0

Total .......................................................................................................................... ........................ 145,840 122,446

¥ 16

The State expects a 16% reduction in
SO 2 emissions by 2018 due to planned controls on existing sources, even with expected growth in generating capacity for the State. NO X NO X emissions in Wyoming comemostly from point sources and from onroad and off-road mobile sources.



### TABLE 

### 22—WYOMING 

### NO X 

### E MISSIONS

### —2002 AND 

### 2018

Source Category Baseline 2002 Future 2018 Percent Change

Point .......................................................................................................................... ............................... 117,806 110,109

¥ 7 Area ........................................................................................................................... .............................. 15,192 19,663 29 On-Road Mobile ................................................................................................................. ...................... 38,535 9,728

¥ 75 Off-Road Mobile ................................................................................................................ ....................... 76,637 49,677

¥ 35 Oil & Gas ...................................................................................................................... ........................... 14,725 34,142 132 Road Dust ...................................................................................................................... .......................... 0 0 0 Fugitive Dust .................................................................................................................. .......................... 0 0 0 Windblown Dust ................................................................................................................. ...................... 0 0 0 Anthropogenic Fire ............................................................................................................. ..................... 782 484

¥ 38 Natural Fire ................................................................................................................... ........................... 8,372 8,372 0 Biogenic ....................................................................................................................... ............................ 15,925 15,925 0

Total .......................................................................................................................... ........................ 287,974 248,100

¥ 14

The State expects NO X emissions to decrease by 14% by 2018, primarily due to significant reductions in mobile source emissions. The State projects that off-road and on-road vehicles emissions will decline by more than 55,760 tpy from the baseline 2002 emissions of 115,172 tpy.

OC

A wide variety of sources contribute emissions to this pollutant, including diesel emissions and combustion byproducts from wood and agricultural burning.



### TABLE 

### 23—WYOMING 

### OC E MISSIONS

### —2002 AND 

### 2018

Source Category Baseline 2002 Future 2018 Percent Change

Point .......................................................................................................................... ............................... 646 990 53 Area ........................................................................................................................... .............................. 2,000 1,975

¥ 1 On-Road Mobile ................................................................................................................. ...................... 304 249

¥ 18 Off-Road Mobile ................................................................................................................ ....................... 625 411

¥ 34 Oil & Gas ...................................................................................................................... ........................... 0 0 0 Road Dust ...................................................................................................................... .......................... 20 26 30 Fugitive Dust .................................................................................................................. .......................... 96 133 39 Windblown Dust ................................................................................................................. ...................... 0 0 0 Anthropogenic Fire ............................................................................................................. ..................... 1,709 886

¥ 48 Natural Fire ................................................................................................................... ........................... 23,793 23,793 0 Biogenic ....................................................................................................................... ............................ 0 0 0

Total .......................................................................................................................... ........................ 29,193 28,463

¥ 3

OC emissions from all sources are expected to show a 3% decline. Natural fire is the largest source contributing to OC emissions. The State does not have the ability to predict future emissions from natural fires and thus, the State


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held this category constant in the inventory. EC EC is a byproduct of incomplete combustion. EC emissions mainly come from mobile sources and natural fires.



### TABLE 

### 24—WYOMING 

### EC E MISSIONS

### —2002 AND 

### 2018

Source Category Baseline 2002 Future 2018 Percent Change

Point .......................................................................................................................... ............................... 104 180 73 Area ........................................................................................................................... .............................. 304 335 10 On-Road Mobile ................................................................................................................. ...................... 443 86

¥ 81 Off-Road Mobile ................................................................................................................ ....................... 1,986 1,161

¥ 42 Oil & Gas ...................................................................................................................... ........................... 0 0 0 Road Dust ...................................................................................................................... .......................... 2 2 0 Fugitive Dust .................................................................................................................. .......................... 7 9 29 Windblown Dust ................................................................................................................. ...................... 0 0 0 Anthropogenic Fire ............................................................................................................. ..................... 298 153

¥ 49 Natural Fire ................................................................................................................... ........................... 4,922 4,922 0 Biogenic ....................................................................................................................... ............................ 0 0 0

Total .......................................................................................................................... ........................ 8,066 6,848

¥ 15

The State predicts EC emissions to decrease approximately 15% by 2018. Reductions in manmade emissions of EC are largely due to mobile sources emission reductions resulting from new federal emission standards for mobile sources, especially for diesel engines.

PM 2.5

PM 2.5 emissions come mainly from agricultural and mining activities, windblown dust from construction areas, and emissions from unpaved and paved roads.



### TABLE 

### 25—WYOMING 

### PM 2.5 

### E MISSIONS

### —2002 AND 

### 2018

Source Category Baseline 2002 Future 2018 Percent Change

Point .......................................................................................................................... ............................... 11,375 15,709 38 Area ........................................................................................................................... .............................. 1,601 1,756 10 On-Road Mobile ................................................................................................................. ...................... 0 0 0 Off-Road Mobile ................................................................................................................ ....................... 0 0 0 Oil & Gas ...................................................................................................................... ........................... 0 0 0 Road Dust ...................................................................................................................... .......................... 160 206 29 Fugitive Dust .................................................................................................................. .......................... 2,082 2,882 38 Windblown Dust ................................................................................................................. ...................... 5,838 5,838 0 Anthropogenic Fire ............................................................................................................. ..................... 242 129

¥ 47 Natural Fire ................................................................................................................... ........................... 1,535 1,535 0 Biogenic ....................................................................................................................... ............................ 0 0 0

Total .......................................................................................................................... ........................ 22,833 28,055 23

The State predicts emissions of PM 2.5 to increase 23% by 2018. Emission increases are related to population growth and an increase in vehicle miles traveled. PM 10

PM 10 emissions come from many of the same sources as PM 2.5 emissions but other activities like rock crushing and processing, material transfer, open pit mining and unpaved road emissions can be prominent sources.



### TABLE 

### 26—WYOMING 

### PM 10 

### E MISSIONS

### —2002 AND 

### 2018

Source Category Baseline 2002 Future 2018 Percent Change

Point .......................................................................................................................... ............................... 24,751 30,619 24 Area ........................................................................................................................... .............................. 409 653 60 On-Road Mobile ................................................................................................................. ...................... 171 165

¥ 4 Off-Road Mobile ................................................................................................................ ....................... 0 0 0 Oil & Gas ...................................................................................................................... ........................... 0 0 0 Road Dust ...................................................................................................................... .......................... 1,125 1,449 29 Fugitive Dust .................................................................................................................. .......................... 18,030 25,144 39 Windblown Dust ................................................................................................................. ...................... 52,546 52,546 0 Anthro Fire .................................................................................................................... ........................... 259 109

¥ 58 Natural Fire ................................................................................................................... ........................... 5,369 5,369 0


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TABLE 

### 26—WYOMING 

### PM 10 

### E MISSIONS

### —2002 AND 

### 2018—Continued

Source Category Baseline 2002 Future 2018 Percent Change

Biogenic ....................................................................................................................... ............................ 0 0 0

Total .......................................................................................................................... ........................ 102,660 116,054 13

Overall, PM 10 emissions are expected to increase by 13%. Increases in coarse PM emissions are linked to population growth and vehicle miles traveled. NH 3

NH 3 emissions come from a variety of sources including wastewater treatment facilities, livestock operations, fertilizer application, mobile sources, and point

sources.



### TABLE 

### 27—WYOMING 

### NH 3 

### E MISSIONS

### —2002 AND 

### 2018

Source Category Baseline 2002 Future 2018 Percent Change

Point .......................................................................................................................... ............................... 685 1,398 104 Area ........................................................................................................................... .............................. 29,776 29,901 0 On-Road Mobile ................................................................................................................. ...................... 538 724 35 Off-Road Mobile ................................................................................................................ ....................... 41 57 39 Oil & Gas ...................................................................................................................... ........................... 0 0 0 Road Dust ...................................................................................................................... .......................... 0 0 0 Fugitive Dust .................................................................................................................. .......................... 0 0 0 Windblown Dust ................................................................................................................. ...................... 0 0 0 Anthropogenic Fire ............................................................................................................. ..................... 218 119

¥ 45 Natural Fire ................................................................................................................... ........................... 1,775 1,775 0 Biogenic ....................................................................................................................... ............................ 0 0 0

Total .......................................................................................................................... ........................ 33,033 33,974 3

NH 3 emissions are expected to increase by 3% by 2018. Increases in
NH 3 emissions are linked to population growth and increased vehicular traffic.

2. Consultation and Emissions Reductions for Other States’ Class I
Areas

40 CFR 51.308(d)(3)(i) requires that Wyoming consult with another state if its emissions are reasonably anticipated to contribute to visibility impairment at that state’s Class I area(s), and that Wyoming consult with other states if those other states’ emissions are reasonably anticipated to contribute to visibility impairment at its Class I areas. The State participated in regional planning, coordination, and consultation with other states in developing emission management strategies through the WRAP. Through the WRAP consultation process, Wyoming has reviewed and analyzed contributions from other states that reasonably may cause or contribute to visibility impairment in Wyoming’s Class I areas and analyzed Wyoming’s impact on other states’ Class I areas.

40 CFR 51.308(d)(3)(ii) requires that if Wyoming emissions cause or contribute to impairment in another state’s Class I area, Wyoming must demonstrate that it has included in its regional haze SIP all measures necessary to obtain its share of the emission reductions needed to meet the RPG for that Class I area. Section 51.308(d)(3)(ii) also requires that, since Wyoming participated in a regional planning process, it must ensure it has included all measures needed to achieve its apportionment of emission reduction obligations agreed upon through that process. As we state in the RHR, Wyoming’s commitments to participate in WRAP bind it to secure emission reductions agreed to as a result of that

process.

The State determined it did potentially impact Class I areas in South Dakota, Colorado, Utah, Idaho, Montana, and North Dakota (see Table 8.1.2.1–1 in the SIP). Wyoming accepted and incorporated the WRAP-developed visibility modeling into its regional haze SIP and the SIP includes the controls assumed in the modeling. Wyoming has satisfied the RHR requirements for consultation and included controls in the SIP sufficient to address the relevant requirements related to impacts on Class I areas in other states.

We are proposing to find that the State has met the requirements for consultation under 40 CFR 51.308(d)(3)(i) and 40 CFR 51.308(d)(3)(ii). 3. Mandatory Long-Term Strategy Requirements

40 CFR 51.308(d)(3)(v) requires that Wyoming, at a minimum, consider certain factors in developing its LTS. These are: (a) Emission reductions due to ongoing air pollution control programs, including measures to address RAVI; (b) measures to mitigate the impacts of construction activities; (c) emissions limitations and schedules for compliance to achieve the reasonable progress goals; (d) source retirement and replacement schedules; (e) smoke management techniques for agricultural and forestry management purposes including plans that 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 LTS.
a. Reductions Due to Ongoing Air Pollution Programs

In addition to its BART and reasonable progress determinations, the State’s LTS contains other reductions due to ongoing air pollution programs. The State’s LTS contains numerous ongoing air pollution programs, including: (1) New Source Review Program, which is a permit program for


### 33048 Federal Register / Vol. 77, No. 107 / Monday, June 4, 2012 / Proposed Rules

the construction of new sources and the modification of existing sources; (2) Prevention of Significant Deterioration Program, which protects visibility impairment from proposed major stationary sources or major modifications to existing facilities; and (3) New Source Performance Standards, which the State incorporates by reference on an annual basis. For a complete listing of ongoing air pollution programs in Wyoming, see Chapter 8.2.1 of the SIP.

b. Measures To Mitigate the Impacts of
Construction Activities

Chapter 3 of the Wyoming Air Quality Standards and Regulations (WAQSR) establishes limits on the quantity or concentration of emissions of air pollutants from numerous sources, including construction activities. Specifically, WAQSR Chapter 3, Section 2(f), prescribes measures to ensure the control of fugitive dust emissions during construction or demolition activities. WAQSR Chapter 3, Section 2(f) requires any person engaged in clearing or leveling of land, earthmoving, excavation, or movement of trucks or construction equipment over access haul roads or cleared land to take steps to minimize fugitive dust from such activities. Such control measures may include frequent watering and/or chemical stabilization. EPA approved WAQSR Chapter 3 into the SIP on July 28, 2004 (69 FR 44965).

c. Smoke Management

WAQSR Chapter 10 establishes restrictions and requirements on different types of burning in Wyoming. WAQSR Chapter 10, Section 2 regulates open burning, including refuse burning, open burning of trade wastes, open burning at salvage operations, open burning for firefighting training, and small vegetative material open burning (not exceeding 0.25 tons per day of PM). WAQSR Chapter 10, Section 3 regulates emissions from wood waste burners. EPA approved WAQSR Chapter 10, Section 2 and 3 into the SIP on July 28, 2004 (69 FR 44965). WAQSR Chapter 10, Section 4 was adopted by the State and submitted to EPA to meet the requirements for programs related to fire under 40 CFR 51.309(d)(6). Chapter 10, Section 4 seeks to minimize the impacts from private and prescribed burning on visibility in Class I areas and potentially affected populations. EPA is proposing approval of Chapter 10, Section 4 in a separate action. d. Emission Limitations and Schedules for Compliance

Chapter 6.5 of the State’s SIP contains the emission limitations and schedules for compliance for BART sources. Chapter 6.5 of the SIP requires the BART sources to install and demonstrate compliance with the State’s BART determination as expeditiously as practicable but no later than five years after EPA approval of the SIP. For some sources where controls have already been installed, the State specifies an earlier compliance deadline in Chapter 6.5 of the SIP. In addition, Chapter 8.3.3 of the SIP contains the emission limits and compliance schedule for LTS controls on Jim Bridger Units 1–4. e. Source Retirement and Replacement Schedules

The State is not currently aware of any specific scheduled shutdowns, retirements in upcoming years, or replacement schedules, such as planned installation of new control equipment to meet other regulations. If such actions occur, the State will factor them into upcoming reviews. f. Enforceability of Wyoming’s Measures

As discussed in section VII.D of this notice, EPA is proposing to disapprove the State’s SIP because it contains inadequate monitoring, recordkeeping, and reporting requirements, and we are proposing a FIP to address the enforceability of BART and reasonable progress controls. g. Anticipated Net Effect on Visibility Due to Projected Changes

The anticipated net effect on visibility due to projected changes in point, area, and mobile source emissions during this planning period is addressed in section VI.D.3 of this notice.4. Our Conclusions on Wyoming’s LongTerm Strategy

We propose to partially approve and partially disapprove Wyoming’s LTS. Because we are proposing to disapprove the NO X BART determinations for PacifiCorp Dave Johnston Unit 3, PacifiCorp Jim Bridger Units 1 and 2, PacifiCorp Wyodak Unit 1, and Basin Electric Laramie River Units 1, 2, and 3, we are also proposing to disapprove the corresponding emission limits and compliance schedules that Wyoming relied on as part of its LTS. Because we are proposing to disapprove the reasonable progress determination for PacifiCorp Dave Johnston Units 1 and 2, we are also proposing to disapprove the LTS because it does not include appropriate NO X reasonable progress emission limits and compliance schedules for Dave Johnston Units 1 and 2. We are also proposing to disapprove the State’s LTS because it does not contain the necessary monitoring, recordkeeping, and reporting requirements to make the BART and reasonable progress limits practically enforceable. Except for these elements, the State’s LTS satisfies the requirements of 40 CFR 51.308(d)(3), and we are proposing to approve it. F. Coordination of RAVI and Regional Haze Rule Requirements

Per 40 CFR 51.306(c), the State must provide for review and revision of a coordinated LTS for addressing RAVI and regional haze, and the State must submit the first such coordinated LTS with its first regional haze SIP. The State failed to provide for the coordination of their RAVI and regional haze LTS. We are proposing to disapprove the State’s SIP as not meeting the requirements of 40 CFR 51.306(c). We are proposing a FIP as explained in section VII.F of this notice to meet the coordination requirements of 40 CFR 51.306(c). G. Monitoring Strategy and Other Implementation Plan Requirements

40 CFR 51.308(d)(4) requires that the SIP contain a monitoring strategy for measuring, characterizing, and reporting regional haze visibility impairment that is representative of all mandatory Class I Federal areas within the state. This monitoring strategy must be coordinated with the monitoring strategy required in 40 CFR 51.305 for RAVI. As 40 CFR 51.308(d)(4) notes, compliance with this requirement may be met through participation in the IMPROVE network. 40 CFR 51.308(d)(4)(i) further requires the establishment of any additional monitoring sites or equipment needed to assess whether the RPGs for all mandatory Class I Federal areas within the state are being achieved.

Consistent with EPA’s monitoring regulations for RAVI and regional haze, Wyoming states in Chapter 9 of the regional haze SIP that it will rely on the IMPROVE network for compliance purposes, in addition to any additional visibility impairment monitoring that may be needed in the future.

Section 51.308(d)(4)(ii) requires that states establish procedures by which monitoring data and other information are used in determining the contribution of emissions from within Wyoming to regional haze visibility impairment at mandatory Class I Federal areas both within and outside the state. The IMPROVE monitoring program is national in scope, and other states have similar monitoring and data reporting


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procedures, ensuring a consistent and robust monitoring data collection system. As 40 CFR 51.308(d)(4) indicates, Wyoming’s participation in the IMPROVE program constitutes compliance with this requirement.

40 CFR 51.308(d)(4)(iv) requires that the SIP provide for the reporting of all visibility monitoring data to the Administrator, at least annually, for each mandatory Class I Federal area in the state. To the extent possible, Wyoming should report visibility monitoring data electronically. 40 CFR 51.308(d)(4)(vi) also requires that the SIP provide for other elements, including reporting, recordkeeping, and other measures, necessary to assess and report on visibility. We propose that Wyoming’s participation in the IMPROVE network ensures that the monitoring data is reported at least annually and is easily accessible; therefore, such participation complies with this requirement. IMPROVE data are centrally compiled and made available to EPA, states and the public via various electronic formats and Web sites including IMPROVE (http://vista. cira.colostate.edu/improve/ ) and VIEWS (http://vista.cira.colostate.edu/views/ ). 40 CFR 51.308(d)(4)(v) requires that Wyoming maintain a statewide inventory of emissions of pollutants that are reasonably anticipated to cause or contribute to visibility impairment in any mandatory Class I Federal 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. The State must also include a commitment to update the inventory periodically. The State’s emission inventory is discussed in section VI.F.1 of this notice. Wyoming states in Chapter 9 of the SIP that it intends to update the Wyoming statewide emissions inventories periodically and review periodic emissions information from other states and future emissions projections. We propose that this satisfies the requirement.

40 CFR 51.308(d)(4)(vi) requires that states provide for any additional reporting, recordkeeping, and measures necessary to evaluate and report on visibility. The State of Wyoming, in accordance with provisions of 40 CFR 51.308(d)(4)(vi), will track data related to regional haze for sources for which the State has regulatory authority, and will depend on the IMPROVE program and RPO sponsored collection and analysis efforts for monitoring and emissions inventory data, respectively. To ensure the availability of data and analyses to report on visibility conditions and progress toward Class I area visibility goals, the State of Wyoming will collaborate with members of a RPO to ensure the continued operation of the IMPROVE program and RPO sponsored technical support analysis tools and systems.

We propose to find that the State’s SIP satisfies the requirements of 40 CFR 51.308(d)(4).

H. Consultation With FLMs

Although the FLMs are very active in participating in the RPOs, the RHR grants the FLMs a special role in the review of the regional haze SIPs, summarized in section V.H, above. Under 40 CFR 51.308(i)(2), states are obligated to provide the FLMs with an opportunity for consultation, in person, and at least 60 days prior to holding a public hearing on the regional haze SIP. The State provided an opportunity for FLM consultation, in person and at least 60 days prior to holding any public hearing on the SIP. As required by 40 CFR Section 51.308(i)(3), the State has included FLM comments and State responses in Chapter 11 of the Wyoming TSD.

40 CFR 51.308(i)(3) requires that States provide in its regional haze SIP a description of how it addressed any comments provided by the FLMs. The FLMs formally commented on the Wyoming proposed SIP in November and December of 2010. The FLM comments provided support for the modeling approach used by the State in the BART determinations and complimented the State on thorough BART, reasonable progress, and area source analysis. The FLMs also recommended the State reevaluate costs and emission limits for some of the BART and reasonable progress sources. Chapter 11 of the State’s TSD provides detailed information on the State’s response to FLM comments.

Lastly, 40 CFR 51.308(i)(4) specifies the regional haze SIP must provide procedures for continuing consultation between a State and FLMs on the implementation of the visibility protection program required by 40 CFR 51.308. This includes development and review of implementation plan revisions and five-year progress reports and the implementation of other programs having the potential to contribute to impairment of visibility in mandatory Class I Federal areas. Pursuant to Chapter 11.2 of the SIP, the State will provide the FLMs an opportunity to review and comment on SIP revisions, the five-year progress reports, and other developing programs that may contribute to Class I visibility impairment. We are proposing that the State’s SIP satisfies the requirements of 40 CFR 51.308(i).

I. Periodic SIP Revisions and 5-Year Progress Reports

40 CFR 51.308(f) requires a State to revise and submit its regional haze SIP to EPA by July 31, 2018, and every ten years thereafter. Pursuant to Chapter 10 of the SIP, the State will provide this revision. In accordance with the requirements listed in 40 CFR 51.308(g), the State will submit a report on reasonable progress to EPA every five years following the initial submittal of the SIP. That report will be in the form of an implementation plan revision. The State’s report will evaluate the progress made toward the RPGs for each mandatory Class I area located within the State and in each mandatory Class I area located outside the State, which have been identified as being affected by emissions from the State. The State will also evaluate the monitoring strategy adequacy in assessing RPGs.

Based on the findings of the five-year progress report, 40 CFR 51.308(h) requires a State to make a determination of adequacy of the current implementation plan. The State must take one or more of the actions listed in 40 CFR 51.308(h)(1) through (4) that are applicable at the same time as the State submits a five-year progress report. Chapter 12 of the SIP requires the State to make an adequacy determination of the current SIP pursuant to 40 CFR 51.308(h)(1) through (4) at the same time a five-year progress report is due.

We propose to find the State’s SIP satisfies the requirements of 40 CFR 51.308(f)–(h). VII. Federal Implementation Plan

EPA is proposing a FIP to address the deficiencies indentified in our proposed partial disapproval of Wyoming’s regional haze SIP. In lieu of this proposed FIP, or a portion thereof, we would propose approval of a SIP revision if the State submits such a revision and the revision matches the terms of our proposed FIP. We encourage the State to submit a SIP revision to replace the FIP, either before or after our final action. A. Disapproval of the State’s NO X BART Determinations and Federal Implementation Plan for NO X BART Determinations and Limits

As noted above, the State provided five-factor analyses that considered all factors, except analyzing the degree of visibility improvement modeling for each individual pollutant. Thus, in disapproving specific State BART


### 33050 Federal Register / Vol. 77, No. 107 / Monday, June 4, 2012 / Proposed Rules

determinations, we are basing our analysis on information provided by the State in their BART analysis, with the exception of visibility improvement modeling. We have accepted the cost information provided by the State. As discussed above, visibility improvement modeling was performed by the EPA. EPA is proposing to disapprove the State’s NO X BART determinations, and we are proposing to issue a BART FIP, for the following units: PacifiCorp Dave Johnston Unit 3, PacifiCorp Jim Bridger Units 1 and 2, PacifiCorp Wyodak Unit 1, and Basin Electric Laramie River Units 1, 2, and 3. EPA’s rationale for disapproving the State’s BART determinations for these units, as well as EPA’s BART FIP determinations and emission limits, is discussed below.

1. Disapproval of the State’s Basin Electric Laramie River Units 1–3 NO X BART Determination and FIP To Address NO X BART
Wyoming’s NO X BART Determination

All three units are currently controlled with LNBs with a permit limit of 0.5 lbs/MMBtu (3-hour rolling average). The State determined that new LNBs, OFA, LNBs and OFA, SNCR/SCR hybrid, LNBs and OFA with SNCR, and SCR were technically feasible for reducing NO X emissions at Units 1–3. The State determined that natural gas reburn was technically infeasible. TheState did not identify any energy or nonair quality environmental impacts that would preclude the selection of any of the controls evaluated, and there are no remaining-useful-life issues for this source. A summary of the State’s NO X BART analysis is provided in Tables 28–30 below. As discussed above, the visibility improvement modeling results in these tables were developed by EPA. Baseline NO X emissions are 6,320 tpy for Unit 1, 6,285 tpy for Unit 2, and 6,448 tpy for Unit 3 based on an average on 2001–2003 actual emissions.



### TABLE 

### 28—S UMMARY OF 

### BASIN 

### E LECTRIC 

### LARAMIE 

### R IVER 

### U NIT 

### 1 NO X 

### BART A NALYSIS

Control Technology Control Efficiency (%) Emission Rate (lb/MMBtu)(30-day Rolling Average) Emission Reduction

(tpy) Annualized Costs Average Cost Effectiveness ($/ton) Visibility Improvement (Delta dv for the Maximum 98th Percentile Impact at Wind Cave National Park)

OFA .......................................................... 14.8 0.23 936 $625,000 $668 0.08 LNBs ........................................................ 14.8 0.23 936 1,360,000 1,453 0.08 LNBs with OFA ........................................ 14.8 0.23 936 1,944,000 2,077 0.08 SNCR/SCR Hybrid ................................... 25.9 0.20 1,639 7,429,000 4,534 ........................ LNBs with OFA and SNCR ...................... 55.6 0.12 3,511 7,365,000 2,098 0.32 SCR .......................................................... 74.1 0.07 4,681 15,787,000 3,372 0.44

Incremental cost effectiveness for the controls evaluated is as follows: LNBs with OFA and SNCR: $2,105/ton, and SCR: $7,198/ton.



### TABLE 

### 29—S UMMARY OF 

### BASIN 

### E LECTRIC 

### LARAMIE 

### R IVER 

### U NIT 

### 2 NO X 

### BART A NALYSIS

Control Technology Control Efficiency (%) Emission Rate (lb/MMBtu)(30-day Rolling Average) Emission Reduction

(tpy) Annualized Costs Average Cost Effectiveness ($/ton) Visibility Improvement (Delta dv for the Maximum 98th Percentile Impact at Wind Cave National Park)

OFA .......................................................... 14.3 0.23 931 $625,000 $671 0.08 LNBs ........................................................ 14.3 0.23 931 1,360,000 1,461 0.08 LNBs with OFA ........................................ 14.3 0.23 931 1,944,000 2,088 0.08 SNCR/SCR Hybrid ................................... 25.5 0.20 1,630 7,429,000 4,559 ........................ LNBs with OFA and SNCR ...................... 55.3 0.12 3,492 7,365,000 2,109 0.32 SCR .......................................................... 73.9 0.07 4,656 15,787,000 3,391 0.44

Incremental cost effectiveness for the controls evaluated is as follows: LNBs with OFA and SNCR: $2,117/ton; and SCR: $7,242/ton.



### TABLE 

### 30—S UMMARY OF 

### BASIN 

### E LECTRIC 

### LARAMIE 

### R IVER 

### U NIT 

### 3 NO X 

### BART A NALYSIS

Control Technology Control Efficiency (%) Emission Rate (lb/MMBtu)(30-day Rolling Average) Emission Reduction

(tpy) Annualized Costs Average Cost Effectiveness ($/ton) Visibility Improvement (Delta dv for the Maximum 98th Percentile Impact at Wind Cave National Park)

OFA .......................................................... 16.5 0.23 955 $625,000 $654 0.08


### 33051 Federal Register / Vol. 77, No. 107 / Monday, June 4, 2012 / Proposed Rules

32 Since the State did not provide costs for the source to achieve a 0.21 lb/MMBtu emission limit and EPA did not model a 0.21 lb/MMBtu control option, we are basing our analysis on the information for LNBs with OFA at a limit of 0.23 lb/MMBtu. 

### TABLE 

### 30—S UMMARY OF 

### BASIN 

### E LECTRIC 

### LARAMIE 

### R IVER 

### U NIT 

### 3 NO X 

### BART A NALYSIS

### —Continued

Control Technology Control Efficiency (%) Emission Rate (lb/MMBtu)(30-day Rolling Average) Emission Reduction

(tpy) Annualized Costs Average Cost Effectiveness ($/ton) Visibility Improvement (Delta dv for the Maximum 98th Percentile Impact at Wind Cave National Park)

LNBs ........................................................ 16.5 0.23 955 1,360,000 1,424 0.08 LNBs with OFA ........................................ 16.5 0.23 955 1,944,000 2,036 0.08 SNCR/SCR Hybrid ................................... 27.4 0.20 1,672 7,429,000 4,444 ........................ LNBs with OFA and SNCR ...................... 56.4 0.12 3,582 7,365,000 2,056 0.33 SCR .......................................................... 74.6 0.07 4,777 15,787,000 3,305 0.44

Incremental cost effectiveness for the controls evaluated is as follows: LNBs with OFA and SNCR: $2,064/ton, and SCR: $7,054/ton.

The State eliminated the SNCR/SCR hybrid from further consideration because it has higher cost effectiveness and lower control efficiency compared to new LNBs plus OFA with SNCR.

Based on its consideration of the five factors, the State determined LNBs with OFA was reasonable for NO X BART. The State determined that the NO X BART emission limits for Laramie River Unit 1 are 0.23 lb/MMBtu (30-day rolling average), 1,348 lb/hr (30-day rolling average), and 5,343 tpy. The State determined the NO X BART emission limits for Laramie River Unit 2 are 0.23 lb/MMBtu (30-day rolling average), 1,348 lb/hr (30-day rolling average), and 5,343 tpy. The State determined the NO X BART emission limits for Laramie River Unit 3 are 0.23 lb/MMBtu (30-day rolling average), 1,386 lb/hr (30-day rolling average), and 5,493 tpy.

The State’s proposed SIP required additional NO X emission reductions for Laramie River under its LTS. Based on the costs and visibility improvement for Laramie River Station Units 1, 2, and 3, the State proposed installation of two SCRs, or equivalent performing emission control systems, at any of the three units. The State proposed that the add-on NO X control achieve an emission rate, on an individual unit basis, at or below 0.07 lb/MMBtu on a 30-day rolling average. The State proposed that the add-on controls be installed and operational on one of the Laramie River Station units by December 31, 2018 and on a second Laramie River Station unit by December 31, 2023.

On March 8, 2010, Basin Electric Power Cooperative appealed the additional controls proposed by the State under its LTS before the Wyoming Environmental Quality Council. The State entered into a settlement agreement on November 16, 2010 with Basin Electric Power Cooperative (a copy of the settlement agreement is included in the State’s revised NO X BART Analysis for Laramie River dated January 3, 2011). As part of the settlement agreement, the State agreed to remove the requirement for Basin Electric to install additional controls under the LTS. In return, Basin Electric agreed to additional NO X emissions reductions under BART. Under the settlement agreement, Basin Electric agreed to a NO X emission limit of 0.21 lb/MMBtu (30-day rolling average) on all three units. Basin Electric also agreed to a NO X emission limit for Unit 1 and Unit 2 of 4,780 tpy and a NO X emission limit for Unit 3 of 4,914 tpy, effectively capping emissions from all three units at 12,773 tpy. In the SIP adopted by the State, the State determined the emission limits in the settlement agreement were BART for Basin Electric Laramie River Units 1, 2, and 3.

EPA’s Conclusions on Basin Electric Laramie River Units 1–3 NO X BART Determination and FIP for NO X BART

EPA does not agree with the State’s conclusion that a limit of 0.21 lb/ MMBtu is reasonable for BART for Laramie River Units 1, 2, and 3, which can be achieved with the installation and operation of LNBs with OFA. In particular, the cost effectiveness values for LNBs with OFA plus SNCR at this unit is only slightly higher than LNBs with OFA (i.e., about $20/ton), with incremental costs of approximately $2,100. 32 The increase in cost effectiveness for LNBs with OFA plus SNCR affords a visibility improvement of 0.23 delta deciview per unit over LNBs plus OFA. LNBs with OFA plus SNCR would result in total NO X emissions of 8,468 tpy—4,305 tpy less than the State’s BART determination. We find that it was unreasonable for the State not to determine that LNBs with OFA plus SNCR was NO X BART for Laramie River Units 1–3. Thus, we are proposing to disapprove the State’s NO X BART determination for Basin Electric Laramie River Units 1, 2, and 3 and proposing a FIP for NO X BART as explained below.

Based on our examination of the State’s costs estimates, emission reductions, and the predicted visibility improvement, we propose to find that LNBs with OFA plus SNCR at an emission limit of 0.12 lb/MMBtu (30- day rolling average) is reasonable for NO X BART for Basin Electric Laramie River Units 1, 2, and 3. We are proposing that the FIP NO X BART emission limit for Basin Electric Laramie River Unit 1, Unit 2, and Unit 3 is 0.12 lb/MMBtu (30-day rolling average).

We have eliminated the single highest performing option from consideration— LNBs with OFA plus SCR—because the cost effectiveness value is significantly higher than LNBs with OFA and there is a comparatively small incremental visibility improvement over LNBs with OFA.

We propose that Basin Electric meet our proposed emission limit at Laramie River Units 1, 2, and 3 no later than five years after EPA finalizes action on our proposed FIP. This is consistent with the requirements of 40 CFR 51.308(e)(iv).
2. Disapproval of the State’s PacifiCorp Dave Johnston Unit 3 NO X BART Determination and FIP To Address NO X BART Wyoming’s NO X BART Determination

Dave Johnston Unit 3 is currently uncontrolled for NO X . The State determined LNBs with advanced OFA, LNBs with advanced OFA and SNCR, and LNBs with advanced OFA and SCR were technically feasible for controlling


### 33052 Federal Register / Vol. 77, No. 107 / Monday, June 4, 2012 / Proposed Rules

33 We are assuming the same costs for Unit 2 as the other Jim Bridger Units. The State analyzed Unit 2 using post installation of LNBs/OFA costs so the cost information provided in their analysis is not consistent with an uncontrolled baseline. NO X emissions from Unit 3. The State did not identify any technically infeasible controls.

The State did not identify any energy or non-air quality environmental impacts that would preclude the selection of any of the controlsevaluated, and there are no remaininguseful-life issues for this source. Baseline NO X emissions are 5,814 tpy for Unit 3 based on unit heat input rate of 2,500 MMBtu/hr and 7,884 hours of operation. A summary of the State’s NO X BART analysis and the visibility impacts is provided in Table 31 below.



### TABLE 

### 31—S UMMARY OF 

### D AVE 

### J OHNSTON 

### U NIT 

### 3 NO X 

### BART A NALYSIS

Control Technology Control Efficiency (%) Emission Rate (lb/MMBtu)(30-day Rolling Average) Emission Reduction

(tpy) Annualized Costs Average Cost Effectiveness ($/ton) Visibility Improvement (Delta deciview for the Maximum 98th Percentile Impact at Wind Cave National Park)

LNB with advanced OFA ......................... 46.8 0.28 2,723 $1,764,775 $648 0.77 New LNB with advanced OFA and

SNCR ................................................... 63.9 0.19 3,717 2,679,192 721 0.94 LNB with advanced OFA and SCR ......... 86.7 0.07 5,041 16,347,519 3,243 1.16

Incremental cost effectiveness for the controls evaluated is as follows: New LNB with advanced OFA and SNCR: $920/ton, and LNB with advanced OFA and SCR: $10,234/ton.

Based on its consideration of the five factors, the State determined LNBs with OFA was reasonable for NO X BART. The State determined the cost of compliance (capital costs and annual operating and maintenance costs) were significantly higher for the addition of SCR. The State determined the NO X BART emission limits for Unit 3 are 0.28 lb/MMBtu (30-day rolling average), 784 lb/hr (30-day rolling average), and 3,434 tpy. EPA’s Conclusions on Dave Johnston Unit 3 NO X BART Determination and FIP for NO X BART

EPA does not agree with the State’s conclusion that a limit of 0.28 lb/ MMBtu is reasonable for NO X BART for Dave Johnston Unit 3, which can be achieved with the installation and operation on LNBs with OFA. In particular, the cost effectiveness values for LNB with OFA and SNCR at this unit is only $73/ton higher than LNBs with OFA, with incremental costs of $920. The increase in cost effectiveness for LNBs with OFA plus SNCR affords visibility improvement over LNBs plus OFA of 0.17 delta deciview. LNBs with OFA plus SNCR would result in an additional reduction of 994 tons of NO X . We find that it was unreasonable for the State not to determine that LNBs with OFA plus SNCR was NO X BART for Dave Johnston Unit 3. Thus, we are proposing to disapprove the State’s NO X BART determination for Dave Johnston Unit 3 and proposing a FIP for NO X BART as explained below.

Based on our examination of the State’s costs estimates, emission reductions, and the predicted visibility improvement, we propose to find that LNBs with OFA plus SNCR at an emission limit of 0.19 lb/MMBtu (30- day rolling average) is reasonable for NO X BART for Dave Johnston Unit 3. We are proposing that the FIP NO X BART emission limit for PacifiCorp Dave Johnston Unit 3 is 0.19 lb/MMBtu (30-day rolling average).

We have eliminated the single highest performing option from consideration— LNBs with OFA plus SCR—because the cost effectiveness value is significantly higher than LNBs with OFA and there is a comparatively small incremental visibility improvement over LNBs with OFA.

We propose that PacifiCorp meet our proposed emission limit at Dave Johnston Unit 3 no later than five years after EPA finalizes action on our proposed FIP. This is consistent with the requirements of 40 CFR 51.308(e)(iv).
3. Disapproval of the State’s PacifiCorp Jim Bridger Units 1 and 2 NO X BART Determination and FIP To Address NO X BART Wyoming’s NO X BART Determination

PacifiCorp Jim Bridger Units 1 and 2 are equipped with early generation LNBs with a permit limit of 0.70 lb/ MMBtu (3-hour fixed). The State determined that LNBs with SOFA, ROFA, LNBs with SOFA plus SNCR, and LNBs with SOFA plus SCR were technically feasible for controlling NO X emissions. The State did not identify any technically infeasible options.

The State did not identify any energy or non-air quality environmental impacts that would preclude the selection of any of the controlsevaluated, nor are there any remaininguseful-life issues for this source. Baseline NO X emissions are 10,643 tpy for all both units based on unit heat input rate of 6,000 MMBtu/hr and 7,884 hours of operation. A summary of the State’s NO X BART analysis and the visibility impacts is provided in Table 32 below. 33


### 33053 Federal Register / Vol. 77, No. 107 / Monday, June 4, 2012 / Proposed Rules

34 Unit 4 has different modeling results than the other three units as the stack parameters used in the modeling are different enough from Units 1–3 to yield different modeled results. 35 Wyoming determined that LNBs with OFA and SCR was BART for Naughton Unit 3. The cost effectiveness of SCR for Naughton Unit 3 is $2,830 with 1.0 deciview of visibility improvement. 36 The proposed regulatory language for this rulemaking only covers our first proposed approach. 

### TABLE 

### 32—S UMMARY OF 

### J IM 

### B RIDGER 

### U NITS 

### 1 AND 

### 2 NO X 

### BART A NALYSIS

### —C OSTS PER 

### B OILER

Control Technology Control Efficiency (%) Emission Rate (lb/MMBtu)(30-day Rolling Average) Emission Reduction

(tpy) Annualized Costs Average Cost Effectiveness ($/ton) Visibility Improvement (Delta deciview for the Maximum 98th Percentile Impact at Mt. Zirkel Wilderness)— Units 1—3/4–34

LNB with SOFA .......................................... 42.2 0.26 4,493 $1,144,969 $255 .41/.47 New LNB with SOFA and SNCR ............... 55.6 0.20 5,913 2,710,801 459 .52/.62 LNB with SOFA and SCR .......................... 84.4 0.07 8,987 20,296,400 2,258 .76/.82

Incremental cost effectiveness for the control evaluated is as follows: New LNB with SOFA and SNCR: $1,103/ton, and LNB with SOFA and SCR: $5,721/

ton.

Based on its consideration of the five factors, the State determined LNBs with SOFA was reasonable for NO X BART. The State determined the cost of compliance (capital costs and annual operating and maintenance costs) were significantly higher for the addition of SCR. The State determined the NO X BART emission limits for Jim Bridger Units 1 and 2 are 0.28 lb/MMBtu (30- day rolling average), 1,560 lb/hr (30-day average), and 6,833 tpy.

PacifiCorp is required to install additional controls under the State’s LTS. The State determined that based on the cost of compliance and visibility improvement presented by PacifiCorp in the BART applications for Jim Bridger Units 1 and 2 and taking into consideration the logistical challenge of managing multiple pollution control installations within the regulatory time allotted for installation of BART by the RHR, additional controls would be required under the LTS but not BART. With respect to Jim Bridger Units 1 and 2, the State has required PacifiCorp to install SCR, or other NO X control systems, to achieve an emission limit or otherwise reduce NO X emissions to achieve a 0.07 lb/MMBtu 30-day rolling average NO X emissions rate. PacifiCorp is required to meet the 0.07 lb/MMBtu emission rate on Unit 1 prior to December 31, 2021 and on Unit 2 prior to December 31, 2022.

EPA does not agree with the State’s conclusion that a limit of 0.26 lb/ MMBtu is reasonable for BART for Jim Bridger Units 1 and 2, which can be achieved with the installation and operation on LNBs with SOFA. In particular, the cost effectiveness values for LNBs with SOFA and SCR at each unit is $2,258 with approximately 0.80 delta deciview visibility improvement. The cost effectiveness values are reasonable and the visibility improvement significant for LNBs with SOFA plus SCR. In addition, the costs are within the range that Wyoming has considered reasonable in the BART

context. 35 LNBs with OFA plus SCR would result in an additional reduction of 4,494 tpy of NO X emissions at each unit. This difference is substantial. We find that it was unreasonable for the State not to determine that LNBs with OFA plus SCR was NO X BART for Jim Bridger Units 1 and 2. Though the State is requiring the installation of SCR on Units 1 and 2 under its LTS, the compliance date for both installations is beyond the five-years allowed for BART sources by 40 CFR 51.308(e)(iv). Thus, we are proposing to disapprove the State’s NO X BART determination for Jim Bridger Units 1 and 2 and proposing a FIP for NO X BART as explained below.

Based on our examination of the State’s costs estimates, emission reductions, and the predicted visibility improvement, we propose to find that LNBs with SOFA plus SCR at an emission limit of 0.07 lb/MMBtu (30- day rolling average) is reasonable for NO X BART for Jim Bridger Units 1 and 2. Because our examination of the factors leads us to propose SCR is reasonable for BART, we have eliminated SNCR from further consideration. We are proposing that the FIP NO X BART emission limit for PacifiCorp Units 1 and 2 is 0.07 lb/ MMBtu (30-day rolling average).

We propose that PacifiCorp meet our proposed emission limit at Jim Bridger Unit 1 and 2 no later than five years after EPA finalizes action on our proposed FIP. This is consistent with the requirements of 40 CFR 51.308(e)(iv). 4. Proposals in the Alternative for PacifiCorp Jim Bridger Units 1, 2, 3, and 4 NO X BART

As noted above, EPA is seeking comment on a proposal (‘‘first proposed approach’’) to approve in part and disapprove in part the regional haze plan submitted by the State. Among other things, EPA’s proposal would determine that BART for Units 1 and 2 of the BART-eligible Jim Bridger power plant is SCR, and would establish corresponding NOx emission limits for these units that would have to be achieved within 5 years of our final action. 36 This would have the effect of accelerating the installation of the SCR controls at these units that the State and source owner (PacifiCorp) had proposedto install later (in the 2021–2022 timeperiod). The State determined that BART for these units is LNB plus OFA, and selected the 2021–2022 time-period for SCR-based emission limits as a reasonable progress measure. The delay was based on the large number of actions PacifiCorp is undertaking (or helping to finance) at a large number of EGUs in Wyoming, Utah, Colorado, andArizona that it owns and operates or coowns.

EPA is also seeking comment on an alternative approach (‘‘second proposed approach’’) that differs from our first proposed approach only with regard to Units 3 and 4 at Jim Bridger. The second proposed approach would only differ from the first proposed approach by allowing PacifiCorp to install SCR at Jim Bridger Units 3 and 4 within five years from the date of our final action. This would differ from the first proposed approach that requires PacifiCorp to install SCR at Unit 3 by 2015 and Unit 4 by 2016, while we would still propose SCR on Units 1 and 2 within the five year BART installation timeframe. This second proposed approach would allow PacifiCorp flexibility on timing for the


### 33054 Federal Register / Vol. 77, No. 107 / Monday, June 4, 2012 / Proposed Rules

37 For a listing of PacifiCorp’s retrofit actions, see Table 1 of Exhibit A—PacifiCorp’s Emissions Reductions Plan in Chapter 6 of the State’s TSD.

38 See Exhibit A—PacifiCorp’s Emissions Reductions Plan in Chapter 6 of the State’s TSD. 39 See Exhibit A—PacifiCorp’s Emissions Reductions Plan in Chapter 6 of the State’s TSD. installation of SCR on all four Jim Bridger Units within the BART installation timeline allowed by the RHR. Installing SCR on all four units within the statutory five year period would provide PacifiCorp maximum flexibility to manage the implementation of controls on all the units.

EPA also is seeking comment on another alternative approach (‘‘third proposed approach’’) that differs from the first proposed approach only with regard to Units 1 and 2 at Jim Bridger. This third proposed approach would include a different determination regarding BART for these units and would have the effect of approving the state’s timeline for the installation of SCR technologies at Units 1 and 2.

PacifiCorp asserted to the State during formulation of the SIP proposal, and has since asserted directly to EPA, that a number of factors, when considered together, suggest that requiring installation of SCR at Jim Bridger Units 1 and 2 earlier than 2021–2022 is not reasonable. First, PacifiCorp points to the large number of retrofit actions it is taking at 20 coal-fired electric generating units in Wyoming, Utah, and Arizona in order to reduce their emissions. 37 These retrofits are intended to comply with the requirements in the regional haze SIPs that these states have submitted to EPA and with other regulatory requirements, including required controls for mercury and acid gases under the recent Mercury and Air Toxics Standards rule. The company claims that there are high capital costs for the measures required for these air quality-improving retrofits. Moreover, PacifiCorp states that accelerating the required installation of SCR at Jim Bridger Units 1 and 2 to late 2017, rather than the 2021 and 2022 dates established by the State, would significantly increase the costs to the utility and to its customers. 38

In addition, the company asserts that it has designed the installation schedule in order to minimize the number of units that are out of service system wide for installation of emissions controls at any one time. Its goal, it asserts, is to be able to maintain service to its customers with an adequate capacity margin. The company asserts that accelerating the timeline for installation of SCR would upset the orderly shut-down schedule they have devised and would threaten both service interruptions and an increased risk of spot-purchases of more expensive electrical energy, if it is available, to serve customers, but that either eventuality would significantly increase costs to its customers. 39

Taken together, PacifiCorp claims that the schedule for installation of emissions control devices envisioned in our first proposed approach would be excessively costly and would pose service interruption risks for electrical energy customers over a large part of the region. EPA notes that PacifiCorp has offered these claims taking into account only the requirements in the SIPs that have been submitted to EPA by Wyoming, Utah, Colorado, and Arizona. Today’s proposal includes requirements that would likely require the additional installation of SNCRs at two units owned by PacifiCorp in Wyoming. In addition, we have proposed to partially disapprove the SIP for Utah, and the eventual resolution of this disapproval may involve requirements for retrofits of more units owned by PacifiCorp in that state. We have not yet proposed action on the SIP for Arizona, and the possibility that the Cholla power plant that is partially owned by PacifiCorp may require retrofits not already in PacifiCorp’s plans, cannot be ruled out at this time.

Based on the claims made both by the State and PacifiCorp and noting the additional requirements in the proposed FIP for Wyoming and the possibility of additional requirements in future FIPs or SIPs in Utah and Arizona, EPA is seeking comment on these assertions of cost infeasibility and risk to electrical power reliability, as well as the desirability of the third proposed approach including the possible rationale for this third approach as described below.

Our third proposed approach has two parts, one addressing BART and one addressing reasonable progress with respect to Jim Bridger. First, EPA would determine that the facts indicate that BART for the all the units at Jim Bridger is SCR when the units are considered individually based on the five factors without regard the status of those factors for other units in the PacifiCorp system. However, when the five factors are considered across all the units in that system, including the fact that EPA’s actions on the SIPs for Wyoming, Utah, and Arizona may create additionalretrofit obligations for other PacifiCorpowned EGUs, BART for Jim Bridger as a whole is SCR on Units 3 and 4 and LNB plus OFA on Units 1 and 2. Costs, considered broadly, would be unreasonable to require any further retrofits at this source within 5 years of our final action. We note that the CAA establishes 5 years at the longest period that can be allowed for compliance with BART emission limits.

The second part of our third proposed approach is that EPA would approve the SIP with regard to the State’s determination that the appropriate level of NO X control for Units 1 and 2 at Jim Bridger for purposes of reasonable progress is the SCR-based emission limit in the SIP, with compliance dates of December 31, 2021 for Unit 2 and December 31, 2022 for Unit 1. We believe it may be reasonable and feasible for these retrofits to be completed somewhat earlier than these dates even if, as would be necessary to conclude this third approach to have merit, they cannot be completed within 5 years of our final action. However, in the context of reasonable progress in the second planning period of the regional haze program, we believe it may be appropriate to give considerable deference to the State’s conclusions about what controls are reasonable and when they should be implemented. Thus, assuming that we were to finalize this third approach, we do not believe at this time that it would be appropriate to disapprove the State’s preferred compliance deadlines for Units 1 and 2.

Under the third proposed approach, we would approve the SIP’s provisions for Units 1 and 2 and not adopt a FIP, because while we would disagree with the State’s reasoning, we would be agreeing with the outcome in terms of the sequence of emission limits that apply to these units and their compliance deadlines. We would be agreeing with the outcome within the context of the phased regional haze statutory and regulatory framework.

As stated above, we are asking for comments and information pertaining to our second and third proposed approaches. We need more information to be able to support either alternative approach. If we receive such information, we will provide notice to the public on the availability of such information. We request that any information be submitted as soon as possible, but preferably no later than 30 days after the publication date of this notice. We are requesting that information be submitted within this timeframe to give the public an opportunity to review and comment on the information before the end of the comment period.


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40 A summary of EPA’s modeling methodology and results can be found in the docket under EPA BART and RP Modeling for Wyoming Sources. 5. Disapproval of the State’s PacifiCorp Wyodak Unit 1 NO X BART Determination and FIP To Address NO X BART Wyoming’s NO X BART Determination

Wyodak Unit 1 is currently controlled for NO X emissions with early generation LNBs with a permit limit of 0.70 lb/ MMBtu (3-hour block). The State determined new LNBs with OFA, existing LNBs with ROFA, new LNBs with OFA plus SNCR, and LNBs with OFA plus SCR were technically feasible for controlling NO X emissions. The State did not identify any technically infeasible control options.

The State did not identify any energy or non-air quality environmental impacts that would preclude the selection of any of the controlsevaluated, and there are no remaininguseful-life issues for this source. A summary of the State’s NO X BART analyses for Unit 1 is provided in Table 33 below. Baseline NO X emissions are 5,744 tpy based on the unit heat input rate of 4,700 MMBtu/hr and 7,884 hours of operation per year.



### TABLE 

### 33—S UMMARY OF 

### WYODAK 

### U NIT 

### 1 NO X 

### BART A NALYSIS

Control Technology Control Efficiency (%) Emission Rate (lb/MMBtu)(30-day Rolling Average) Emission Reduction

(tpy) Annualized Costs Average Cost Effectiveness ($/ton) Visibility Improvement (Delta dv for the Maximum 98th Percentile Impact at Wind Cave National Park)

LNBs with OFA ........................................ 25.8 0.23 1,483 $1,306,203 $881 0.25 LNBs with OFA and SNCR ...................... 41.9 0.18 2,409 2,306,728 958 0.40 LNBs with OFA and SCR ........................ 77.4 0.07 4,447 18,910,781 4,252 0.72

Incremental cost effectiveness for the controls evaluated is as follows: LNBs with OFA and SNCR: $1,080/ton, and LNBs with OFA and SCR: $8,147/ton.

Based on its consideration of the five factors, the State determined LNBs with OFA was reasonable for NO X BART for Unit 1. The State determined other control technologies were not reasonable based on the high cost effectiveness and low visibility improvement. The State determined the NO X BART emission limits for Wyodak Unit 1 are 0.23 lb/MMBtu (30-day rolling average), 1,081 lb/MMBtu (30- day rolling average), and 4,735 tpy.

EPA’s Conclusions on Wyodak Unit 1 NO X BART Determination and FIP for NO X BART

EPA does not agree with the State’s conclusion that a limit of 0.23 lb/ MMBtu is reasonable for NO X BART for Wyodak Unit 1, which can be achieved with the installation and operation of LNBs with OFA. In particular, the cost effectiveness value for LNB with OFA plus SNCR at this unit is only $77/ton higher than LNBs with OFA, with an incremental cost of $1,080. The increase in cost effectiveness for LNBs with OFA plus SNCR affords a visibility improvement of 0.15 deciviews over LNBs plus OFA. LNBs with OFA plus SNCR would result in an additional reduction of around 900 tons of NO X . We find that it was unreasonable for the State not to determine that LNBs with OFA plus SNCR was NO X BART for Wyodak Unit 1. Thus, we are proposing to disapprove the State’s NO X BART determination for Wyodak Unit 1 and proposing a FIP for NO X BART as explained below.

Based on our examination of the State’s costs estimates, emission reductions, and the predicted visibility improvement, we propose to find that LNBs with OFA plus SNCR at an emission limit of 0.18 lb/MMBtu (30- day rolling average) is reasonable for NO X BART for Wyodak Unit 1. We are proposing that the FIP NO X BART emission limit for PacifiCorp Wyodak Unit 1 is 0.18 lb/MMBtu (30-day rolling average).

We have eliminated the single highest performing option from consideration— LNBs with OFA plus SCR—because the cost effectiveness value is significantly higher than LNBs with OFA and there is a comparatively small incremental visibility improvement over LNBs with OFA.

We propose that PacifiCorp meet our proposed emission limit at Wyodak Unit 1 no later than five years after EPA finalizes action on our proposed FIP. This is consistent with the requirements of 40 CFR 51.308(e)(iv). B. Disapproval of the State’s NO X Reasonable Progress Determinations and Federal Implementation Plan for NO X Reasonable Progress Determinations and Limits

We are proposing to disapprove the State’s reasonable progress determination for PacifiCorp Dave Johnston Unit 1 and Unit 2, and we are proposing a reasonable progress NO X FIP for these units, as explained below.As noted above, the State provided fourfactor analyses that adequately evaluated the required factors. Thus, in disapproving the State’s reasonable progress determination, we are basing our analysis on information provided by the State in its reasonable progress analysis, with the exception of visibility improvement modeling.

We concluded that it is also appropriate for this facility to consider a fifth factor for evaluating potential reasonable progress control options— the degree of visibility improvement that may reasonably be anticipated from the use of the reasonable progress controls. Our reasonable progress guidance contemplates that states (or EPA in lieu of a state) may be able to consider other relevant factors for reasonable progress sources (see EPA’s Guidance for Setting Reasonable Progress Goals under the Regional Haze Program, (‘‘Reasonable Progress Guidance’’), pp. 2–3, July 1, 2007). We find it appropriate, in certain circumstances, to consider visibility improvement when evaluating potential reasonable progress controls. Thus, EPA conducted visibility improvement modeling for Dave Johnston Units 1 and

2. 40
1. PacifiCorp Dave Johnston—Units 1 and 2 Background

PacifiCorp’s Dave Johnston Power Plant is comprised of four units burning pulverized subbituminous Powder River Basin coal. Both are nominal 106 MW pulverized coal-fired units. Unit 1 began operation in 1958 and Unit 2 in 1960.


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41 States must consider the four factors as listed above but can also take into account other relevant factors for the reasonable progress sources identified (see EPA’s Guidance for Setting Reasonable Progress Goals under the Regional Haze Program, (‘‘EPA’s Reasonable Progress Guidance’’), p. 2–3, July 1, 2007). Wyoming’s NO X Reasonable Progress Determination

Unit 1 and Unit 2 are currently uncontrolled for NO X emissions. The State determined that LNBs, LNBs with OFA, SNCR, and SCR were technically feasible for controlling NO X emissions. The State did not identify any technically infeasible control options. The State did not identify any energy or non-air quality environmental impacts that would preclude the selection of any of the controlsevaluated, and there are no remaininguseful-life issues for this source. A summary of the State’s NO X reasonable progress analyses for Unit 1 and Unit 2, along with our visibility modeling results, is provided in Tables 34 and 35 below. Baseline NO X emissions are 2,256 tpy for Unit 1 and 2,174 tpy for Unit 2 based on 2002 actual emissions. Wyoming did not provide controlled emission rates in their reasonable progress analysis. EPA calculated the controlled emission rates shown here.



### TABLE 

### 34—S UMMARY OF 

### D AVE 

### J OHNSTON 

### U NIT 

### 1 NO X 

### R EASONABLE 

### P ROGRESS 

### A NALYSIS

Control Technology Control Efficiency (%) Emission Rate (lb/MMBtu)(30-day Rolling Average) Emission Reduction

(tpy) Annualized Costs Average cost Effectiveness ($/ton) Visibility Improvement (Delta dv for the Maximum 98th Percentile Impact at Wind Cave National Park)

LNBs ........................................................ 51 0.28 1,150 $631,000 $528 0.37 LNBs with OFA ........................................ 65 0.20 1,466 962,000 632 0.49 SNCR ....................................................... 40 0.35 902 2,490,000 2,659 0.26 SCR .......................................................... 80 0.12 1,804 3,390,000 1,810 0.58



### TABLE 

### 35—S UMMARY OF 

### D AVE 

### J OHNSTON 

### U NIT 

### 2 NO X 

### R EASONABLE 

### P ROGRESS 

### A NALYSIS

Control Technology Control Efficiency (%) Emission Rate (lb/MMBtu)(30-day Rolling Average) Emission Reduction

(tpy) Annualized Costs Average Cost Effectiveness ($/ton) Visibility Improvement (Delta dv for the Maximum 98th Percentile Impact at Wind Cave National Park)

LNBs ........................................................ 51 0.28 1,108 $631,000 $538 0.38 LNBs with OFA ........................................ 65 0.20 1,413 962,000 644 0.49 SNCR ....................................................... 40 0.35 869 2,490,000 2,709 0.28 SCR .......................................................... 80 0.12 1,739 3,390,000 1,844 0.58

The State estimated that it would take nearly five and a half years for NO X reduction strategies to become effective. The State determined that roughly two years would be necessary for the State to develop the necessary regulations to implement the selected control measures. The State estimated that it would take up to a year for the source to secure the capital necessary to purchase emission control devices and approximately 18 months would be required for the company to design, fabricate, and install SCR or SNCR technology. Since there are two boilers being evaluated at Dave Johnston, the State determined an additional year may be required for staging the installation

process.

The State determined that no controls were reasonable for this planningperiod. The State cited that the fourfactor analysis was limited, in that no guidance was provided by EPA for identifying significant sources and EPA did not establish contribution to visibility impairment thresholds (a potential fifth factor for reasonable progress determinations). 41 The State further claims that the State cannot, per Wyoming Statute 35–11–202, establish emission control requirements except through State rule or regulation. Furthermore, the Wyoming statute requires the State to consider the character and degree of injury of the emissions involved. In this case, the State claims it would need to have visibility modeling that assessed the degree of injury caused by the emissions, which the State does not have. The State believes it has taken a strong and reasonable first step in identifying potential contributors to visibility impairment, and that the next step of creating an appropriate rule or regulation will be accomplished in the
next SIP revision. EPA’s Conclusions on Dave Johnston Units 1 and 2 NO X Reasonable Progress Determination and FIP for NO X Reasonable Progress Controls

We disagree with the State’s reasoning for not adopting reasonable progress controls for Dave Johnston Unit 1 and Unit 2. If the State determined that it needed to adopt a rule or perform modeling to adequately assess and, if warranted, require reasonable progress controls, the State should have completed these steps before it submitted its regional haze SIP. The RHR does not allow for commitments to potentially implement strategies at some later date that are identified under reasonable progress or for the State to take credit for such commitments.

In addition, the cost effectiveness values for LNBs with OFA at each unit are $632 and $644 per ton. These values are very reasonable and far less than some of the cost effectiveness values the State found reasonable in making its BART determinations. Given predicted NO X reductions of approximately 1,400 tpy per unit, visibility improvement of


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42 CAA Section 110(a)(2) states that SIPs ‘‘shall (A) include enforceable emission limitations and other control measures, means, or techniques (including economic incentives such as fees, marketable permits, and auctions of emissions rights), as well as schedules and timetables for compliance, as may be necessary or appropriate to meet the applicable requirements of this chapter; (C) include a program to provide for the enforcement of the measures described in subparagraph (A), and regulation of the modification and construction of any stationary source within the areas covered by the plan as necessary to assure that national ambient air quality standards are achieved, including a permit program as required in parts C and D of this subchapter; (F) require, as may be prescribed by the Administrator—(i) the installation, maintenance, and replacement of equipment, and the implementation of other necessary steps, by owners or operators of stationary sources to monitor emissions from such sources, (ii) periodic reports on the nature and amounts of emissions and emissions-related data from such sources, and (iii) correlation of such reports by the State agency with any emission limitations or standards established pursuant to this chapter, which reports shall be available at reasonable times for public inspection’’

43 Appendix V part 51 states in section 2.2 that complete SIPs contain: ‘‘(g) Evidence that the plan contains emission limitations, work practice standards and recordkeeping/reporting requirements, where necessary, to ensure emission levels’’; and ‘‘(h) Compliance/enforcement strategies, including how compliance will be determined in practice.’’ 44 On July 6, 2011, EPA sent an email to the State with detailed comments (that are summarized above) on the State’s monitoring, recordkeeping, and reporting requirements in Chapter 6.4, Section V of the SIP. The July 6, 2011 email from Laurel Dygowski, EPA Region 8, to Tina Anderson, State of Wyoming, is included in the Supporting and Related Materials section of the docket. approximately 0.5 deciviews per unit, and the fact that Wyoming’s reasonable progress goals will not meet the URP, we find that it was unreasonable for the State to reject these very inexpensive controls. Thus, we are proposing to disapprove the State’s NO X reasonable progress determination for Dave Johnston Unit 1 and Unit 2 and proposing a FIP for NO X reasonable progress controls as explained below.

Based on our examination of the State’s costs estimates, emission reductions, and the predicted visibility improvement, we propose to find that LNBs with OFA at an emission limit of 0.20 lb/MMBtu (30-day rolling average) is reasonable for NO X reasonable progress controls for Dave Johnston Units 1 and 2. We are proposing that the FIP NO X reasonable progress emission limit for PacifiCorp Dave Johnston Unit 1 and Unit 2 is 0.20 lb/MMBtu (30-day rolling average).

We have eliminated higher performing options from consideration—LNBs with OFA plus SCR—because the cost effectiveness values are significantly higher than LNBs with OFA and there is a comparatively small incremental visibility improvement over LNBs with OFA.

We propose that PacifiCorp meet our proposed emission limit at Dave Johnston Units 1 and 2 as expeditiously as possible, but no later than July 31, 2018. This is consistent with the requirement that the SIP cover an initial planning period that ends July 31, 2018. C. Reasonable Progress Goals

We are proposing to impose reasonable progress controls on Dave Johnston Units 1 and 2, as well as more stringent NO X BART controls on PacifiCorp Dave Johnston Unit 3, PacifiCorp Jim Bridger Units 1 and 2, PacifiCorp Wyodak Unit 1, and Basin Electric Laramie River Units 1, 2, and 3, than WRAP assumed in modeling Wyoming’s RPGs.

We could not re-run the WRAP modeling due to time and resource constraints, but anticipate that the additional controls would result in an increase in visibility improvement during the 20% worst days. As noted in our analyses, many of our proposed controls would result in significant incremental visibility benefits when modeled against natural background. We anticipate that this would translate into some measurable improvement if modeled on the 20% best days as well. While we expect our proposed controls will result in additional visibility improvement, we do not expect that these improvements will result in the State achieving the URP. For the reasons discussed in section VI.D.3, we find it reasonable for the State to not achieve the URP during this planning period. We expect the State to quantify the visibility improvement in its next regional haze SIP revision.

For purposes of this action, we are proposing RPGs that are consistent with the additional controls we are proposing. While we would prefer to quantify the RPGs, we note that the RPGs themselves are not enforceable values. The more critical elements for our FIP are the emissions limits we are proposing to impose, which will be enforceable. D. Federal Monitoring, Recordkeeping, and Reporting Requirements

The CAA requires that SIPs, including the regional haze SIP, contain elements sufficient to ensure emission limits are practically enforceable. 42 Other applicable regulatory provisions are contained in Appendix V to Part 51— Criteria for Determining the Completeness of Plan Submissions. 43 We are proposing to find that the State’s regional haze SIP does not contain adequate monitoring, recordkeeping and reporting requirements. Chapter 6.4, Section V of the SIP contains monitoring and reporting requirements that we find inadequate for numerous reasons, summarized as follows: (1) The State’s language includes references to WAQSR Chapters that EPA has not approved as part of the SIP and are thus not federally enforceable. These references should be to the appropriate sections in the CFR; (2) Definitions have not been included; (3) The State’s language allows for data substitution pursuant to 40 CFR part 75. The data substitution procedures of 40 CFR part 75 were never intended to apply to BART sources; (4) There are numerous language clarifications and rewordings needed; and (5) The State did not include appropriate recordkeeping language. 44

EPA is proposing to disapprove the State’s monitoring, recordkeeping, and reporting requirements in Chapter 6.4 of the SIP. EPA is proposing regulatory language as part of our FIP that specifies monitoring, recordkeeping, and reporting requirements for all BART and reasonable progress sources. For purposes of consistency, EPA is proposing to adopt language that is the same we have adopted for other states in Region 8. E. Federal Implementation Plan for the Long-Term Strategy

We are proposing regulatory language as part of our FIP that specifies NO X emission limits and compliance schedules for the following sources: PacifiCorp Dave Johnston Units 1–3, PacifiCorp Jim Bridger Units 1 and 2, PacifiCorp Wyodak Unit 1, and Basin Electric Laramie River Units 1, 2, and 3. We are also proposing monitoring, recordkeeping, and reporting requirements for all BART SIP and FIP sources and for Dave Johnston Units 1 and 2. We are proposing this regulatory language to fill the gap in the LTS that would be left by our proposed partial disapproval of the LTS. F. Federal Implementation Plan for Coordination of RAVI and Regional Haze Long-Term Strategy

In response to EPA’s RAVI rules, Wyoming adopted WAQSR Chapter 9, Section 2. EPA approved WAQSR Chapter 9, Section 2 as part of the SIP on July 28, 2004 (69 FR 44965). As discussed above, the State is required to coordinate the review of its RAVI and regional haze LTS and conduct the reviews together. WAQSR Chapter 9, Section 2(f) requires the State to review its RAVI LTS every three years, which does not coordinate with the five-year review for the State’s regional haze LTS.


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Thus, we are proposing to disapprove the State’s SIP because it does not meet the requirements of 40 CFR 51.306(c). We are proposing a FIP in which EPA commits to coordinating the State’s RAVI LTS review with the regional haze LTS review. Thus, EPA is committing to provide a review of the State’s RAVI LTS every five years in coordination with the State’s regional haze LTS review. EPA is proposing that our review of the State’s RAVI LTS will follow those items as indicated by 40 CFR 51.306(c).
VIII. EPA’s Proposed Action

EPA is proposing to partially approve and partially disapprove a regional haze SIP revision submitted by the State of Wyoming on January 12, 2011. Specifically, we are proposing to disapprove the following:

• The State’s NO X BART determinations for PacifiCorp Dave Johnston Unit 3, PacifiCorp Jim Bridger Units 1 and 2, PacifiCorp Wyodak Unit 1, and Basin Electric Laramie River Units 1, 2, and, 3.

• The State’s NO X reasonable progress determination for PacifiCorp Dave Johnston Units 1 and 2.

• Wyoming’s Reasonable Progress Goals (RPGs)

• The State’s monitoring and recordkeeping requirements in Chapter 6.4 of the SIP.

• Portions of the State’s long-term strategy (LTS) that rely on or reflect other aspects of the regional haze SIP we are proposing to disapprove.

• The State’s SIP because it does not contain the necessary provisions to meet the requirements for the coordination of the review of the reasonably attributable visibility impairment (RAVI) and the regional haze long-term strategy (LTS).

We are proposing to approve the remaining aspects of the State’s January 12, 2011, SIP submittal. We are also seeking comment on two alternative proposals related to the State’s NO X BART determination for PacifiCorp Jim Bridger Units 1 and 2.

We are proposing the promulgation of a FIP to address the deficiencies in the Wyoming regional haze SIP that we have identified in this proposal. The proposed FIP includes the following elements:

• NO X BART determinations and limits for PacifiCorp Dave Johnston Unit 3, PacifiCorp Jim Bridger Units 1 and 2, PacifiCorp Wyodak Unit 1, and Basin Electric Laramie River Units 1, 2, and 3.

• NO X reasonable progress determination and limits for PacifiCorp Dave Johnston Units 1 and 2. • RPGs consistent with the SIP limits proposed for approval and the proposed FIP limits.

• Monitoring, record-keeping, and reporting requirements applicable to all BART and reasonable progress sources for which there is a SIP or FIP emissions limit.

• LTS elements pertaining to emission limits and compliance schedules for the proposed BART and reasonable progress FIP limits.

• Provisions to ensure the coordination of the RAVI and regional haze LTS.
IX. Statutory and Executive Order Reviews A. Executive Order 12866: Regulatory Planning and Review and Executive Order 13563: Improving Regulation and Regulatory Review

This action is not a ‘‘significant regulatory action’’ under the terms of Executive Order 12866 (58 FR 51735, October 4, 1993) and is therefore not subject to review under Executive Orders 12866 and 13563 (76 FR 3821, January 21, 2011). As discussed in section C below, the proposed FIP applies to only four facilities. It is therefore not a rule of general applicability.
B. Paperwork Reduction Act

This action does not impose an information collection burden under the provisions of the Paperwork Reduction Act, 44 U.S.C. 3501 et seq. Burden is defined at 5 CFR 1320.3(b). Because the proposed FIP applies to just four facilities, the Paperwork Reduction Act does not apply. See 5 CFR 1320(c).
C. Regulatory Flexibility Act

The Regulatory Flexibility Act (RFA) generally requires an agency to prepare a regulatory flexibility analysis of any rule subject to notice and comment rulemaking requirements under the Administrative Procedure Act or any other statute unless the agency certifies that the rule will not have a significant economic impact on a substantial number of small entities. Small entities include small businesses, small organizations, and small governmental jurisdictions.

For purposes of assessing the impacts of today’s proposed rule on small entities, small entity is defined as: (1) A small business as defined by the Small Business Administration’s (SBA) regulations at 13 CFR 121.201; (2) a small governmental jurisdiction that is a government of a city, county, town, school district or special district with a population of less than 50,000; and (3) a small organization that is any not-forprofit enterprise which is independently owned and operated and is not dominant in its field.

After considering the economic impacts of today’s proposed rule on small entities, I certify that this action will not have a significant economic impact on a substantial number of small entities. The Regional Haze FIP that EPA is proposing for purposes of the regional haze program consists of imposing federal controls to meet the BART requirement for NO X emissions on specific units at four sources in Wyoming, and imposing controls to meet the reasonable progress requirement for NO X emissions at one additional source in Wyoming. The net result of this FIP action is that EPA is proposing direct emission controls on selected units at only four sources. The sources in question are each large electric generating plants that are not owned by small entities, and therefore are not small entities. The proposed partial approval of the SIP, if finalized, merely approves state law as meeting Federal requirements and imposes no additional requirements beyond those imposed by state law. See Mid-Tex Electric Cooperative, Inc. v. FERC, 773 F.2d 327 (D.C. Cir. 1985).

We continue to be interested in the potential impacts of the proposed rule on small entities and welcome comments on issues related to such impacts. D. Unfunded Mandates Reform Act (UMRA)

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


### 33059 Federal Register / Vol. 77, No. 107 / Monday, June 4, 2012 / Proposed Rules

EPA to adopt an alternative other than the least costly, most cost-effective, or least burdensome alternative if the Administrator publishes with the final rule an explanation why that alternative was not adopted. Before EPA establishes any regulatory requirements that may significantly or uniquely affect small governments, including Tribal governments, it must have developed under section 203 of UMRA a small government agency plan. The plan must provide for notifying potentially affected small governments, enabling officials of affected small governments to have meaningful and timely input in the development of EPA regulatory proposals with significant federal intergovernmental mandates, and informing, educating, and advising small governments on compliance with the regulatory requirements.

Under Title II of UMRA, EPA has determined that this proposed rule does not contain a federal mandate that may result in expenditures that exceed the inflation-adjusted UMRA threshold of $100 million by State, local, or Tribal governments or the private sector in any one year. In addition, this proposed rule does not contain a significant federal intergovernmental mandate as described by section 203 of UMRA nor does it contain any regulatory requirements that might significantly or uniquely affect small governments.

E. Executive Order 13132: Federalism

Federalism (64 FR 43255, August 10, 1999) revokes and replaces Executive Orders 12612 (Federalism) and 12875 (Enhancing the Intergovernmental Partnership). Executive Order 13132 requires EPA to develop an accountable process to ensure ‘‘meaningful and timely input by State and local officials in the development of regulatory policies that have federalism implications.’’ ‘‘Policies that have federalism implications’’ is defined in the Executive Order to include regulations that have ‘‘substantial direct effects on the States, on the relationship between the national government and the States, or on the distribution of power and responsibilities among the various levels of government.’’ Under Executive Order 13132, EPA may not issue a regulation that has federalism implications, that imposes substantial direct compliance costs, and that is not required by statute, unless the federal government provides the funds necessary to pay the direct compliance costs incurred by state and local governments, or EPA consults with state and local officials early in the process of developing the proposed regulation. EPA also may not issue a regulation that has federalism implications and that preempts state law unless the Agency consults with state and local officials early in the process of developing the proposed regulation.

This rule will not have substantial direct effects on the states, on the relationship between the national government and the states, or on the distribution of power and responsibilities among the various levels of government, as specified in Executive Order 13132, because it merely addresses the State not fully meeting its obligation to prohibit emissions from interfering with other states measures to protect visibility established in the CAA. Thus, Executive Order 13132 does not apply to this action. In the spirit of Executive Order 13132, and consistent with EPA policy to promote communications between EPA and state and local governments, EPA specifically solicits comment on this proposed rule from state and local officials.

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

Executive Order 13175, entitled Consultation and Coordination With Indian Tribal Governments (65 FR 67249, November 9, 2000), requires EPA to develop an accountable process to ensure ‘‘meaningful and timely input by tribal officials in the development of regulatory policies that have tribal implications.’’ This proposed rule does not have tribal implications, as specified in Executive Order 13175. It will not have substantial direct effects on tribal governments. Thus, Executive Order 13175 does not apply to this rule.

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

EPA interprets EO 13045 (62 FR 19885, April 23, 1997) as applying only to those regulatory actions that concern health or safety risks, such that the analysis required under section 5–501 of the EO has the potential to influence the regulation. This action is not subject to EO 13045 because it implements specific standards established by Congress in statutes. However, to the extent this proposed rule will limit emissions of NO x, SO 2, and PM, the rule will have a beneficial effect on children’s health by reducing air pollution. H. Executive Order 13211: Actions Concerning Regulations That Significantly Affect Energy Supply, Distribution, or Use

This action is not subject to Executive Order 13211 (66 FR 28355 (May 22, 2001)), because it is not a significant regulatory action under Executive Order

12866. I. National Technology Transfer and Advancement Act

Section 12(d) of the National Technology Transfer and Advancement Act of 1995 (‘‘NTTAA’’), Public Law No. 104–113, 12(d) (15 U.S.C. 272 note) directs EPA to use voluntary consensus standards in its regulatory activities unless to do so would be inconsistent with applicable law or otherwise impractical. Voluntary consensus standards are technical standards ( e.g., materials specifications, test methods, sampling procedures, and business practices) that are developed or adopted by voluntary consensus standards bodies. NTTAA directs EPA to provide Congress, through OMB, explanations when the Agency decides not to use available and applicable voluntary consensus standards.

This proposed rulemaking does not involve technical standards. Therefore, EPA is not considering the use of any voluntary consensus standards.

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

Executive Order 12898 (59 FR 7629, February 16, 1994), establishes federal executive policy on environmental justice. Its main provision directs federal agencies, to the greatest extent practicable and permitted by law, to make environmental justice part of their mission by identifying and addressing, as appropriate, disproportionately high and adverse human health or environmental effects of their programs, policies, and activities on minority populations and low-income populations in the United States.

We have determined that this proposed action, if finalized, will not have disproportionately high and adverse human health or environmental effects on minority or low-income populations because it increases the level of environmental protection for all affected populations without having any disproportionately high and adverse human health or environmental effects on any population, including any minority or low-income population. This proposed rule limits emissions of NO X from four facilities in Wyoming.


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The partial approval of the SIP, if finalized, merely approves state law as meeting Federal requirements and imposes no additional requirements beyond those imposed by state law.
K. Congressional Review Act

The Congressional Review Act, 5 U.S.C. 801 et seq., as added by the Small Business Regulatory Enforcement Fairness Act of 1996, does not apply because this action is not a ‘‘major rule’’ as defined by 5 U.S.C. 804(2).
List of Subjects in 40 CFR Part 52

Environmental protection, Air pollution control, Intergovernmental relations, Nitrogen dioxide, Particulate matter, Reporting and recordkeeping requirements, Sulfur oxides, Volatile organic compounds.

Dated: May 15, 2012. James B. Martin, Regional Administrator, Region 8.

40 CFR part 52 is proposed to be amended as follows:

**PART 52—[AMENDED]**

1. The authority citation for part 52 continues to read as follows:

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

**Subpart ZZ—Wyoming**

2. Add section 52.2636 to read as follows:

**§ 52.2636 Federal implementation plan for regional haze.** 

(a) Applicability. This section applies to each owner and operator of the following emissions units in the State of Wyoming for which EPA proposes to approve the State’s BART determination:

FMC Westvaco Trona Plant Units NS– 1A and NS–1B (PM and NO X); TATA Chemicals Partners (previously General Chemical) Boilers C and D (PM and NO X);

Basin Electric Power Cooperative Laramie River Station Units 1, 2, and 3 (PM);

Pacificorp Dave Johnston Power Plant Unit 3 (PM);

Pacificorp Dave Johnston Power Plant Unit 4 (PM and NO X);

Pacificorp Jim Bridger Power Plant Units 1 and 2 (PM);

Pacificorp Jim Bridger Power Plant Units 3 and 4 (PM and NO X);

Pacificorp Naughton Power Plant Units 1, 2, and 3 (PM and NO X); and

Pacificorp Wyodak Power Plant Unit 1 (PM).

This section also applies to each owner and operator of the following emissions units in the State of Wyoming for which EPA proposes to disapprove the State’s BART determination and issue a NO X BART Federal Implementation Plan:

Basin Electric Power Cooperative Laramie River Station Units 1, 2, and 3;

Pacificorp Dave Johnston Power Plant Unit 3;

Pacificorp Jim Bridger Power Plant Units 1 and 2; and

Pacificorp Wyodak Power Plant Unit

1. This section also applies to each owner and operator of the following emissions units in the State of Wyoming for which EPA proposes to disapprove the State’s reasonable progress determinations and issue a reasonable progress determination NO X Federal Implementation Plan: Pacificorp Dave Johnston Power Plant Units 1 and 2.

(b) Definitions. Terms not defined below shall have the meaning given them in the Clean Air Act or EPA’s regulations implementing the Clean Air Act. For purposes of this section:

(1) BART means Best Available Retrofit Technology. (2) BART unit means any unit subject to a Regional Haze emission limit in Table 1 and Table 2 of this section.

(3) CAM means Compliance Assurance Monitoring as required by 40 CFR part 64.

(4) Continuous emission monitoring system or CEMS means the equipment required by this section to sample, analyze, measure, and provide, by means of readings recorded at least once every 15 minutes (using an automated data acquisition and handling system (DAHS)), a permanent record of NO X emissions, diluent, or stack gas volumetric flow rate.

(5) FIP means Federal Implementation Plan.

(6) Lb/hr means pounds per hour. (7) Lb/MMBtu means pounds per million British thermal units of heat input to the fuel-burning unit.

(8) NO X means nitrogen oxides. (9) Operating day means a 24-hour period between 12 midnight and the following midnight during which any fuel is combusted at any time in the BART or RP unit. It is not necessary for fuel to be combusted for the entire 24- hour period.

(10) The owner/operator means any person who owns or who operates, controls, or supervises a unit identified in paragraph (a) of this section.

(11) PM means filterable total particulate matter.

(12) RP unit means any Reasonable Progress unit subject to a Regional Haze emission limit in Table 3 of this section.

(13) Unit means any of the units identified in paragraph (a) of this section.

(c) Emissions limitations. (1) The owners/operators of emissions units subject to this section shall not emit, or cause to be emitted, PM or NO X in excess of the following limitations:



### TABLE 

### 1—E MISSION 

### L IMITS FOR 

### BART U NITS FOR 

### W HICH 

### EPA P ROPOSES TO 

### A PPROVE THE 

### STATE 

### ’ S 

### BART D ETERMINATION

Source Name/BART Unit PM Emission Limits NO X Emission Limits

lb/MMBtu lb/hr Tons per year lb/MMBtu lb/hr Tons per year

FMC Westvaco Trona Plant/Unit NS–1A .................... 0 .05 45 197 0.35 284 1244 FMC Westvaco Trona Plant/Unit NS–1B .................... 0 .05 45 197 0.35 284 1244 TATA Chemicals Partners (General Chemical) Green

River Trona Plant/Boiler C ....................................... 0 .09 50 219 0.28 149.5 654 .9 TATA Chemicals Partners (General Chemical) Green

River Trona Plant/Boiler D ....................................... 0 .09 80 350 .4 0.28 246.4 1,079 .2Basin Electric Power Cooperative Laramie River Station/Unit 1 ................................................................. 0 .03 193 844 N/A N/A N/ABasin Electric Power Cooperative Laramie River Station/Unit 2 ................................................................. 0 .03 193 844 N/A N/A N/ABasin Electric Power Cooperative Laramie River Station/Unit 3 ................................................................. 0 .03 198 867 N/A N/A N/A Pacificorp Dave Johnston Power Plant/Unit 3 ............. 0 .015 42 .1 184 N/A N/A N/A Pacificorp Dave Johnston Power Plant/Unit 4 ............. 0 .015 61 .5 269 0.15 615 2,694


### 33061 Federal Register / Vol. 77, No. 107 / Monday, June 4, 2012 / Proposed Rules

TABLE 

### 1—E MISSION 

### L IMITS FOR 

### BART U NITS FOR 

### W HICH 

### EPA P ROPOSES TO 

### A PPROVE THE 

### STATE 

### ’ S 

### BART D ETERMINATION

### —Continued

Source Name/BART Unit PM Emission Limits NO X Emission Limits

lb/MMBtu lb/hr Tons per year lb/MMBtu lb/hr Tons per year

Pacificorp Jim Bridger Power Plant/Unit 1 .................. 0 .03 180 788 N/A N/A N/A Pacificorp Jim Bridger Power Plant/Unit 2 .................. 0 .03 180 788 N/A N/A N/A Pacificorp Jim Bridger Power Plant/Unit 3 .................. 0 .03 180 788 0.07 N/A N/A Pacificorp Jim Bridger Power Plant/Unit 4 .................. 0 .03 180 788 0.07 N/A N/A Pacificorp Naughton Power Plant/Unit 1 ..................... 0 .04 74 324 0.26 481 2,107 Pacificorp Naughton Power Plant/Unit 2 ..................... 0 .04 96 421 0.26 624 2,733 Pacificorp Naughton Power Plant/Unit 3 ..................... 0 .015 56 243 0.07 259 1,134 Pacificorp Wyodak Power Plant/Unit 1 ........................ 0 .015 71 308 .8 N/A N/A N/A



### TABLE 

### 2—E MISSION 

### L IMITS FOR 

### BART

U NITS FOR 

### W HICH 

### EPA P ROPOSES 

### TO 

### D ISAPPROVE THE 

### STATE 

### ’ S 

### BART D ETERMINATION AND 

### I MPLEMENT A 

### FIP

Source Name/BART Unit NO X Emission Limit (lb/MMBtu)

Basin Electric Power Cooperative Laramie River Station/Unit 1 .......................... 0.12Basin Electric Power Cooperative Laramie River Station/Unit 2 .......................... 0.12Basin Electric Power Cooperative Laramie River Station/Unit 3 .......................... 0.12 Pacificorp Dave Johnston

Power Plant/Unit 3 ............ 0.19 Pacificorp Jim Bridger Power

Plant/Unit 1 ....................... 0.07 Pacificorp Jim Bridger Power

Plant/Unit 2 ....................... 0.07 Pacificorp Wyodak Power

Plant/Unit 1 ....................... 0.18



### TABLE 

### 3—E MISSION 

### L IMITS FOR 

### RP U NITS FOR 

### W HICH 

### EPA P ROPOSES 

### TO 

### D ISAPPROVE THE 

### STATE 

### ’ S 

### RP D ETERMINATION AND 

### I MPLEMENT A 

### FIP

Source Name/RP Unit NOX Emission Limit (lb/MMBtu)

Pacificorp Dave Johnston

Power Plant/Unit 1 ............ 0.20 Pacificorp Dave Johnston

Power Plant/Unit 2 ............ 0.20

(2) These emission limitations shall apply at all times, including startups, shutdowns, emergencies, and malfunctions.

(d) Compliance date. The owners and operators of the BART and RP sources subject to this section shall comply with the emissions limitations and other requirements of this section within five years of the effective date of this rule

(e) Compliance determinations for NO X. (1) For all BART and RP units other than Trona Plant units:

(i) CEMS. At all times after the compliance date specified in paragraph (d) of this section, the owner/operator of each unit shall maintain, calibrate, and operate a CEMS, in full compliance with the requirements found at 40 CFR part 75, to accurately measure NO X , diluent, and stack gas volumetric flow rate from each unit. The CEMS shall be used to determine compliance with the emission limitations in paragraph (c) of this section for each unit.

(ii) Method. ( a ) For any hour in which fuel is combusted in a unit, the owner/operator of each unit shall calculate the hourly average NO X concentration in lb/ MMBtu and lb/hr at the CEMS in accordance with the requirements of 40 CFR part 75. At the end of each operating day, the owner/operator shall calculate and record a new 30-day rolling average emission rate in lb/ MMBtu and lb/hr from the arithmetic average of all valid hourly emission rates from the CEMS for the current operating day and the previous 29 successive operating days.

( b) An hourly average NO X emission rate in lb/MMBtu or lb/hr is valid only if the minimum number of data points, as specified in 40 CFR part 75, is acquired by both the pollutant concentration monitor (NO X) and the diluent monitor (O 2 or CO 2).

( c) Compliance with tons-per-year emission limits shall be calculated on a rolling 12-month basis. At the end of each calendar month, the owner/ operator shall calculate and record a new 12-month rolling average emission rate from the arithmetic average of all valid hourly emission rates from the CEMS for the current month and the previous 11 months and the report the result in tons.

( d) Data reported to meet the requirements of this section shall not include data substituted using the missing data substitution procedures of subpart D of 40 CFR part 75, nor shall the data have been bias adjusted according to the procedures of 40 CFR part 75.

(2) For all Trona Plant BART units: (i) CEMS. At all times after the compliance date specified in paragraph (d) of this section, the owner/operator of each unit shall maintain, calibrate, and operate a CEMS, in full compliance with the requirements found at 40 CFR part 60, to accurately measure NO X , diluent, and stack gas volumetric flow rate from each unit, including the CEMS quality assurance requirements in appendix F of 40 CFR part 60. The CEMS shall be used to determine compliance with the emission limitations in paragraph (c) of this section for each unit.

(ii) Method. ( a ) For any hour in which fuel is combusted in a unit, the owner/operator of each unit shall calculate the hourly average NO X concentration in lb/ MMBtu and lb/hr at the CEMS in accordance with the requirements of 40 CFR part 60. At the end of each operating day, the owner/operator shall calculate and record a new 30-day rolling average emission rate in lb/ MMBtu and lb/hr from the arithmetic average of all valid hourly emission rates from the CEMS for the current operating day and the previous 29 successive operating days.

( b) An hourly average NO X emission rate in lb/MMBtu or lb/hr is valid only if the minimum number of data points, as specified in 40 CFR part 60, is acquired by both the pollutant concentration monitor (NO X) and the diluent monitor (O 2 or CO 2).

( c) Compliance with tons-per-year emission limits shall be calculated on a rolling 12-month basis. At the end of each calendar month, the owner/ operator shall calculate and record a new 12-month rolling average emission rate from the arithmetic average of all valid hourly emission rates from the CEMS for the current month and the previous 11 months and report results in tons.

(f) Compliance determinations for particulate matter.


### 33062 Federal Register / Vol. 77, No. 107 / Monday, June 4, 2012 / Proposed Rules

Compliance with the particulate matter emission limit for each BART and RP unit shall be determined from annual performance stack tests. Within 60 days of the compliance deadline specified in section (d), and on at least an annual basis thereafter, the owner/ operator of each unit shall conduct a stack test on each unit to measure particulate emissions using EPA Method 5, 5B, 5D, or 17, as appropriate, in 40 CFR part 60, Appendix A. A test shall consist of three runs, with each run at least 120 minutes in duration and each run collecting a minimum sample of 60 dry standard cubic feet. Results shall be reported in lb/MMBtu and lb/hr. In addition to annual stack tests, the owner/operator shall monitor particulate emissions for compliance with the BART emission limits in accordance with the applicable Compliance Assurance Monitoring (CAM) plan developed and approved by the State in accordance with 40 CFR part 64.

(g) Recordkeeping. The owner/ operator shall maintain the following records for at least five years:

(1) All CEMS data, including the date, place, and time of sampling or measurement; parameters sampled or measured; and results.

(2) Records of quality assurance and quality control activities for emissions measuring systems including, but not limited to, any records required by 40 CFR part 75. Or, for Trona Plant units, records of quality assurance and quality control activities for emissions measuring systems including, but not limited to appendix F of 40 CFR part 60.

(3) Records of all major maintenance activities conducted on emission units, air pollution control equipment, and CEMS.

(4) Any other CEMS records required by 40 CFR part 75. Or, for Trona Plant units, any other CEMs records required by 40 CFR part 60.

(5) Records of all particulate stack test results.

(6) All data collected pursuant to the CAM plan.

(h) Reporting. All reports under this section shall be submitted to the Director, Office of Enforcement, Compliance and Environmental Justice, U.S. Environmental Protection Agency, Region 8, Mail Code 8ENF–AT, 1595 Wynkoop Street, Denver, Colorado

80202–1129.

(1) The owner/operator of each unit shall submit quarterly excess emissions reports for NO X BART and RP units no later than the 30th day following the end of each calendar quarter. Excess emissions means emissions that exceed the emissions limits specified in paragraph (c) of this section. The reports shall include the magnitude, date(s), and duration of each period of excess emissions, specific identification of each period of excess emissions that occurs during startups, shutdowns, and malfunctions of the unit, the nature and cause of any malfunction (if known), and the corrective action taken or preventative measures adopted. The owner/operator shall also submit reports of any exceedances of tons-per-year emission limits.

(2) The owner/operator of each unit shall submit quarterly CEMS performance reports, to include dates and duration of each period during which the CEMS was inoperative (except for zero and span adjustments and calibration checks), reason(s) why the CEMS was inoperative and steps taken to prevent recurrence, and any CEMS repairs or adjustments. The owner/operator of each unit shall also submit results of any CEMS performance tests required by 40 CFR part 75. Or, for Trona Plant units, the owner/operator of each unit shall also submit results of any CEMs performance test required appendix F of 40 CFR part 60 (Relative Accuracy Test Audits, Relative Accuracy Audits, and Cylinder Gas Audits).

(3) When no excess emissions have occurred or the CEMS has not been inoperative, repaired, or adjusted during the reporting period, such information shall be stated in the quarterly reports required by sections (h)(1) and (2) above.

(4) The owner/operator of each unit shall submit results of any particulate matter stack tests conducted for demonstrating compliance with the particulate matter BART limits in section (c) above, within 60 calendar days after completion of the test.

(5) The owner/operator of each unit shall submit semi-annual reports of any excursions under the approved CAM plan in accordance with the schedule specified in the source’s title V permit.

(i) Notifications. (1) The owner/operator shall submit notification of commencement of construction of any equipment which is being constructed to comply with the NO X emission limits in paragraph (c) of this section.

(2) The owner/operator shall submit semi-annual progress reports on construction of any such equipment.

(3) The owner/operator shall submit notification of initial startup of any such equipment.

(j) Equipment operation. At all times, the owner/operator shall maintain each unit, including associated air pollution control equipment, in a manner consistent with good air pollution control practices for minimizing emissions.

(k) Credible Evidence. Nothing in this section shall preclude the use, including the exclusive use, of any credible evidence or information, relevant to whether a source would have been in compliance with requirements of this section if the appropriate performance or compliance test procedures or method had been performed.

3. Add section 52.2637 to read as follows:

**§ 52.2637 Federal implementation plan for reasonable attributable visibility impairment**  **long-term strategy.**

As required by 40 CFR 41.306(c), EPA will ensure that the review of the State’s reasonably attributable visibility impairment long-term strategy iscoordinated with the regional haze longterm strategy under 40 CFR 51.308(g). EPA’s review will be in accordance with the requirements of 40 CFR 51.306(c).

[FR Doc. 2012–12923 Filed 6–1–12; 8:45 am]

**BILLING CODE 6560–50–P**