§ 52.173 Visibility protection.  


Latest version.
  • (a) Regional haze. The regional haze State Implementation Plan (SIP) revisions submitted on September 23, 2008 and August 3, 2010, and supplemented on September 27, 2011 are partially approved and partially disapproved.

    (1) The identification of sources that are eligible for Best Available Retrofit Technology (BART) is approved, with the exception of the 6A Boiler at the Georgia-Pacific Crossett Mill, which is BART eligible.

    (2) The identification of sources subject to BART is approved, with the exception of the 6A and 9A Boilers at the Georgia-Pacific Crossett Mill, which are both subject to BART.

    (3) The following BART determinations are disapproved:

    (i) The sulfur dioxide (SO2), nitrogen dioxide (NOX), and particulate matter (PM) BART determinations for the Arkansas Electric Cooperative Corporation Bailey Plant Unit 1 and the AECC McClellan Plant Unit 1;

    (ii) The SO2 and NOX BART determinations for the American Electric Power Flint Creek Plant Boiler No. 1;

    (iii) The NOX BART determination for the natural gas firing scenario and the SO2, NOX, and PM BART determinations for the fuel oil firing scenario for the Entergy Lake Catherine Plant Unit 4;

    (iv) The SO2 and NOX BART determinations for both the bituminous and sub-bituminous coal firing scenarios for the Entergy White Bluff Plant Units 1 and 2;

    (v) The BART determination for the Entergy White Bluff Plant Auxiliary Boiler;

    (vi) The SO2 and NOX BART determinations for the Domtar Ashdown Mill Power Boiler No. 1; and

    (vii) The SO2, NOX and PM BART determinations for the Domtar Ashdown Mill Power Boiler No. 2.

    (4) The Arkansas Regional Haze Rule, (APCEC Regulation 19, Chapter 15), is partially approved and partially disapproved such that:

    (i) The requirement under Reg. 19.104(B) for BART installation and operation as expeditiously as practicable, but no later than 5 years after EPA approval of the Arkansas Regional Haze State Implementation Plan is partially approved and partially disapproved, such that the partial approval is for the BART determinations we are approving and the partial disapproval is for the BART determinations we are disapproving;

    (ii) The requirement under Reg. 19.1504(B) for BART installation and operation no later than 6 years after the effective date of the State regulation is disapproved;

    (iii) Reg. 19.1505 (A)(1) and (2), (B), (C), (D)(1) and (2), (E), (F)(1) and (2), (G)(1) and (2), (H), (I)(1) and (2), (J)(1) and (2), (K), (L), (M)(1), and (N) are disapproved;

    (iv) the Reg. 19.1506 requirement to demonstrate compliance with the BART limits listed in Reg. 19.1505 (A)(1) and (2), (B), (C), (D)(1) and (2), (E), (F)(1) and (2), (G)(1) and (2), (H), (I)(1) and (2), (J)(1) and (2), (K), (L), (M)(1), and (N) is disapproved; and

    (v) The remaining portions are approved.

    (5) The regional haze long term strategy under 40 CFR 51.308(d)(3) is partially approved and partially disapproved.

    (6) The reasonable progress goals are disapproved.

    (b) Interstate Transport. The portion of the SIP pertaining to adequate provisions to prohibit emissions from interfering with measures required in another state to protect visibility, submitted on March 28, 2008, and supplemented on September 27, 2011, is partially approved and partially disapproved.

    (1) The Arkansas Regional Haze Rule, (APCEC Regulation 19, Chapter 15), is partially approved and partially disapproved such that:

    (i) The requirement under Reg. 19.104(B) for BART installation and operation as expeditiously as practicable, but no later than 5 years after EPA approval of the Arkansas Regional Haze State Implementation Plan is partially approved and partially disapproved, such that the partial approval is for the BART determinations we are approving and the partial disapproval is for the BART determinations we are disapproving;

    (ii) The requirement under Reg. 19.1504(B) for BART installation and operation no later than 6 years after the effective date of the State regulation is disapproved;

    (iii) Reg. 19.1505 (A)(1) and (2), (B), (C), (D)(1) and (2), (E), (F)(1) and (2), (G)(1) and (2), (H), (I)(1) and (2), (J)(1) and (2), (K), (L), (M)(1), and (N) are disapproved;

    (iv) The Reg. 19.1506 requirement to demonstrate compliance with the BART limits listed in Reg. 19.1505 (A)(1) and (2), (B), (C), (D)(1) and (2), (E), (F)(1) and (2), (G)(1) and (2), (H), (I)(1) and (2), (J)(1) and (2), (K), (L), (M)(1), and (N) is disapproved; and

    (v) The remaining portions are approved.

    (c) Federal implementation plan for regional haze. Requirements for AECC Carl E. Bailey Unit 1; AECC John L. McClellan Unit 1; AEP Flint Creek Unit 1; Entergy White Bluff Units 1, 2, and Auxiliary Boiler; Entergy Lake Catherine Unit 4; Domtar Ashdown Paper Mill Power Boilers No. 1 and 2; and Entergy Independence Units 1 and 2 affecting visibility.

    (1) Applicability. The provisions of this section shall apply to each owner or operator, or successive owners or operators, of the sources designated as: AECC Carl E. Bailey Unit 1; AECC John L. McClellan Unit 1; AEP Flint Creek Unit 1; Entergy White Bluff Units 1, 2, and Auxiliary Boiler; Entergy Lake Catherine Unit 4; Domtar Ashdown Paper Mill Power Boilers No. 1 and 2; and Entergy Independence Units 1 and 2.

    (2) Definitions. All terms used in this part but not defined herein shall have the meaning given them in the Clean Air Act and in parts 51 and 60 of this title. For the purposes of this section:

    24-hour period means the period of time between 12:01 a.m. and 12 midnight.

    Air pollution control equipment includes selective catalytic control units, baghouses, particulate or gaseous scrubbers, and any other apparatus utilized to control emissions of regulated air contaminants which would be emitted to the atmosphere.

    Boiler-operating-day for electric generating units listed under paragraph (c)(1) of this section means any 24-hour period between 12 midnight and the following midnight during which any fuel is combusted at any time at the steam generating unit, unless otherwise specified. For power boilers listed under paragraph (c)(1) of this section, we define boiler-operating-day as a 24-hr period between 6 a.m. and 6 a.m. the following day during which any fuel is fed into and/or combusted at any time in the power boiler.

    Daily average means the arithmetic average of the hourly values measured in a 24-hour period.

    Heat input means heat derived from combustion of fuel in a unit and does not include the heat input from preheated combustion air, recirculated flue gases, or exhaust gases from other sources. Heat input shall be calculated in accordance with 40 CFR part 75.

    Owner or Operator means any person who owns, leases, operates, controls, or supervises any of the units or power boilers listed under paragraph (c)(1) of this section.

    Regional Administrator means the Regional Administrator of EPA Region 6 or his/her authorized representative.

    Unit means one of the natural gas, fuel oil, or coal fired boilers covered under paragraph (c) of this section.

    (3) Emissions limitations for AECC Bailey Unit 1 and AECC McClellan Unit 1. The individual SO2 and PM emission limits for each unit are as listed in the table in this paragraph (c)(3).

    (4) Compliance dates for AECC Bailey Unit 1 and AECC McClellan Unit 1. The owner or operator of each unit must comply with the SO2 and PM requirements listed in paragraph (c)(3) of this section by October 27, 2021. As of October 27, 2016, the owner or operator of each unit shall not purchase fuel for combustion at the unit that does not meet the sulfur content limit in paragraph (c)(3) of this section. The owner or operator of each unit must comply with the requirement in paragraph (c)(3) of this section to burn only fuel with a sulfur content limit of 0.5% by weight by October 27, 2021.

    (5) Compliance determination and reporting and recordkeeping requirements for AECC Bailey Unit 1 and AECC McClellan Unit 1 for SO4 and PM. To determine compliance with the SO2 and PM requirements listed in paragraph (c)(3) of this section, the owner or operator shall sample and analyze each shipment of fuel to determine the sulfur content by weight, except for natural gas shipments. A “shipment” is considered delivery of the entire amount of each order of fuel purchased. Fuel sampling and analysis may be performed by the owner or operator of an affected unit, an outside laboratory, or a fuel supplier. All records pertaining to the sampling of each shipment of fuel as described in this paragraph (c)(5), including the results of the sulfur content analysis, must be maintained by the owner or operator and made available upon request to EPA and ADEQ representatives.

    (6) Emissions limitations for AEP Flint Creek Unit 1 and Entergy White Bluff Units 1 and 2. The individual SO2 emission limits for each unit are as listed in the table in this paragraph (c)(6), as specified in pounds per million British thermal units (lb/MMBtu). The SO2 emission limits of 0.06 lb/MMBtu are on a rolling 30 boiler-operating-day averaging period.

    (7) Compliance dates for AEP Flint Creek Unit 1 and Entergy White Bluff Units 1 and 2. The owner or operator of AEP Flint Creek Unit 1 must comply with the SO2 emission limit listed in paragraph (c)(6) of this section by April 27, 2018. The owner or operator of White Bluff Units 1 and 2 must comply with the SO2 emission limit listed in paragraph (c)(6) of this section by October 27, 2021.

    (8) Compliance determination and reporting and recordkeeping requirements for AEP Flint Creek Unit 1 and Entergy White Bluff Units 1 and 2. (i) For purposes of determining compliance with the SO2 emission limit listed in paragraph (c)(6) of this section for AEP Flint Creek Unit 1 and with the SO2 emission limits listed in paragraph (c)(6) of this section for White Bluff Units 1 and 2, the emissions for each boiler-operating-day for each unit shall be determined by summing the hourly emissions measured in pounds of SO2. For each unit, heat input for each boiler-operating-day shall be determined by adding together all hourly heat inputs, in millions of BTU. Each boiler-operating-day of the 30-day rolling average for a unit shall be determined by adding together the pounds of SO2 from that day and the preceding 29 boiler-operating-days and dividing the total pounds of SO2 by the sum of the heat input during the same 30 boiler-operating-day period. The result shall be the 30 boiler-operating-day rolling average in terms of lb/MMBtu emissions of SO2. If a valid SO2 pounds per hour or heat input is not available for any hour for a unit, that heat input and SO2 pounds per hour shall not be used in the calculation of the 30 boiler-operating-day rolling average for SO2. For each day, records of the total SO2 emitted that day by each emission unit and the sum of the hourly heat inputs for that day must be maintained by the owner or operator and made available upon request to EPA and ADEQ representatives. Records of the 30 boiler-operating-day rolling average for SO2 for each unit as described in this paragraph (c)(8)(i) must be maintained by the owner or operator for each boiler-operating-day and made available upon request to EPA and ADEQ representatives.

    (ii) The owner or operator shall continue to maintain and operate a CEMS for SO2 on the units listed in paragraph (c)(6) of this section in accordance with 40 CFR 60.8 and 60.13(e), (f), and (h), and appendix B of 40 CFR part 60. The owner or operator shall comply with the quality assurance procedures for CEMS found in 40 CFR part 75. Compliance with the emission limits for SO2 shall be determined by using data from a CEMS.

    (iii) Continuous emissions monitoring shall apply during all periods of operation of the units listed in paragraph (c)(6) of this section, including periods of startup, shutdown, and malfunction, except for CEMS breakdowns, repairs, calibration checks, and zero and span adjustments. Continuous monitoring systems for measuring SO2 and diluent gas shall complete a minimum of one cycle of operation (sampling, analyzing, and data recording) for each successive 15-minute period. Hourly averages shall be computed using at least one data point in each fifteen-minute quadrant of an hour. Notwithstanding this requirement, an hourly average may be computed from at least two data points separated by a minimum of 15 minutes (where the unit operates for more than one quadrant in an hour) if data are unavailable as a result of performance of calibration, quality assurance, preventive maintenance activities, or backups of data from data acquisition and handling system, and recertification events. When valid SO2 pounds per hour emission data are not obtained because of continuous monitoring system breakdowns, repairs, calibration checks, or zero and span adjustments, emission data must be obtained by using other monitoring systems approved by the EPA to provide emission data for a minimum of 18 hours in each 24-hour period and at least 22 out of 30 successive boiler operating days.

    (9) Emissions limitations for Entergy White Bluff Auxiliary Boiler. The individual SO2 and PM emission limits for the unit are as listed in the table in this paragraph (c)(9) in pounds per hour (lb/hr).

    (10) Compliance dates for Entergy White Bluff Auxiliary Boiler. The owner or operator of the unit must comply with the SO2 and PM emission limits listed in paragraph (c)(9) of this section by October 27, 2016.

    (11) Compliance determination and reporting and recordkeeping requirements for Entergy White Bluff Auxiliary Boiler. For purposes of demonstrating compliance with the emission limits listed in paragraph (c)(9) of this section, records of fuel oil analysis must be maintained by the owner or operator and made available upon request to EPA and ADEQ representatives.

    (12) Emissions limitations for Entergy Lake Catherine Unit 4. The unit must not burn fuel oil until BART determinations are promulgated for the unit for SO2 and PM for the fuel oil firing scenario through a FIP and/or through EPA action upon and approval of revised BART determinations submitted by the State as a SIP revision.

    (13) Emissions Limitations for Domtar Ashdown Paper Mill Power Boiler No. 1. The SO2 emission limit for the boiler is as listed in the following table in pounds per day (lb/day) as averaged over a rolling 30 boiler-operating-day period. The NOX emission limit for the boiler is as listed in the following table in pounds per hour (lb/hr).

    (14) Compliance dates for Domtar Ashdown Mill Power Boiler No. 1. The owner or operator of the boiler must comply with the SO2 and NOX emission limits listed in paragraph (c)(13) of this section by November 28, 2016.

    (15) Compliance determination and reporting and recordkeeping requirements for Domtar Ashdown Paper Mill Power Boiler No. 1. (i)(A) SO2 emissions resulting from combustion of fuel oil shall be determined by assuming that the SO2 content of the fuel delivered to the fuel inlet of the combustion chamber is equal to the SO2 being emitted at the stack. The owner or operator must maintain records of the sulfur content by weight of each fuel oil shipment, where a “shipment” is considered delivery of the entire amount of each order of fuel purchased. Fuel sampling and analysis may be performed by the owner or operator, an outside laboratory, or a fuel supplier. All records pertaining to the sampling of each shipment of fuel oil, including the results of the sulfur content analysis, must be maintained by the owner or operator and made available upon request to EPA and ADEQ representatives. SO2 emissions resulting from combustion of bark shall be determined by using the following site-specific curve equation, which accounts for the SO2 scrubbing capabilities of bark combustion:

    Y= 0.4005 * X − 0.2645

    (B) The owner or operator must confirm the site-specific curve equation through stack testing. By October 27, 2017, the owner or operator must provide a report to EPA showing confirmation of the site-specific curve equation accuracy. Records of the quantity of fuel input to the boiler for each fuel type for each day must be compiled no later than 15 days after the end of the month and must be maintained by the owner or operator and made available upon request to EPA and ADEQ representatives. Each boiler-operating-day of the 30-day rolling average for the boiler must be determined by adding together the pounds of SO2 from that boiler-operating-day and the preceding 29 boiler-operating-days and dividing the total pounds of SO2 by the sum of the total number of boiler operating days (i.e., 30). The result shall be the 30 boiler-operating-day rolling average in terms of lb/day emissions of SO2. Records of the total SO2 emitted for each day must be compiled no later than 15 days after the end of the month and must be maintained by the owner or operator and made available upon request to EPA and ADEQ representatives. Records of the 30 boiler-operating-day rolling averages for SO2 as described in this paragraph (c)(15)(i) must be maintained by the owner or operator for each boiler-operating-day and made available upon request to EPA and ADEQ representatives.

    (ii) If the air permit is revised such that Power Boiler No. 1 is permitted to burn only pipeline quality natural gas, this is sufficient to demonstrate that the boiler is complying with the SO2 emission limit under paragraph (c)(13) of this section. The compliance determination requirements and the reporting and recordkeeping requirements under paragraph (c)(15)(i) of this section would not apply and confirmation of the accuracy of the site-specific curve equation under paragraph (c)(15)(i)(B) of this section through stack testing would not be required so long as Power Boiler No. 1 is only permitted to burn pipeline quality natural gas.

    (iii) To demonstrate compliance with the NOX emission limit under paragraph (c)(13) of this section, the owner or operator shall conduct stack testing using EPA Reference Method 7E, found at 40 CFR part 60, appendix A, once every 5 years, beginning October 27, 2017. Records and reports pertaining to the stack testing must be maintained by the owner or operator and made available upon request to EPA and ADEQ representatives.

    (iv) If the air permit is revised such that Power Boiler No. 1 is permitted to burn only pipeline quality natural gas, the owner or operator may demonstrate compliance with the NOX emission limit under paragraph (c)(13) of this section by calculating NOX emissions using fuel usage records and the applicable NOX emission factor under AP-42, Compilation of Air Pollutant Emission Factors, section 1.4, Table 1.4-1. Records of the quantity of natural gas input to the boiler for each day must be compiled no later than 15 days after the end of the month and must be maintained by the owner or operator and made available upon request to EPA and ADEQ representatives. Records of the calculation of NOX emissions for each day must be compiled no later than 15 days after the end of the month and must be maintained by the owner or operator and made available upon request to EPA and ADEQ representatives. Each boiler-operating-day of the 30-day rolling average for the boiler must be determined by adding together the pounds of NOX from that day and the preceding 29 boiler-operating-days and dividing the total pounds of NOX by the sum of the total number of hours during the same 30 boiler-operating-day period. The result shall be the 30 boiler-operating-day rolling average in terms of lb/hr emissions of NOX. Records of the 30 boiler-operating-day rolling average for NOX must be maintained by the owner or operator for each boiler-operating-day and made available upon request to EPA and ADEQ representatives. Under these circumstances, the compliance determination requirements and the reporting and recordkeeping requirements under paragraph (c)(15)(iii) of this section would not apply.

    (16) SO2 and NOX Emissions Limitations for Domtar Ashdown Paper Mill Power Boiler No.2. The individual SO2 and NOX emission limits for the boiler are as listed in the following table in pounds per hour (lb/hr) as averaged over a rolling 30 boiler-operating-day period.

    (17) SO2 and NOX Compliance dates for Domtar Ashdown Mill Power Boiler No. 2. The owner or operator of the boiler must comply with the SO2 and NOX emission limits listed in paragraph (c)(16) of this section by October 27, 2021.

    (18) SO2 and NOX Compliance determination and reporting and recordkeeping requirements for Domtar Ashdown Mill Power Boiler No. 2. (i) NOX and SO2 emissions for each day shall be determined by summing the hourly emissions measured in pounds of NOX or pounds of SO2. Each boiler-operating-day of the 30-day rolling average for the boiler shall be determined by adding together the pounds of NOX or SO2 from that day and the preceding 29 boiler-operating-days and dividing the total pounds of NOX or SO2 by the sum of the total number of hours during the same 30 boiler-operating-day period. The result shall be the 30 boiler-operating-day rolling average in terms of lb/hr emissions of NOX or SO2. If a valid NOX pounds per hour or SO2 pounds per hour is not available for any hour for the boiler, that NOX pounds per hour shall not be used in the calculation of the 30 boiler-operating-day rolling average for NOX. For each day, records of the total SO2 and NOX emitted for that day by the boiler must be maintained by the owner or operator and made available upon request to EPA and ADEQ representatives. Records of the 30 boiler-operating-day rolling average for SO2 and NOX for the boiler as described in this paragraph (c)(18)(i) must be maintained by the owner or operator for each boiler-operating-day and made available upon request to EPA and ADEQ representatives.

    (ii) The owner or operator shall continue to maintain and operate a CEMS for SO2 and NOX on the boiler listed in paragraph (c)(16) of this section in accordance with 40 CFR 60.8 and 60.13(e), (f), and (h), and appendix B of 40 CFR part 60. The owner or operator shall comply with the quality assurance procedures for CEMS found in 40 CFR part 60. Compliance with the emission limits for SO2 and NOX shall be determined by using data from a CEMS.

    (iii) Continuous emissions monitoring shall apply during all periods of operation of the boiler listed in paragraph (c)(16) of this section, including periods of startup, shutdown, and malfunction, except for CEMS breakdowns, repairs, calibration checks, and zero and span adjustments. Continuous monitoring systems for measuring SO2 and NOX and diluent gas shall complete a minimum of one cycle of operation (sampling, analyzing, and data recording) for each successive 15-minute period. Hourly averages shall be computed using at least one data point in each fifteen-minute quadrant of an hour. Notwithstanding this requirement, an hourly average may be computed from at least two data points separated by a minimum of 15 minutes (where the unit operates for more than one quadrant in an hour) if data are unavailable as a result of performance of calibration, quality assurance, preventive maintenance activities, or backups of data from data acquisition and handling system, and recertification events. When valid SO2 or NOX pounds per hour emission data are not obtained because of continuous monitoring system breakdowns, repairs, calibration checks, or zero and span adjustments, emission data must be obtained by using other monitoring systems approved by the EPA to provide emission data for a minimum of 18 hours in each 24-hour period and at least 22 out of 30 successive boiler operating days.

    (iv) If the air permit is revised such that Power Boiler No. 2 is permitted to burn only pipeline quality natural gas, this is sufficient to demonstrate that the boiler is complying with the SO2 emission limit under paragraph (c)(16) of this section. Under these circumstances, the compliance determination requirements under paragraphs (c)(18)(i) through (iii) of this section would not apply to the SO2 emission limit listed in paragraph (c)(16) of this section.

    (v) If the air permit is revised such that Power Boiler No. 2 is permitted to burn only pipeline quality natural gas and the operation of the CEMS is not required under other applicable requirements, the owner or operator may demonstrate compliance with the NOX emission limit under paragraph (c)(16) of this section by calculating NOX emissions using fuel usage records and the applicable NOX emission factor under AP-42, Compilation of Air Pollutant Emission Factors, section 1.4, Table 1.4-1. Records of the quantity of natural gas input to the boiler for each day must be compiled no later than 15 days after the end of the month and must be maintained by the owner or operator and made available upon request to EPA and ADEQ representatives. Records of the calculation of NOX emissions for each day must be compiled no later than 15 days after the end of the month and must be maintained and made available upon request to EPA and ADEQ representatives. Each boiler-operating-day of the 30-day rolling average for the boiler must be determined by adding together the pounds of NOX from that day and the preceding 29 boiler-operating-days and dividing the total pounds of NOX by the sum of the total number of hours during the same 30 boiler-operating-day period. The result shall be the 30 boiler-operating-day rolling average in terms of lb/hr emissions of NOX. Records of the 30 boiler-operating-day rolling average for NOX must be maintained by the owner or operator for each boiler-operating-day and made available upon request to EPA and ADEQ representatives. Under these circumstances, the compliance determination requirements under paragraphs (c)(18)(i) through (iii) of this section would not apply to the NOX emission limit.

    (19) PM BART Requirements for Domtar Ashdown Paper Mill Power Boiler No.2. The owner or operator must rely on the applicable PM standard required under 40 CFR part 63, subpart DDDDD—National Emission Standards for Hazardous Air Pollutants for Major Sources: Industrial, Commercial, and Institutional Boilers and Process Heaters, as revised, to satisfy the PM BART requirement. Compliance with the applicable PM standard under 40 CFR part 63 subpart DDDDD, as revised, shall demonstrate compliance with the PM BART requirement.

    (20) PM compliance dates for Domtar Ashdown Mill Power Boiler No. 2. The owner or operator of the boiler must comply with the PM BART requirement listed in paragraph (c)(19) of this section by November 28, 2016.

    (21) Alternative PM Compliance Determination for Domtar Ashdown Paper Mill Power Boiler No.2. If the air permit is revised such that Power Boiler No. 2 is permitted to burn only pipeline quality natural gas, this is sufficient to demonstrate that the boiler is complying with the PM BART requirement under paragraph (c)(19) of this section.

    (22) Emissions limitations for Entergy Independence Units 1 and 2. The individual emission limits for each unit are as listed in the table in this paragraph (c)(22) in pounds per million British thermal units (lb/MMBtu). The SO2 emission limits listed in the table as lb/MMBtu are on a rolling 30 boiler-operating-day averaging period.

    (23) Compliance dates for Entergy Independence Units 1 and 2. The owner or operator of each unit must comply with the SO2 emission limits in paragraph (c)(22) of this section by October 27, 2021.

    (24) Compliance determination and reporting and recordkeeping requirements for Entergy Independence Units 1 and 2. (i) For purposes of determining compliance with the SO2 emissions limit listed in paragraph (c)(22) of this section for each unit, the SO2 emissions for each boiler-operating-day shall be determined by summing the hourly emissions measured in pounds of SO2. For each unit, heat input for each boiler-operating-day shall be determined by adding together all hourly heat inputs, in millions of BTU. Each boiler-operating-day of the thirty-day rolling average for a unit shall be determined by adding together the pounds of SO2 from that day and the preceding 29 boiler-operating-days and dividing the total pounds of SO2 by the sum of the heat input during the same 30 boiler-operating-day period. The result shall be the 30 boiler-operating-day rolling average in terms of lb/MMBtu emissions of SO2. If a valid SO2 pounds per hour or heat input is not available for any hour for a unit, that heat input and SO2 pounds per hour shall not be used in the calculation of the applicable 30 boiler-operating-days rolling average. For each day, records of the total SO2 emitted that day by each emission unit and the sum of the hourly heat inputs for that day must be maintained by the owner or operator and made available upon request to EPA and ADEQ representatives. Records of the 30 boiler-operating-day rolling average for each unit as described in this paragraph (c)(24)(i) must be maintained by the owner or operator for each boiler-operating-day and made available upon request to EPA and ADEQ representatives.

    (ii) The owner or operator shall continue to maintain and operate a CEMS for SO2 on the units listed in paragraph (c)(22) in accordance with 40 CFR 60.8 and 60.13(e), (f), and (h), and appendix B of 40 CFR part 60. The owner or operator shall comply with the quality assurance procedures for CEMS found in 40 CFR part 75. Compliance with the emission limits for SO2 shall be determined by using data from a CEMS.

    (iii) Continuous emissions monitoring shall apply during all periods of operation of the units listed in paragraph (c)(22) of this section, including periods of startup, shutdown, and malfunction, except for CEMS breakdowns, repairs, calibration checks, and zero and span adjustments. Continuous monitoring systems for measuring SO2 and diluent gas shall complete a minimum of one cycle of operation (sampling, analyzing, and data recording) for each successive 15-minute period. Hourly averages shall be computed using at least one data point in each fifteen-minute quadrant of an hour. Notwithstanding this requirement, an hourly average may be computed from at least two data points separated by a minimum of 15 minutes (where the unit operates for more than one quadrant in an hour) if data are unavailable as a result of performance of calibration, quality assurance, preventive maintenance activities, or backups of data from data acquisition and handling system, and recertification events. When valid SO2 pounds per hour emission data are not obtained because of continuous monitoring system breakdowns, repairs, calibration checks, or zero and span adjustments, emission data must be obtained by using other monitoring systems approved by the EPA to provide emission data for a minimum of 18 hours in each 24-hour period and at least 22 out of 30 successive boiler operating days.

    (25) Reporting and recordkeeping requirements. Unless otherwise stated all requests, reports, submittals, notifications, and other communications to the Regional Administrator required under paragraph (c) of this section shall be submitted, unless instructed otherwise, to the Director, Multimedia Planning and Permitting Division, U.S. Environmental Protection Agency, Region 6, to the attention of Mail Code: 6PD, at 1445 Ross Avenue, Suite 1200, Dallas, Texas 75202-2733. For each unit subject to the emissions limitation under paragraph (c) of this section, the owner or operator shall comply with the following requirements, unless otherwise specified:

    (i) For each emissions limit under paragraph (c) of this section where compliance shall be determined by using data from a CEMS, comply with the notification, reporting, and recordkeeping requirements for CEMS compliance monitoring in 40 CFR 60.7(c) and (d).

    (ii) [Reserved]

    (26) Equipment operations. At all times, including periods of startup, shutdown, and malfunction, the owner or operator shall, to the extent practicable, maintain and operate the unit including associated air pollution control equipment in a manner consistent with good air pollution control practices for minimizing emissions. Determination of whether acceptable operating and maintenance procedures are being used will be based on information available to the Regional Administrator which may include, but is not limited to, monitoring results, review of operating and maintenance procedures, and inspection of the unit.

    (27) Enforcement. (i) Notwithstanding any other provision in this implementation plan, any credible evidence or information relevant as to whether the unit would have been in compliance with applicable requirements if the appropriate performance or compliance test had been performed, can be used to establish whether or not the owner or operator has violated or is in violation of any standard or applicable emission limit in the plan.

    (ii) Emissions in excess of the level of the applicable emission limit or requirement that occur due to a malfunction shall constitute a violation of the applicable emission limit.

    (d) Measures Addressing Partial Disapproval of Portion of Interstate Visibility Transport SIP for the 1997 8-hour ozone and PM2.5 NAAQS. The deficiencies identified in EPA's partial disapproval of the portion of the SIP pertaining to adequate provisions to prohibit emissions in Arkansas from interfering with measures required in another state to protect visibility, submitted on March 28, 2008, and supplemented on September 27, 2011 are satisfied by §52.173.

    (e) Measures addressing best available retrofit technology (BART) for electric generating unit (EGU) emissions of nitrogen oxides (NOX). The BART requirements for EGU NOX emissions are satisfied by §52.184 and the Arkansas Regional Haze NOX SIP Revision approved February 12, 2018, 83 FR 5927.

    (f) Other measures addressing reasonable progress. The reasonable progress requirements for NOX emissions are satisfied by the Arkansas Regional Haze NOX SIP Revision approved February 12, 2018.

    [77 FR 14676, Mar. 12, 2012, as amended at 81 FR 66415, Sept. 27, 2016; 82 FR 18995, Apr. 25, 2017; 83 FR 5917, 5940, Feb. 12, 2018]

[77 FR 14676, Mar. 12, 2012, as amended at 81 FR 66415, Sept. 27, 2016; 82 FR 18995, Apr. 25, 2017; 83 FR 5917, 5940, Feb. 12, 2018