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  <FDSYS>
    <CFRTITLE>40</CFRTITLE>
    <CFRTITLETEXT>Protection of Environment</CFRTITLETEXT>
    <VOL>2</VOL>
    <DATE>2006-07-01</DATE>
    <ORIGINALDATE>2006-07-01</ORIGINALDATE>
    <COVERONLY>false</COVERONLY>
    <TITLE>ENVIRONMENTAL PROTECTION AGENCY (CONTINUED)</TITLE>
    <GRANULENUM>I</GRANULENUM>
    <HEADING>CHAPTER I</HEADING>
    <ANCESTORS>
      <PARENT HEADING="Title 40" SEQ="0">Protection of Environment</PARENT>
    </ANCESTORS>
  </FDSYS>
  <CHAPTER>
    <TOC>
      <TOCHD>
        <PRTPAGE P="3"/>
        <HD SOURCE="HED">CHAPTER I—ENVIRONMENTAL PROTECTION AGENCY (CONTINUED)</HD>
      </TOCHD>
      <SUBCHAP>
        <HD SOURCE="HED">SUBCHAPTER C—AIR PROGRAMS</HD>
      </SUBCHAP>
      <PTHD>Part</PTHD>
      <PGHD>Page</PGHD>
      <CHAPTI>
        <PT>50</PT>
        <SUBJECT>National primary and secondary ambient air quality standards</SUBJECT>
        <PG>5</PG>
        <PT>51</PT>
        <SUBJECT>Requirements for preparation, adoption, and submittal of implementation plans</SUBJECT>
        <PG>121</PG>
      </CHAPTI>
    </TOC>
    <SUBCHAP TYPE="N">
      <PRTPAGE P="5"/>
      <HD SOURCE="HED">SUBCHAPTER C—AIR PROGRAMS</HD>
      <PART>
        <EAR>Pt. 50</EAR>
        <HD SOURCE="HED">PART 50—NATIONAL PRIMARY AND SECONDARY AMBIENT AIR QUALITY STANDARDS</HD>
        <CONTENTS>
          <SECHD>Sec.</SECHD>
          <SECTNO>50.1</SECTNO>
          <SUBJECT>Definitions.</SUBJECT>
          <SECTNO>50.2</SECTNO>
          <SUBJECT>Scope.</SUBJECT>
          <SECTNO>50.3</SECTNO>
          <SUBJECT>Reference conditions.</SUBJECT>
          <SECTNO>50.4</SECTNO>
          <SUBJECT>National primary ambient air quality standards for sulfur oxides (sulfur dioxide).</SUBJECT>
          <SECTNO>50.5</SECTNO>
          <SUBJECT>National secondary ambient air quality standard for sulfur oxides (sulfur dioxide).</SUBJECT>
          <SECTNO>50.6</SECTNO>

          <SUBJECT>National primary and secondary ambient air quality standards for PM<E T="52">10</E>.</SUBJECT>
          <SECTNO>50.7</SECTNO>

          <SUBJECT>National primary and secondary ambient air quality standards for PM<E T="52">2.5</E>.</SUBJECT>
          <SECTNO>50.8</SECTNO>
          <SUBJECT>National primary ambient air quality standards for carbon monoxide.</SUBJECT>
          <SECTNO>50.9</SECTNO>
          <SUBJECT>National 1-hour primary and secondary ambient air quality standards for ozone.</SUBJECT>
          <SECTNO>50.10</SECTNO>
          <SUBJECT>National 8-hour primary and secondary ambient air quality standards for ozone.</SUBJECT>
          <SECTNO>50.11</SECTNO>
          <SUBJECT>National primary and secondary ambient air quality standards for nitrogen dioxide.</SUBJECT>
          <SECTNO>50.12</SECTNO>
          <SUBJECT>National primary and secondary ambient air quality standards for lead.</SUBJECT>
          <APP>Appendix A to Part 50—Reference Method for the Determination of Sulfur Dioxide in the Atmosphere (Pararosaniline Method)</APP>
          <APP>Appendix B to Part 50—Reference Method for the Determination of Suspended Particulate Matter in the Atmosphere (High-Volume Method)</APP>
          <APP>Appendix C to Part 50—Measurement Principle and Calibration Procedure for the Measurement of Carbon Monoxide in the Atmosphere (Non-Dispersive Infrared Photometry)</APP>
          <APP>Appendix D to Part 50—Measurement Principle and Calibration Procedure for the Measurement of Ozone in the Atmosphere</APP>
          <APP>Appendix E to Part 50 [Reserved]</APP>
          <APP>Appendix F to Part 50—Measurement Principle and Calibration Procedure for the Measurement of Nitrogen Dioxide in the Atmosphere (Gas Phase Chemiluminescence)</APP>
          <APP>Appendix G to Part 50—Reference Method for the Determination of Lead in Suspended Particulate Matter Collected From Ambient Air</APP>
          <APP>Appendix H to Part 50—Interpretation of the 1-Hour Primary and Secondary National Ambient Air Quality Standards for Ozone</APP>
          <APP>Appendix I to Part 50—Interpretation of the 8-Hour Primary and Secondary National Ambient Air Quality Standards for Ozone</APP>

          <APP>Appendix J to Part 50—Reference Method for the Determination of Particulate Matter as PM<E T="52">10</E> in the Atmosphere</APP>
          <APP>Appendix K to Part 50—Interpretation of the National Ambient Air Quality Standards for Particulate Matter</APP>

          <APP>Appendix L to Part 50—Reference Method for the Determination of Fine Particulate Matter as PM<E T="52">2.5</E> in the Atmosphere</APP>
          <APP>Appendix M to Part 50 [Reserved]</APP>
          <APP>Appendix N to Part 50—Interpretation of the National Ambient Air Quality Standards for Particulate Matter</APP>
        </CONTENTS>
        <AUTH>
          <HD SOURCE="HED">Authority:</HD>
          <P>42 U.S.C. 7401, <E T="03">et seq.</E>
          </P>
        </AUTH>
        <SOURCE>
          <HD SOURCE="HED">Source:</HD>
          <P>36 FR 22384, Nov. 25, 1971, unless otherwise noted.</P>
        </SOURCE>
        <SECTION>
          <SECTNO>§ 50.1</SECTNO>
          <SUBJECT>Definitions.</SUBJECT>
          <P>(a) As used in this part, all terms not defined herein shall have the meaning given them by the Act.</P>
          <P>(b) <E T="03">Act</E> means the Clean Air Act, as amended (42 U.S.C. 1857-18571, as amended by Pub. L. 91-604).</P>
          <P>(c) <E T="03">Agency</E> means the Environmental Protection Agency.</P>
          <P>(d) <E T="03">Administrator</E> means the Administrator of the Environmental Protection Agency.</P>
          <P>(e) <E T="03">Ambient air</E> means that portion of the atmosphere, external to buildings, to which the general public has access.</P>
          <P>(f) <E T="03">Reference method</E> means a method of sampling and analyzing the ambient air for an air pollutant that is specified as a reference method in an appendix to this part, or a method that has been designated as a reference method in accordance with part 53 of this chapter; it does not include a method for which a reference method designation has been cancelled in accordance with § 53.11 or § 53.16 of this chapter.</P>
          <P>(g) <E T="03">Equivalent method</E> means a method of sampling and analyzing the ambient air for an air pollutant that has been designated as an equivalent method in accordance with part 53 of this chapter; it does not include a method for which an equivalent method designation has been cancelled in accordance with § 53.11 or § 53.16 of this chapter.<PRTPAGE P="6"/>
          </P>
          <P>(h) <E T="03">Traceable</E> means that a local standard has been compared and certified either directly or via not more than one intermediate standard, to a primary standard such as a National Bureau of Standards Standard Reference Material (NBS SRM), or a USEPA/NBS-approved Certified Reference Material (CRM).</P>
          <P>(i) <E T="03">Indian country</E> is as defined in 18 U.S.C. 1151.</P>
          <CITA>[36 FR 22384, Nov. 25, 1971, as amended at 41 FR 11253, Mar. 17, 1976; 48 FR 2529, Jan. 20, 1983; 63 FR 7274, Feb. 12, 1998]</CITA>
        </SECTION>
        <SECTION>
          <SECTNO>§ 50.2</SECTNO>
          <SUBJECT>Scope.</SUBJECT>
          <P>(a) National primary and secondary ambient air quality standards under section 109 of the Act are set forth in this part.</P>
          <P>(b) National primary ambient air quality standards define levels of air quality which the Administrator judges are necessary, with an adequate margin of safety, to protect the public health. National secondary ambient air quality standards define levels of air quality which the Administrator judges necessary to protect the public welfare from any known or anticipated adverse effects of a pollutant. Such standards are subject to revision, and additional primary and secondary standards may be promulgated as the Administrator deems necessary to protect the public health and welfare.</P>
          <P>(c) The promulgation of national primary and secondary ambient air quality standards shall not be considered in any manner to allow significant deterioration of existing air quality in any portion of any State or Indian country.</P>
          <P>(d) The proposal, promulgation, or revision of national primary and secondary ambient air quality standards shall not prohibit any State or Indian country from establishing ambient air quality standards for that State or area under a tribal CAA program or any portion thereof which are more stringent than the national standards.</P>
          <CITA>[36 FR 22384, Nov. 25, 1971, as amended at 63 FR 7274, Feb. 12, 1998]</CITA>
        </SECTION>
        <SECTION>
          <SECTNO>§ 50.3</SECTNO>
          <SUBJECT>Reference conditions.</SUBJECT>

          <P>All measurements of air quality that are expressed as mass per unit volume (<E T="03">e.g.</E>, micrograms per cubic meter) other than for the particulate matter (PM<E T="52">2.5</E>) standards contained in § 50.7 shall be corrected to a reference temperature of 25 °C and a reference pressure of 760 millimeters of mercury (1,013.2 millibars). Measurements of PM<E T="52">2.5</E> for purposes of comparison to the standards contained in § 50.7 shall be reported based on actual ambient air volume measured at the actual ambient temperature and pressure at the monitoring site during the measurement period.</P>
          <CITA>[69 FR 45595, July 30, 2004]</CITA>
        </SECTION>
        <SECTION>
          <SECTNO>§ 50.4</SECTNO>
          <SUBJECT>National primary ambient air quality standards for sulfur oxides (sulfur dioxide).</SUBJECT>
          <P>(a) The level of the annual standard is 0.030 parts per million (ppm), not to be exceeded in a calendar year. The annual arithmetic mean shall be rounded to three decimal places (fractional parts equal to or greater than 0.0005 ppm shall be rounded up).</P>
          <P>(b) The level of the 24-hour standard is 0.14 parts per million (ppm), not to be exceeded more than once per calendar year. The 24-hour averages shall be determined from successive nonoverlapping 24-hour blocks starting at midnight each calendar day and shall be rounded to two decimal places (fractional parts equal to or greater than 0.005 ppm shall be rounded up).</P>
          <P>(c) Sulfur oxides shall be measured in the ambient air as sulfur dioxide by the reference method described in appendix A to this part or by an equivalent method designated in accordance with part 53 of this chapter.</P>

          <P>(d) To demonstrate attainment, the annual arithmetic mean and the second-highest 24-hour averages must be based upon hourly data that are at least 75 percent complete in each calendar quarter. A 24-hour block average shall be considered valid if at least 75 percent of the hourly averages for the 24-hour period are available. In the event that only 18, 19, 20, 21, 22, or 23 hourly averages are available, the 24-hour block average shall be computed as the sum of the available hourly averages using 18, 19, etc. as the divisor. If fewer than 18 hourly averages are available, but the 24-hour average would exceed the level of the standard when zeros are substituted for the <PRTPAGE P="7"/>missing values, subject to the rounding rule of paragraph (b) of this section, then this shall be considered a valid 24-hour average. In this case, the 24-hour block average shall be computed as the sum of the available hourly averages divided by 24.</P>
          <CITA>[61 FR 25579, May 22, 1996]</CITA>
        </SECTION>
        <SECTION>
          <SECTNO>§ 50.5</SECTNO>
          <SUBJECT>National secondary ambient air quality standard for sulfur oxides (sulfur dioxide).</SUBJECT>
          <P>(a) The level of the 3-hour standard is 0.5 parts per million (ppm), not to be exceeded more than once per calendar year. The 3-hour averages shall be determined from successive nonoverlapping 3-hour blocks starting at midnight each calendar day and shall be rounded to 1 decimal place (fractional parts equal to or greater than 0.05 ppm shall be rounded up).</P>
          <P>(b) Sulfur oxides shall be measured in the ambient air as sulfur dioxide by the reference method described in appendix A of this part or by an equivalent method designated in accordance with part 53 of this chapter.</P>
          <P>(c) To demonstrate attainment, the second-highest 3-hour average must be based upon hourly data that are at least 75 percent complete in each calendar quarter. A 3-hour block average shall be considered valid only if all three hourly averages for the 3-hour period are available. If only one or two hourly averages are available, but the 3-hour average would exceed the level of the standard when zeros are substituted for the missing values, subject to the rounding rule of paragraph (a) of this section, then this shall be considered a valid 3-hour average. In all cases, the 3-hour block average shall be computed as the sum of the hourly averages divided by 3.</P>
          <CITA>[61 FR 25580, May 22, 1996]</CITA>
        </SECTION>
        <SECTION>
          <SECTNO>§ 50.6</SECTNO>
          <SUBJECT>National primary and secondary ambient air quality standards for PM10.</SUBJECT>
          <P>(a) The level of the national primary and secondary 24-hour ambient air quality standards for particulate matter is 150 micrograms per cubic meter (µg/m<SU>3</SU>), 24-hour average concentration. The standards are attained when the expected number of days per calendar year with a 24-hour average concentration above 150 µg/m<SU>3</SU>, as determined in accordance with appendix K to this part, is equal to or less than one.</P>
          <P>(b) The level of the national primary and secondary annual standards for particulate matter is 50 micrograms per cubic meter (µg/m<SU>3</SU>), annual arithmetic mean. The standards are attained when the expected annual arithmetic mean concentration, as determined in accordance with appendix K to this part, is less than or equal to 50 µg/m<SU>3</SU>.</P>

          <P>(c) For the purpose of determining attainment of the primary and secondary standards, particulate matter shall be measured in the ambient air as PM<E T="52">10</E> (particles with an aerodynamic diameter less than or equal to a nominal 10 micrometers) by:</P>
          <P>(1) A reference method based on appendix J and designated in accordance with part 53 of this chapter, or</P>
          <P>(2) An equivalent method designated in accordance with part 53 of this chapter.</P>
          <CITA>[52 FR 24663, July 1, 1987, as amended at 62 FR 38711, July 18, 1997; 65 FR 80779, Dec. 22, 2000]</CITA>
        </SECTION>
        <SECTION>
          <SECTNO>§ 50.7</SECTNO>

          <SUBJECT>National primary and secondary ambient air quality standards for PM2<E T="52">.</E>5.</SUBJECT>

          <P>(a) The national primary and secondary ambient air quality standards for particulate matter are 15.0 micrograms per cubic meter (µg/m<SU>3</SU>) annual arithmetic mean concentration, and 65 µg/m<SU>3</SU> 24-hour average concentration measured in the ambient air as PM<E T="52">2.5</E> (particles with an aerodynamic diameter less than or equal to a nominal 2.5 micrometers) by either:</P>
          <P>(1) A reference method based on appendix L of this part and designated in accordance with part 53 of this chapter; or</P>
          <P>(2) An equivalent method designated in accordance with part 53 of this chapter.</P>
          <P>(b) The annual primary and secondary PM<E T="52">2.5</E> standards are met when the annual arithmetic mean concentration, as determined in accordance with appendix N of this part, is less than or equal to 15.0 micrograms per cubic meter.</P>
          <P>(c) The 24-hour primary and secondary PM<E T="52">2.5</E> standards are met when <PRTPAGE P="8"/>the 98<E T="51">th</E> percentile 24-hour concentration, as determined in accordance with appendix N of this part, is less than or equal to 65 micrograms per cubic meter.</P>
          <CITA>[62 FR 38711, July 18, 1997, as amended at 69 FR 45595, July 30, 2004]</CITA>
        </SECTION>
        <SECTION>
          <SECTNO>§ 50.8</SECTNO>
          <SUBJECT>National primary ambient air quality standards for carbon monoxide.</SUBJECT>
          <P>(a) The national primary ambient air quality standards for carbon monoxide are:</P>
          <P>(1) 9 parts per million (10 milligrams per cubic meter) for an 8-hour average concentration not to be exceeded more than once per year and</P>
          <P>(2) 35 parts per million (40 milligrams per cubic meter) for a 1-hour average concentration not to be exceeded more than once per year.</P>
          <P>(b) The levels of carbon monoxide in the ambient air shall be measured by:</P>
          <P>(1) A reference method based on appendix C and designated in accordance with part 53 of this chapter, or</P>
          <P>(2) An equivalent method designated in accordance with part 53 of this chapter.</P>
          <P>(c) An 8-hour average shall be considered valid if at least 75 percent of the hourly average for the 8-hour period are available. In the event that only six (or seven) hourly averages are available, the 8-hour average shall be computed on the basis of the hours available using six (or seven) as the divisor.</P>
          <P>(d) When summarizing data for comparision with the standards, averages shall be stated to one decimal place. Comparison of the data with the levels of the standards in parts per million shall be made in terms of integers with fractional parts of 0.5 or greater rounding up.</P>
          <CITA>[50 FR 37501, Sept. 13, 1985]</CITA>
        </SECTION>
        <SECTION>
          <SECTNO>§ 50.9</SECTNO>
          <SUBJECT>National 1-hour primary and secondary ambient air quality standards for ozone.</SUBJECT>
          <P>(a) The level of the national 1-hour primary and secondary ambient air quality standards for ozone measured by a reference method based on appendix D to this part and designated in accordance with part 53 of this chapter, is 0.12 parts per million (235 µg/m<SU>3</SU>). The standard is attained when the expected number of days per calendar year with maximum hourly average concentrations above 0.12 parts per million (235 µg/m<SU>3</SU>) is equal to or less than 1, as determined by appendix H to this part.</P>
          <P>(b) The 1-hour standards set forth in this section will remain applicable to all areas notwithstanding the promulgation of 8-hour ozone standards under § 50.10. The 1-hour NAAQS set forth in paragraph (a) of this section will no longer apply to an area one year after the effective date of the designation of that area for the 8-hour ozone NAAQS pursuant to section 107 of the Clean Air Act. Area designations and classifications with respect to the 1-hour standards are codified in 40 CFR part 81.</P>
          <P>(c) EPA's authority under paragraph (b) of this section to determine that the 1-hour standard no longer applies to an area based on a determination that the area has attained the 1-hour standard is stayed until such time as EPA issues a final rule revising or reinstating such authority and considers and addresses in such rulemaking any comments concerning (1) which, if any, implementation activities for a revised ozone standard (including but not limited to designation and classification of areas) would need to occur before EPA would determine that the 1-hour ozone standard no longer applies to an area, and (2) the effect of revising the ozone NAAQS on the existing 1-hour ozone designations.</P>
          <CITA>[62 FR 38894, July 18, 1997, as amended at 65 FR 45200, July 20, 2000; 68 FR 38163, June 26, 2003, 69 FR 23996, Apr. 30, 2004]</CITA>
        </SECTION>
        <SECTION>
          <SECTNO>§ 50.10</SECTNO>
          <SUBJECT>National 8-hour primary and secondary ambient air quality standards for ozone.</SUBJECT>
          <P>(a) The level of the national 8-hour primary and secondary ambient air quality standards for ozone, measured by a reference method based on appendix D to this part and designated in accordance with part 53 of this chapter, is 0.08 parts per million (ppm), daily maximum 8-hour average.</P>

          <P>(b) The 8-hour primary and secondary ozone ambient air quality standards are met at an ambient air quality monitoring site when the average of the annual fourth-highest daily maximum 8-hour average ozone concentration is <PRTPAGE P="9"/>less than or equal to 0.08 ppm, as determined in accordance with appendix I to this part.</P>
          <CITA>[62 FR 38894, July 18, 1997]</CITA>
        </SECTION>
        <SECTION>
          <SECTNO>§ 50.11</SECTNO>
          <SUBJECT>National primary and secondary ambient air quality standards for nitrogen dioxide.</SUBJECT>
          <P>(a) The level of the national primary ambient air quality standard for nitrogen dioxide is 0.053 parts per million (100 micrograms per cubic meter), annual arithmetic mean concentration.</P>
          <P>(b) The level of national secondary ambient air quality standard for nitrogen dioxide is 0.053 parts per million (100 micrograms per cubic meter), annual arithmetic mean concentration.</P>
          <P>(c) The levels of the standards shall be measured by:</P>
          <P>(1) A reference method based on appendix F and designated in accordance with part 53 of this chapter, or</P>
          <P>(2) An equivalent method designated in accordance with part 53 of this chapter.</P>
          <P>(d) The standards are attained when the annual arithmetic mean concentration in a calendar year is less than or equal to 0.053 ppm, rounded to three decimal places (fractional parts equal to or greater than 0.0005 ppm must be rounded up). To demonstrate attainment, an annual mean must be based upon hourly data that are at least 75 percent complete or upon data derived from manual methods that are at least 75 percent complete for the scheduled sampling days in each calendar quarter.</P>
          <CITA>[50 FR 25544, June 19, 1985]</CITA>
        </SECTION>
        <SECTION>
          <SECTNO>§ 50.12</SECTNO>
          <SUBJECT>National primary and secondary ambient air quality standards for lead.</SUBJECT>
          <P>National primary and secondary ambient air quality standards for lead and its compounds, measured as elemental lead by a reference method based on appendix G to this part, or by an equivalent method, are: 1.5 micrograms per cubic meter, maximum arithmetic mean averaged over a calendar quarter.</P>
          <SECAUTH>(Secs. 109, 301(a) Clean Air Act as amended (42 U.S.C. 7409, 7601(a)))</SECAUTH>
          <CITA>[43 FR 46258, Oct. 5, 1978]</CITA>
        </SECTION>
        <APPENDIX>
          <EAR>Pt. 50, App. A</EAR>
          <HD SOURCE="HED">Appendix A to Part 50—Reference Method for the Determination of Sulfur Dioxide in the Atmosphere (Pararosaniline Method)</HD>
          <P>1.0 <E T="03">Applicability.</E>
          </P>

          <P>1.1 This method provides a measurement of the concentration of sulfur dioxide (SO<E T="52">2</E>) in ambient air for determining compliance with the primary and secondary national ambient air quality standards for sulfur oxides (sulfur dioxide) as specified in § 50.4 and § 50.5 of this chapter. The method is applicable to the measurement of ambient SO<E T="52">2</E> concentrations using sampling periods ranging from 30 minutes to 24 hours. Additional quality assurance procedures and guidance are provided in part 58, appendixes A and B, of this chapter and in references 1 and 2.</P>
          <P>2.0 <E T="03">Principle.</E>
          </P>

          <P>2.1 A measured volume of air is bubbled through a solution of 0.04 M potassium tetrachloromercurate (TCM). The SO<E T="52">2</E> present in the air stream reacts with the TCM solution to form a stable monochlorosulfonatomercurate(<E T="03">3</E>) complex. Once formed, this complex resists air oxidation(<E T="03">4, 5</E>) and is stable in the presence of strong oxidants such as ozone and oxides of nitrogen. During subsequent analysis, the complex is reacted with acid-bleached pararosaniline dye and formaldehyde to form an intensely colored pararosaniline methyl sulfonic acid.(<E T="03">6</E>) The optical density of this species is determined spectrophotometrically at 548 nm and is directly related to the amount of SO<E T="52">2</E> collected. The total volume of air sampled, corrected to EPA reference conditions (25 °C, 760 mm Hg [101 kPa]), is determined from the measured flow rate and the sampling time. The concentration of SO<E T="52">2</E> in the ambient air is computed and expressed in micrograms per standard cubic meter (µg/std m<SU>3</SU>).</P>
          <P>3.0 <E T="03">Range.</E>
          </P>
          <P>3.1 The lower limit of detection of SO<E T="52">2</E> in 10 mL of TCM is 0.75 µg (based on collaborative test results).(<E T="03">7</E>) This represents a concentration of 25 µg SO<E T="52">2</E>/m<SU>3</SU> (0.01 ppm) in an air sample of 30 standard liters (short-term sampling) and a concentration of 13 µg SO<E T="52">2</E>/m<SU>3</SU> (0.005 ppm) in an air sample of 288 standard liters (long-term sampling). Concentrations less than 25 µg SO<E T="52">2</E>/m<SU>3</SU> can be measured by sampling larger volumes of ambient air; however, the collection efficiency falls off rapidly at low concentrations.(<E T="03">8, 9</E>) Beer's law is adhered to up to 34 µg of SO<E T="52">2</E> in 25 mL of final solution. This upper limit of the analysis range represents a concentration of 1,130 µg SO<E T="52">2</E>/m<SU>3</SU> (0.43 ppm) in an air sample of 30 standard liters and a concentration of 590 µg SO<E T="52">2</E>/m<SU>3</SU> (0.23 ppm) in an air sample of 288 standard liters. Higher concentrations can be measured by collecting a smaller volume of air, by increasing the volume of absorbing solution, or by diluting a suitable portion of <PRTPAGE P="10"/>the collected sample with absorbing solution prior to analysis.</P>
          <P>4.0 <E T="03">Interferences.</E>
          </P>

          <P>4.1 The effects of the principal potential interferences have been minimized or eliminated in the following manner: Nitrogen oxides by the addition of sulfamic acid,(<E T="03">10, 11</E>) heavy metals by the addition of ethylenediamine tetracetic acid disodium salt (EDTA) and phosphoric acid,(<E T="03">10, 12</E>) and ozone by time delay.(<E T="03">10</E>) Up to 60 µg Fe (III), 22 µg V (V), 10 µg Cu (II), 10 µg Mn (II), and 10 µg Cr (III) in 10 mL absorbing reagent can be tolerated in the procedure.(<E T="03">10</E>) No significant interference has been encountered with 2.3 µg NH<E T="52">3</E>.(<E T="03">13</E>)</P>
          <P>5.0 <E T="03">Precision and Accuracy.</E>
          </P>

          <P>5.1 The precision of the analysis is 4.6 percent (at the 95 percent confidence level) based on the analysis of standard sulfite samples.(<E T="03">10</E>)</P>
          <P>5.2 Collaborative test results (<E T="03">14</E>) based on the analysis of synthetic test atmospheres (SO<E T="52">2</E> in scrubbed air) using the 24-hour sampling procedure and the sulfite-TCM calibration procedure show that:
          </P>
          <FP SOURCE="FP-1">• The replication error varies linearly with concentration from ±2.5 µg/m<SU>3</SU> at concentrations of 100 µg/m<SU>3</SU> to ±7 µg/m<SU>3</SU> at concentrations of 400 µg/m<SU>3</SU>.</FP>
          <FP SOURCE="FP-1">• The day-to-day variability within an individual laboratory (repeatability) varies linearly with concentration from ±18.1 µg/m<SU>3</SU> at levels of 100 µg/m<SU>3</SU> to ±50.9 µg/m<SU>3</SU> at levels of 400 µg/m<SU>3</SU>.</FP>
          <FP SOURCE="FP-1">• The day-to-day variability between two or more laboratories (reproducibility) varies linearly with concentration from ±36.9 µg/m<SU>3</SU> at levels of 100 µg/m<SU>3</SU> to ±103.5 µ g/m<SU>3</SU> at levels of 400 µg/m<SU>3</SU>.</FP>

          <FP SOURCE="FP-1">• The method has a concentration-dependent bias, which becomes significant at the 95 percent confidence level at the high concentration level. Observed values tend to be lower than the expected SO<E T="52">2</E> concentration level.</FP>
          
          <P>6.0 <E T="03">Stability.</E>
          </P>

          <P>6.1 By sampling in a controlled temperature environment of 15°±10 °C, greater than 98.9 percent of the SO<E T="52">2</E>-TCM complex is retained at the completion of sampling. (<E T="03">15</E>) If kept at 5 °C following the completion of sampling, the collected sample has been found to be stable for up to 30 days.(<E T="03">10</E>) The presence of EDTA enhances the stability of SO<E T="52">2</E> in the TCM solution and the rate of decay is independent of the concentration of SO<E T="52">2</E>.(<E T="03">16</E>)</P>
          <P>7.0 <E T="03">Apparatus.</E>
          </P>
          <P>7.1 <E T="03">Sampling.</E>
          </P>
          <P>7.1.1 <E T="03">Sample probe:</E> A sample probe meeting the requirements of section 7 of 40 CFR part 58, appendix E (Teflon<E T="51">®</E> or glass with residence time less than 20 sec.) is used to transport ambient air to the sampling train location. The end of the probe should be designed or oriented to preclude the sampling of precipitation, large particles, etc. A suitable probe can be constructed from Teflon<E T="51">®</E> tubing connected to an inverted funnel.</P>
          <P>7.1.2 <E T="03">Absorber—short-term sampling:</E> An all glass midget impinger having a solution capacity of 30 mL and a stem clearance of 4 ±1 mm from the bottom of the vessel is used for sampling periods of 30 minutes and 1 hour (or any period considerably less than 24 hours). Such an impinger is shown in Figure 1. These impingers are commercially available from distributors such as Ace Glass, Incorporated.</P>
          <P>7.1.3 <E T="03">Absorber—24-hour sampling:</E> A polypropylene tube 32 mm in diameter and 164 mm long (available from Bel Art Products, Pequammock, NJ) is used as the absorber. The cap of the absorber must be a polypropylene cap with two ports (rubber stoppers are unacceptable because the absorbing reagent can react with the stopper to yield erroneously high SO<E T="52">2</E> concentrations). A glass impinger stem, 6 mm in diameter and 158 mm long, is inserted into one port of the absorber cap. The tip of the stem is tapered to a small diameter orifice (0.4 ±0.1 mm) such that a No. 79 jeweler's drill bit will pass through the opening but a No. 78 drill bit will not. Clearance from the bottom of the absorber to the tip of the stem must be 6 ±2 mm. Glass stems can be fabricated by any reputable glass blower or can be obtained from a scientific supply firm. Upon receipt, the orifice test should be performed to verify the orifice size. The 50 mL volume level should be permanently marked on the absorber. The assembled absorber is shown in Figure 2.</P>
          <P>7.1.4 <E T="03">Moisture trap:</E> A moisture trap constructed of a glass trap as shown in Figure 1 or a polypropylene tube as shown in Figure 2 is placed between the absorber tube and flow control device to prevent entrained liquid from reaching the flow control device. The tube is packed with indicating silica gel as shown in Figure 2. Glass wool may be substituted for silica gel when collecting short-term samples (1 hour or less) as shown in Figure 1, or for long term (24 hour) samples if flow changes are not routinely encountered.</P>
          <P>7.1.5 <E T="03">Cap seals:</E> The absorber and moisture trap caps must seal securely to prevent leaks during use. Heat-shrink material as shown in Figure 2 can be used to retain the cap seals if there is any chance of the caps coming loose during sampling, shipment, or storage.</P>
          <GPH DEEP="420" SPAN="2">
            <PRTPAGE P="11"/>
            <GID>50-702.eps</GID>
          </GPH>
          <GPH DEEP="470" SPAN="2">
            <PRTPAGE P="12"/>
            <GID>50-703.eps</GID>
          </GPH>
          <P>7.1.6 <E T="03">Flow control device:</E> A calibrated rotameter and needle valve combination capable of maintaining and measuring air flow to within ±2 percent is suitable for short-term sampling but may not be used for long-term sampling. A critical orifice can be used for regulating flow rate for both long-term and short-term sampling. A 22-gauge hypodermic <PRTPAGE P="13"/>needle 25 mm long may be used as a critical orifice to yield a flow rate of approximately 1 L/min for a 30-minute sampling period. When sampling for 1 hour, a 23-gauge hypodermic needle 16 mm in length will provide a flow rate of approximately 0.5 L/min. Flow control for a 24-hour sample may be provided by a 27-gauge hypodermic needle critical orifice that is 9.5 mm in length. The flow rate should be in the range of 0.18 to 0.22 L/min.</P>
          <P>7.1.7 <E T="03">Flow measurement device:</E> Device calibrated as specified in 9.4.1 and used to measure sample flow rate at the monitoring site.</P>
          <P>7.1.8 <E T="03">Membrane particle filter:</E> A membrane filter of 0.8 to 2 µm porosity is used to protect the flow controller from particles during long-term sampling. This item is optional for short-term sampling.</P>
          <P>7.1.9 <E T="03">Vacuum pump:</E> A vacuum pump equipped with a vacuum gauge and capable of maintaining at least 70 kPa (0.7 atm) vacuum differential across the flow control device at the specified flow rate is required for sampling.</P>
          <P>7.1.10 <E T="03">Temperature control device:</E> The temperature of the absorbing solution during sampling must be maintained at 15° ±10 °C. As soon as possible following sampling and until analysis, the temperature of the collected sample must be maintained at 5° ±5 °C. Where an extended period of time may elapse before the collected sample can be moved to the lower storage temperature, a collection temperature near the lower limit of the 15 ±10 °C range should be used to minimize losses during this period. Thermoelectric coolers specifically designed for this temperature control are available commercially and normally operate in the range of 5° to 15 °C. Small refrigerators can be modified to provide the required temperature control; however, inlet lines must be insulated from the lower temperatures to prevent condensation when sampling under humid conditions. A small heating pad may be necessary when sampling at low temperatures (&lt;7 °C) to prevent the absorbing solution from freezing.(<E T="03">17</E>)</P>
          <P>7.1.11 <E T="03">Sampling train container:</E> The absorbing solution must be shielded from light during and after sampling. Most commercially available sampler trains are enclosed in a light-proof box.</P>
          <P>7.1.12 <E T="03">Timer:</E> A timer is recommended to initiate and to stop sampling for the 24-hour period. The timer is not a required piece of equipment; however, without the timer a technician would be required to start and stop the sampling manually. An elapsed time meter is also recommended to determine the duration of the sampling period.</P>
          <P>7.2 <E T="03">Shipping.</E>
          </P>
          <P>7.2.1 <E T="03">Shipping container:</E> A shipping container that can maintain a temperature of 5° ±5 °C is used for transporting the sample from the collection site to the analytical laboratory. Ice coolers or refrigerated shipping containers have been found to be satisfactory. The use of eutectic cold packs instead of ice will give a more stable temperature control. Such equipment is available from Cole-Parmer Company, 7425 North Oak Park Avenue, Chicago, IL 60648.</P>
          <P>7.3 <E T="03">Analysis.</E>
          </P>
          <P>7.3.1 <E T="03">Spectrophotometer:</E> A spectrophotometer suitable for measurement of absorbances at 548 nm with an effective spectral bandwidth of less than 15 nm is required for analysis. If the spectrophotometer reads out in transmittance, convert to absorbance as follows:</P>
          <MATH DEEP="13" SPAN="1">
            <MID>EC08NO91.000</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">A = absorbance, and</FP>
          <FP SOURCE="FP-1">T = transmittance (0&lt;≥T&lt;1).</FP>
          
          <P>A standard wavelength filter traceable to the National Bureau of Standards is used to verify the wavelength calibration according to the procedure enclosed with the filter. The wavelength calibration must be verified upon initial receipt of the instrument and after each 160 hours of normal use or every 6 months, whichever occurs first.</P>
          <P>7.3.2 <E T="03">Spectrophotometer cells:</E> A set of 1-cm path length cells suitable for use in the visible region is used during analysis. If the cells are unmatched, a matching correction factor must be determined according to Section 10.1.</P>
          <P>7.3.3 <E T="03">Temperature control device:</E> The color development step during analysis must be conducted in an environment that is in the range of 20° to 30 °C and controlled to ±1 °C. Both calibration and sample analysis must be performed under identical conditions (within 1 °C). Adequate temperature control may be obtained by means of constant temperature baths, water baths with manual temperature control, or temperature controlled rooms.</P>
          <P>7.3.4 <E T="03">Glassware:</E> Class A volumetric glassware of various capacities is required for preparing and standardizing reagents and standards and for dispensing solutions during analysis. These included pipets, volumetric flasks, and burets.</P>
          <P>7.3.5 <E T="03">TCM waste receptacle:</E> A glass waste receptacle is required for the storage of spent TCM solution. This vessel should be stoppered and stored in a hood at all times.</P>
          <P>8.0 <E T="03">Reagents.</E>
          </P>
          <P>8.1 <E T="03">Sampling.</E>
          </P>
          <P>8.1.1 <E T="03">Distilled water:</E> Purity of distilled water must be verified by the following procedure:(<E T="03">18</E>)</P>

          <FP SOURCE="FP-1">• Place 0.20 mL of potassium permanganate solution (0.316 g/L), 500 mL of distilled water, and 1mL of concentrated sulfuric acid in a chemically resistant glass bottle, stopper the bottle, and allow to stand.<PRTPAGE P="14"/>
          </FP>
          <FP SOURCE="FP-1">• If the permanganate color (pink) does not disappear completely after a period of 1 hour at room temperature, the water is suitable for use.</FP>
          <FP SOURCE="FP-1">• If the permanganate color does disappear, the water can be purified by redistilling with one crystal each of barium hydroxide and potassium permanganate in an all glass still.</FP>
          
          <P>8.1.2 <E T="03">Absorbing reagent</E> (0.04 M potassium tetrachloromercurate [TCM]): Dissolve 10.86 g mercuric chloride, 0.066 g EDTA, and 6.0 g potassium chloride in distilled water and dilute to volume with distilled water in a 1,000-mL volumetric flask. (<E T="03">Caution:</E> Mercuric chloride is highly poisonous. If spilled on skin, flush with water immediately.) The pH of this reagent should be between 3.0 and 5.0 (<E T="03">10</E>) Check the pH of the absorbing solution by using pH indicating paper or a pH meter. If the pH of the solution is not between 3.0 and 5.0, dispose of the solution according to one of the disposal techniques described in Section 13.0. The absorbing reagent is normally stable for 6 months. If a precipitate forms, dispose of the reagent according to one of the procedures described in Section 13.0.</P>
          <P>8.2 <E T="03">Analysis</E>.</P>
          <P>8.2.1 <E T="03">Sulfamic acid</E> (0.6%): Dissolve 0.6 g sulfamic acid in 100 mL distilled water. Perpare fresh daily.</P>
          <P>8.2.2 <E T="03">Formaldehyde</E> (0.2%): Dilute 5 mL formaldehyde solution (36 to 38 percent) to 1,000 mL with distilled water. Prepare fresh daily.</P>
          <P>8.2.3 <E T="03">Stock iodine solution</E> (0.1 N): Place 12.7 g resublimed iodine in a 250-mL beaker and add 40 g potassium iodide and 25 mL water. Stir until dissolved, transfer to a 1,000 mL volumetric flask and dilute to volume with distilled water.</P>
          <P>8.2.4 <E T="03">Iodine solution</E> (0.01 N): Prepare approximately 0.01 N iodine solution by diluting 50 mL of stock iodine solution (Section 8.2.3) to 500 mL with distilled water.</P>
          <P>8.2.5 <E T="03">Starch indicator solution:</E> Triturate 0.4 g soluble starch and 0.002 g mercuric iodide (preservative) with enough distilled water to form a paste. Add the paste slowly to 200 mL of boiling distilled water and continue boiling until clear. Cool and transfer the solution to a glass stopperd bottle.</P>
          <P>8.2.6 <E T="03">1 N hydrochloric acid:</E> Slowly and while stirring, add 86 mL of concentrated hydrochloric acid to 500 mL of distilled water. Allow to cool and dilute to 1,000 mL with distilled water.</P>
          <P>8.2.7 <E T="03">Potassium iodate solution:</E> Accurately weigh to the nearest 0.1 mg, 1.5 g (record weight) of primary standard grade potassium iodate that has been previously dried at 180 °C for at least 3 hours and cooled in a dessicator. Dissolve, then dilute to volume in a 500-mL volumetric flask with distilled water.</P>
          <P>8.2.8 <E T="03">Stock sodium thiosulfate solution</E> (0.1 N): Prepare a stock solution by dissolving 25 g sodium thiosulfate (Na<E T="52">2</E> S<E T="52">2</E> O<E T="52">3</E>÷5H<E T="52">2</E> O) in 1,000 mL freshly boiled, cooled, distilled water and adding 0.1 g sodium carbonate to the solution. Allow the solution to stand at least 1 day before standardizing. To standardize, accurately pipet 50 mL of potassium iodate solution (Section 8.2.7) into a 500-mL iodine flask and add 2.0 g of potassium iodide and 10 mL of 1 N HCl. Stopper the flask and allow to stand for 5 minutes. Titrate the solution with stock sodium thiosulfate solution (Section 8.2.8) to a pale yellow color. Add 5 mL of starch solution (Section 8.2.5) and titrate until the blue color just disappears. Calculate the normality (N<E T="52">s</E>) of the stock sodium thiosulfate solution as follows:</P>
          <MATH DEEP="26" SPAN="1">
            <MID>EC08NO91.001</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">M = volume of thiosulfate required in mL, and</FP>
          <FP SOURCE="FP-1">W = weight of potassium iodate in g (recorded weight in Section 8.2.7).</FP>
          <MATH DEEP="19" SPAN="1">
            <MID>EC08NO91.002</MID>
          </MATH>
          <P>8.2.9<E T="03">Working sodium thiosulfate titrant</E> (0.01 N): Accurately pipet 100 mL of stock sodium thiosulfate solution (Section 8.2.8) into a 1,000-mL volumetric flask and dilute to volume with freshly boiled, cooled, distilled water. Calculate the normality of the working sodium thiosulfate titrant (N<E T="52">T</E>) as follows:</P>
          <MATH DEEP="13" SPAN="1">
            <MID>EC08NO91.003</MID>
          </MATH>
          <P>8.2.10 <E T="03">Standardized sulfite solution for the preparation of working sulfite-TCM solution:</E> Dissolve 0.30 g sodium metabisulfite (Na<E T="52">2</E> S<E T="52">2</E> O<E T="52">5</E>) or 0.40 g sodium sulfite (Na<E T="52">2</E> SO<E T="52">3</E>) in 500 mL of recently boiled, cooled, distilled water. (Sulfite solution is unstable; it is therefore important to use water of the highest purity to minimize this instability.) This solution contains the equivalent of 320 to 400 µg SO<E T="52">2</E>/mL. The actual concentration of the solution is determined by adding excess iodine and back-titrating with standard sodium thiosulfate solution. To back-titrate, pipet 50 mL of the 0.01 N iodine solution (Section 8.2.4) into each of two 500-mL iodine flasks (A and B). To flask A (blank) add 25 mL distilled water, and to flask B (sample) pipet 25 mL sulfite solution. Stopper the flasks and allow to stand for 5 minutes. Prepare the working sulfite-TCM solution (Section 8.2.11) immediately prior to adding the iodine solution to the flasks. Using a buret containing standardized 0.01 N thiosulfate titrant (Section 8.2.9), titrate the solution in each flask to a pale yellow color. Then add 5 <PRTPAGE P="15"/>mL starch solution (Section 8.2.5) and continue the titration until the blue color just disappears.</P>
          <P>8.2.11 <E T="03">Working sulfite-TCM solution:</E> Accurately pipet 5 mL of the standard sulfite solution (Section 8.2.10) into a 250-mL volumetric flask and dilute to volume with 0.04 M TCM. Calculate the concentration of sulfur dioxide in the working solution as follows:</P>
          <MATH DEEP="27" SPAN="2">
            <MID>EC08NO91.004</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">A = volume of thiosulfate titrant required for the blank, mL;</FP>
          <FP SOURCE="FP-1">B = volume of thiosulfate titrant required for the sample, mL;</FP>
          <FP SOURCE="FP-1">N<E T="52">T</E> = normality of the thiosulfate titrant, from equation (3);</FP>
          <FP SOURCE="FP-1">32,000 = milliequivalent weight of SO<E T="52">2</E>, µg;</FP>
          <FP SOURCE="FP-1">25 = volume of standard sulfite solution, mL; and</FP>
          <FP SOURCE="FP-1">0.02 = dilution factor.</FP>
          
          <P>This solution is stable for 30 days if kept at 5 °C. (16) If not kept at 5 °C, prepare fresh daily.</P>
          <P>8.2.12 <E T="03">Purified pararosaniline (PRA) stock solution</E> (0.2% nominal):</P>
          <P>8.2.12.1 <E T="03">Dye specifications</E>—
          </P>
          <FP SOURCE="FP-1">• The dye must have a maximum absorbance at a wavelength of 540 nm when assayed in a buffered solution of 0.1 M sodium acetate-acetic acid;</FP>
          <FP SOURCE="FP-1">• The absorbance of the reagent blank, which is temperature sensitive (0.015 absorbance unit/ °C), must not exceed 0.170 at 22 °C with a 1-cm optical path length when the blank is prepared according to the specified procedure;</FP>

          <FP SOURCE="FP-1">• The calibration curve (Section 10.0) must have a slope equal to 0.030 ±0.002 absorbance unit/µg SO<E T="52">2</E> with a 1-cm optical path length when the dye is pure and the sulfite solution is properly standardized.</FP>
          
          <P>8.2.12.2 <E T="03">Preparation of stock PRA solution</E>—A specially purified (99 to 100 percent pure) solution of pararosaniline, which meets the above specifications, is commercially available in the required 0.20 percent concentration (Harleco Co.). Alternatively, the dye may be purified, a stock solution prepared, and then assayed according to the procedure as described below.(<E T="03">10</E>)</P>
          <P>8.2.12.3 <E T="03">Purification procedure for PRA</E>—</P>

          <P>1. Place 100 mL each of 1-butanol and 1 N HCl in a large separatory funnel (250-mL) and allow to equilibrate. Note: Certain batches of 1-butanol contain oxidants that create an SO<E T="52">2</E> demand. Before using, check by placing 20 mL of 1-butanol and 5 mL of 20 percent potassium iodide (KI) solution in a 50-mL separatory funnel and shake thoroughly. If a yellow color appears in the alcohol phase, redistill the 1-butanol from silver oxide and collect the middle fraction or purchase a new supply of 1-butanol.</P>
          <P>2. Weigh 100 mg of pararosaniline hydrochloride dye (PRA) in a small beaker. Add 50 mL of the equilibrated acid (drain in acid from the bottom of the separatory funnel in 1.) to the beaker and let stand for several minutes. Discard the remaining acid phase in the separatory funnel.</P>
          <P>3. To a 125-mL separatory funnel, add 50 mL of the equilibrated 1-butanol (draw the 1-butanol from the top of the separatory funnel in 1.). Transfer the acid solution (from 2.) containing the dye to the funnel and shake carefully to extract. The violet impurity will transfer to the organic phase.</P>
          <P>4. Transfer the lower aqueous phase into another separatory funnel, add 20 mL of equilibrated 1-butanol, and extract again.</P>
          <P>5. Repeat the extraction procedure with three more 10-mL portions of equilibrated 1-butanol.</P>
          <P>6. After the final extraction, filter the acid phase through a cotton plug into a 50-mL volumetric flask and bring to volume with 1 N HCl. This stock reagent will be a yellowish red.</P>
          <P>7. To check the purity of the PRA, perform the assay and adjustment of concentration (Section 8.2.12.4) and prepare a reagent blank (Section 11.2); the absorbance of this reagent blank at 540 nm should be less than 0.170 at 22 °C. If the absorbance is greater than 0.170 under these conditions, further extractions should be performed.</P>
          <P>8.2.12.4 <E T="03">PRA assay procedure</E>—The concentration of pararosaniline hydrochloride (PRA) need be assayed only once after purification. It is also recommended that commercial solutions of pararosaniline be assayed when first purchased. The assay procedure is as follows:(<E T="03">10</E>)</P>
          <P>1. Prepare 1 M acetate-acetic acid buffer stock solution with a pH of 4.79 by dissolving 13.61 g of sodium acetate trihydrate in distilled water in a 100-mL volumetric flask. Add 5.70 mL of glacial acetic acid and dilute to volume with distilled water.</P>

          <P>2. Pipet 1 mL of the stock PRA solution obtained from the purification process or from a commercial source into a 100-mL volumetric flask and dilute to volume with distilled water.<PRTPAGE P="16"/>
          </P>
          <P>3. Transfer a 5-mL aliquot of the diluted PRA solution from 2. into a 50-mL volumetric flask. Add 5mL of 1 M acetate-acetic acid buffer solution from 1. and dilute the mixture to volume with distilled water. Let the mixture stand for 1 hour.</P>
          <P>4. Measure the absorbance of the above solution at 540 nm with a spectrophotometer against a distilled water reference. Compute the percentage of nominal concentration of PRA by</P>
          <MATH DEEP="26" SPAN="1">
            <MID>EC08NO91.005</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">A = measured absorbance of the final mixture (absorbance units);</FP>
          <FP SOURCE="FP-1">W = weight in grams of the PRA dye used in the assay to prepare 50 mL of stock solution (for example, 0.100 g of dye was used to prepare 50 mL of solution in the purification procedure; when obtained from commercial sources, use the stated concentration to compute W; for 98% PRA, W=.098 g.); and</FP>
          <FP SOURCE="FP-1">K = 21.3 for spectrophotometers having a spectral bandwidth of less than 15 nm and a path length of 1 cm.</FP>
          
          <P>8.2.13 <E T="03">Pararosaniline reagent:</E> To a 250-mL volumetric flask, add 20 mL of stock PRA solution. Add an additional 0.2 mL of stock solution for each percentage that the stock assays below 100 percent. Then add 25 mL of 3 M phosphoric acid and dilute to volume with distilled water. The reagent is stable for at least 9 months. Store away from heat and light.</P>
          <P>9.0 <E T="03">Sampling Procedure.</E>
          </P>
          <P>9.1 <E T="03">General Considerations.</E> Procedures are described for short-term sampling (30-minute and 1-hour) and for long-term sampling (24-hour). Different combinations of absorbing reagent volume, sampling rate, and sampling time can be selected to meet special needs. For combinations other than those specifically described, the conditions must be adjusted so that linearity is maintained between absorbance and concentration over the dynamic range. Absorbing reagent volumes less than 10 mL are not recommended. The collection efficiency is above 98 percent for the conditions described; however, the efficiency may be substantially lower when sampling concentrations below 25 µγSO<E T="52">2</E>/m<SU>3</SU>.(<E T="03">8,9</E>)</P>
          <P>9.2 <E T="03">30-Minute and 1-Hour Sampling.</E> Place 10 mL of TCM absorbing reagent in a midget impinger and seal the impinger with a thin film of silicon stopcock grease (around the ground glass joint). Insert the sealed impinger into the sampling train as shown in Figure 1, making sure that all connections between the various components are leak tight. Greaseless ball joint fittings, heat shrinkable Teflon<E T="51">®</E> tubing, or Teflon<E T="51">®</E> tube fittings may be used to attain leakfree conditions for portions of the sampling train that come into contact with air containing SO<E T="52">2</E>. Shield the absorbing reagent from direct sunlight by covering the impinger with aluminum foil or by enclosing the sampling train in a light-proof box. Determine the flow rate according to Section 9.4.2. Collect the sample at 1 ±0.10 L/min for 30-minute sampling or 0.500 ±0.05 L/min for 1-hour sampling. Record the exact sampling time in minutes, as the sample volume will later be determined using the sampling flow rate and the sampling time. Record the atmospheric pressure and temperature.</P>
          <P>9.3 <E T="03">24-Hour Sampling.</E> Place 50 mL of TCM absorbing solution in a large absorber, close the cap, and, if needed, apply the heat shrink material as shown in Figure 3. Verify that the reagent level is at the 50 mL mark on the absorber. Insert the sealed absorber into the sampling train as shown in Figure 2. At this time verify that the absorber temperature is controlled to 15 ±10 °C. During sampling, the absorber temperature must be controlled to prevent decomposition of the collected complex. From the onset of sampling until analysis, the absorbing solution must be protected from direct sunlight. Determine the flow rate according to Section 9.4.2. Collect the sample for 24 hours from midnight to midnight at a flow rate of 0.200 ±0.020 L/min. A start/stop timer is helpful for initiating and stopping sampling and an elapsed time meter will be useful for determining the sampling time.</P>
          <GPH DEEP="340" SPAN="2">
            <PRTPAGE P="17"/>
            <GID>50-708.eps</GID>
          </GPH>
          <P>9.4 <E T="03">Flow Measurement.</E>
          </P>
          <P>9.4.1 <E T="03">Calibration:</E> Flow measuring devices used for the on-site flow measurements required in 9.4.2 must be calibrated against a reliable flow or volume standard such as an NBS traceable bubble flowmeter or calibrated wet test meter. Rotameters or critical orifices used in the sampling train may be calibrated, if desired, as a quality control check, but such calibration shall not replace the on-site flow measurements required by 9.4.2. In-line rotameters, if they are to be calibrated, should be calibrated in situ, with the appropriate volume of solution in the absorber.</P>
          <P>9.4.2 <E T="03">Determination of flow rate at sampling site:</E> For short-term samples, the standard flow rate is determined at the sampling site at the initiation and completion of sample collection with a calibrated flow measuring device connected to the inlet of the absorber. For 24-hour samples, the standard flow rate is determined at the time the absorber is placed in the sampling train and again when the absorber is removed from the train for shipment to the analytical laboratory with a calibrated flow measuring device connected to the inlet of the sampling train. The flow rate determination must be made with all components of the sampling system in operation (e.g., the absorber temperature controller and any sample box heaters must also be operating). Equation 6 may be used to determine the standard flow rate when a calibrated positive displacement meter is used as the flow measuring device. Other types of calibrated flow measuring devices may also be used to determine the flow rate at the sampling site provided that the user applies any appropriate corrections to devices for which output is dependent on temperature or pressure.</P>
          <MATH DEEP="33" SPAN="2">
            <PRTPAGE P="18"/>
            <MID>EC08NO91.006</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">Q<E T="52">std</E> = flow rate at standard conditions, std L/min (25 °C and 760 mm Hg);</FP>
          <FP SOURCE="FP-1">Q<E T="52">act</E> = flow rate at monitoring site conditions, L/min;</FP>
          <FP SOURCE="FP-1">P<E T="52">b</E> = barometric pressure at monitoring site conditions, mm Hg or kPa;</FP>
          <FP SOURCE="FP-1">RH = fractional relative humidity of the air being measured;</FP>
          <FP SOURCE="FP-1">P<E T="52">H</E>
            <E T="0362">2</E>
            <E T="52">O</E> = vapor pressure of water at the temperature of the air in the flow or volume standard, in the same units as P<E T="52">b</E>, (for wet volume standards only, i.e., bubble flowmeter or wet test meter; for dry standards, i.e., dry test meter, P<E T="52">H</E>
            <E T="0362">2</E>
            <E T="52">O</E>=0);</FP>
          <FP SOURCE="FP-1">P<E T="52">std</E> = standard barometric pressure, in the same units as P<E T="52">b</E> (760 mm Hg or 101 kPa); and</FP>
          <FP SOURCE="FP-1">T<E T="52">meter</E> = temperature of the air in the flow or volume standard, °C (e.g., bubble flowmeter).</FP>
          
          <P>If a barometer is not available, the following equation may be used to determine the barometric pressure:</P>
          <MATH DEEP="12" SPAN="2">
            <MID>EC08NO91.007</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">H = sampling site elevation above sea level in meters.</FP>
          
          <P>If the initial flow rate (Q<E T="52">i</E>) differs from the flow rate of the critical orifice or the flow rate indicated by the flowmeter in the sampling train (Q<E T="52">c</E>) by more than 5 percent as determined by equation (8), check for leaks and redetermine Q<E T="52">i</E>.</P>
          <MATH DEEP="29" SPAN="1">
            <MID>EC08NO91.008</MID>
          </MATH>

          <P>Invalidate the sample if the difference between the initial (Q<E T="52">i</E>) and final (Q<E T="52">f</E>) flow rates is more than 5 percent as determined by equation (9):</P>
          <MATH DEEP="29" SPAN="1">
            <MID>EC08NO91.009</MID>
          </MATH>
          <P>9.5 <E T="03">Sample Storage and Shipment.</E> Remove the impinger or absorber from the sampling train and stopper immediately. Verify that the temperature of the absorber is not above 25 °C. Mark the level of the solution with a temporary (e.g., grease pencil) mark. If the sample will not be analyzed within 12 hours of sampling, it must be stored at 5° ±5 °C until analysis. Analysis must occur within 30 days. If the sample is transported or shipped for a period exceeding 12 hours, it is recommended that thermal coolers using eutectic ice packs, refrigerated shipping containers, etc., be used for periods up to 48 hours. (<E T="03">17</E>) Measure the temperature of the absorber solution when the shipment is received. Invalidate the sample if the temperature is above 10 °C. Store the sample at 5° ±5 °C until it is analyzed.</P>
          <P>10.0 <E T="03">Analytical Calibration.</E>
          </P>
          <P>10.1 <E T="03">Spectrophotometer Cell Matching.</E> If unmatched spectrophotometer cells are used, an absorbance correction factor must be determined as follows:</P>
          <P>1. Fill all cells with distilled water and designate the one that has the lowest absorbance at 548 nm as the reference. (This reference cell should be marked as such and continually used for this purpose throughout all future analyses.)</P>
          <P>2. Zero the spectrophotometer with the reference cell.</P>
          <P>3. Determine the absorbance of the remaining cells (A<E T="52">c</E>) in relation to the reference cell and record these values for future use. Mark all cells in a manner that adequately identifies the correction.</P>
          <P>The corrected absorbance during future analyses using each cell is determining as follows:</P>
          <MATH DEEP="13" SPAN="1">
            <MID>EC08NO91.010</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">A = corrected absorbance,</FP>
          <FP SOURCE="FP-1">A<E T="52">obs</E> = uncorrected absorbance, and</FP>
          <FP SOURCE="FP-1">A<E T="52">c</E> = cell correction.</FP>
          
          <P>10.2 <E T="03">Static Calibration Procedure</E> (Option 1). Prepare a dilute working sulfite-TCM solution by diluting 10 mL of the working sulfite-TCM solution (Section 8.2.11) to 100 mL with TCM absorbing reagent. Following the table below, accurately pipet the indicated volumes of the sulfite-TCM solutions into a series of 25-mL volumetric flasks. Add TCM absorbing reagent as indicated to bring the volume in each flask to 10 mL.<PRTPAGE P="19"/>
          </P>
          <GPOTABLE CDEF="s40,8,8,8" COLS="4" OPTS="L2">
            <BOXHD>
              <CHED H="1">Sulfite-TCM solution</CHED>
              <CHED H="1">Volume of sulfite-TCM solution</CHED>
              <CHED H="1">Volume of TCM, mL</CHED>
              <CHED H="1">Total µg SO<E T="52">2</E> (approx.*</CHED>
            </BOXHD>
            <ROW>
              <ENT I="01">Working</ENT>
              <ENT>4.0</ENT>
              <ENT>6.0</ENT>
              <ENT>28.8</ENT>
            </ROW>
            <ROW>
              <ENT I="01">Working</ENT>
              <ENT>3.0</ENT>
              <ENT>7.0</ENT>
              <ENT>21.6</ENT>
            </ROW>
            <ROW>
              <ENT I="01">Working</ENT>
              <ENT>2.0</ENT>
              <ENT>8.0</ENT>
              <ENT>14.4</ENT>
            </ROW>
            <ROW>
              <ENT I="01">Dilute working</ENT>
              <ENT>10.0</ENT>
              <ENT>0.0</ENT>
              <ENT>7.2</ENT>
            </ROW>
            <ROW>
              <ENT I="01">Dilute working</ENT>
              <ENT>5.0</ENT>
              <ENT>5.0</ENT>
              <ENT>3.6</ENT>
            </ROW>
            <ROW>
              <ENT I="11"/>
              <ENT>0.0</ENT>
              <ENT>10.0</ENT>
              <ENT>0.0</ENT>
            </ROW>

            <TNOTE>*Based on working sulfite-TCM solution concentration of 7.2 µg SO<E T="52">2</E>/mL; the actual total µg SO<E T="52">2</E> must be calculated using equation 11 below.</TNOTE>
          </GPOTABLE>

          <P>To each volumetric flask, add 1 mL 0.6% sulfamic acid (Section 8.2.1), accurately pipet 2 mL 0.2% formaldehyde solution (Section 8.2.2), then add 5 mL pararosaniline solution (Section 8.2.13). Start a laboratory timer that has been set for 30 minutes. Bring all flasks to volume with recently boiled and cooled distilled water and mix thoroughly. The color must be developed (during the 30-minute period) in a temperature environment in the range of 20° to 30 °C, which is controlled to ±1 °C. For increased precision, a constant temperature bath is recommended during the color development step. After 30 minutes, determine the corrected absorbance of each standard at 548 nm against a distilled water reference (Section 10.1). Denote this absorbance as (A). Distilled water is used in the reference cell rather than the reagant blank because of the temperature sensitivity of the reagent blank. Calculate the total micrograms SO<E T="52">2</E> in each solution:</P>
          <MATH DEEP="13" SPAN="2">
            <MID>EC08NO91.011</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">V<E T="52">TCM/SO</E>2 = volume of sulfite-TCM solution used, mL;</FP>
          <FP SOURCE="FP-1">C<E T="52">TCM/SO</E>2 = concentration of sulfur dioxide in the working sulfite-TCM, µg SO<E T="52">2</E>/mL (from equation 4); and</FP>
          <FP SOURCE="FP-1">D = dilution factor (D = 1 for the working sulfite-TCM solution; D = 0.1 for the diluted working sulfite-TCM solution).</FP>
          

          <P>A calibration equation is determined using the method of linear least squares (Section 12.1). The total micrograms SO<E T="52">2</E> contained in each solution is the x variable, and the corrected absorbance (eq. 10) associated with each solution is the y variable. For the calibration to be valid, the slope must be in the range of 0.030 ±0.002 absorbance unit/µg SO<E T="52">2</E>, the intercept as determined by the least squares method must be equal to or less than 0.170 absorbance unit when the color is developed at 22 °C (add 0.015 to this 0.170 specification for each °C above 22 °C) and the correlation coefficient must be greater than 0.998. If these criteria are not met, it may be the result of an impure dye and/or an improperly standardized sulfite-TCM solution. A calibration factor (B<E T="52">s</E>) is determined by calculating the reciprocal of the slope and is subsequently used for calculating the sample concentration (Section 12.3).</P>
          <P>10.3 <E T="03">Dynamic Calibration Procedures</E> (Option 2). Atmospheres containing accurately known concentrations of sulfur dioxide are prepared using permeation devices. In the systems for generating these atmospheres, the permeation device emits gaseous SO<E T="52">2</E> at a known, low, constant rate, provided the temperature of the device is held constant (±0.1 °C) and the device has been accurately calibrated at the temperature of use. The SO<E T="52">2</E> permeating from the device is carried by a low flow of dry carrier gas to a mixing chamber where it is diluted with SO<E T="52">2</E>-free air to the desired concentration and supplied to a vented manifold. A typical system is shown schematically in Figure 4 and this system and other similar systems have been described in detail by O'Keeffe and Ortman; (<E T="03">19</E>) Scaringelli, Frey, and Saltzman, (<E T="03">20</E>) and Scaringelli, O'Keeffe, Rosenberg, and Bell. (<E T="03">21</E>) Permeation devices may be prepared or purchased and in both cases must be traceable either to a National Bureau of Standards (NBS) Standard Reference Material (SRM 1625, SRM 1626, SRM 1627) or to an NBS/EPA-approved commercially available Certified Reference Material (CRM). CRM's are described in Reference 22, and a list of CRM sources is available from the address shown for Reference 22. A recommended protocol for certifying a permeation device to an NBS SRM or CRM is given in Section 2.0.7 of Reference 2. Device permeation rates of 0.2 to 0.4 µg/min, inert gas flows of about 50 mL/min, and dilution air flow rates from 1.1 to 15 L/min conveniently yield standard atmospheres in the range of 25 to 600 µg SO<E T="52">2</E>/m<SU>3</SU> (0.010 to 0.230 ppm).</P>
          <P>10.3.1 <E T="03">Calibration Option 2A</E> (30-minute and 1-hour samples): Generate a series of six standard atmospheres of SO<E T="52">2</E> (e.g., 0, 50, 100, 200, 350, 500, 750 µg/m<SU>3</SU>) by adjusting the dilution flow rates appropriately. The concentration of SO<E T="52">2</E> in each atmosphere is calculated as follows:</P>
          <MATH DEEP="32" SPAN="1">
            <MID>ER31AU93.014</MID>
          </MATH>
          <FP>where:</FP>
          
          <PRTPAGE P="20"/>
          <FP SOURCE="FP-1">C<E T="52">a</E> = concentration of SO<E T="52">2</E> at standard conditions, µg/m<SU>3</SU>;</FP>
          <FP SOURCE="FP-1">P<E T="52">r</E> = permeation rate, µg/min;</FP>
          <FP SOURCE="FP-1">Q<E T="52">d</E> = flow rate of dilution air, std L/min; and</FP>
          <FP SOURCE="FP-1">Q<E T="52">p</E> = flow rate of carrier gas across permeation device, std L/min.</FP>
          <GPH DEEP="454" SPAN="2">
            <GID>50-712.eps</GID>
          </GPH>
          <PRTPAGE P="21"/>

          <P>Be sure that the total flow rate of the standard exceeds the flow demand of the sample train, with the excess flow vented at atmospheric pressure. Sample each atmosphere using similar apparatus as shown in Figure 1 and under the same conditions as field sampling (i.e., use same absorbing reagent volume and sample same volume of air at an equivalent flow rate). Due to the length of the sampling periods required, this method is not recommended for 24-hour sampling. At the completion of sampling, quantitatively transfer the contents of each impinger to one of a series of 25-mL volumetric flasks (if 10 mL of absorbing solution was used) using small amounts of distilled water for rinse (&lt;5mL). If &gt;10 mL of absorbing solution was used, bring the absorber solution in each impinger to orginal volume with distilled H<E T="52">2</E> O and pipet 10-mL portions from each impinger into a series of 25-mL volumetric flasks. If the color development steps are not to be started within 12 hours of sampling, store the solutions at 5° ±5 °C. Calculate the total micrograms SO<E T="52">2</E> in each solution as follows:</P>
          <MATH DEEP="27" SPAN="1">
            <MID>ER31AU93.015</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">C<E T="52">a</E> = concentration of SO<E T="52">2</E> in the standard atmosphere, µg/m<SU>3</SU>;</FP>
          <FP SOURCE="FP-1">O<E T="52">s</E> = sampling flow rate, std L/min;</FP>
          <FP SOURCE="FP-1">t=sampling time, min;</FP>
          <FP SOURCE="FP-1">V<E T="52">a</E> = volume of absorbing solution used for color development (10 mL); and</FP>
          <FP SOURCE="FP-1">V<E T="52">b</E> = volume of absorbing solution used for sampling, mL.</FP>
          

          <P>Add the remaining reagents for color development in the same manner as in Section 10.2 for static solutions. Calculate a calibration equation and a calibration factor (B<E T="52">g</E>) according to Section 10.2, adhering to all the specified criteria.</P>

          <P>10.3.2 Calibration Option 2B (24-hour samples): Generate a standard atmosphere containing approximately 1,050 µg SO<E T="52">2</E>/m<SU>3</SU> and calculate the exact concentration according to equation 12. Set up a series of six absorbers according to Figure 2 and connect to a common manifold for sampling the standard atmosphere. Be sure that the total flow rate of the standard exceeds the flow demand at the sample manifold, with the excess flow vented at atmospheric pressure. The absorbers are then allowed to sample the atmosphere for varying time periods to yield solutions containing 0, 0.2, 0.6, 1.0, 1.4, 1.8, and 2.2 µg SO<E T="52">2</E>/mL solution. The sampling times required to attain these solution concentrations are calculated as follows:</P>
          <MATH DEEP="28" SPAN="1">
            <MID>ER31AU93.016</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">t = sampling time, min;</FP>
          <FP SOURCE="FP-1">V<E T="52">b</E> = volume of absorbing solution used for sampling (50 mL);</FP>
          <FP SOURCE="FP-1">C<E T="52">s</E> = desired concentration of SO<E T="52">2</E> in the absorbing solution, µg/mL;</FP>
          <FP SOURCE="FP-1">C<E T="52">a</E> = concentration of the standard atmosphere calculated according to equation 12, µg/m<SU>3</SU>; and</FP>
          <FP SOURCE="FP-1">Q<E T="52">s</E> = sampling flow rate, std L/min.</FP>
          

          <P>At the completion of sampling, bring the absorber solutions to original volume with distilled water. Pipet a 10-mL portion from each absorber into one of a series of 25-mL volumetric flasks. If the color development steps are not to be started within 12 hours of sampling, store the solutions at 5° ±5 °C. Add the remaining reagents for color development in the same manner as in Section 10.2 for static solutions. Calculate the total µg SO<E T="52">2</E> in each standard as follows:</P>
          <MATH DEEP="32" SPAN="1">
            <MID>ER31AU93.017</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">V<E T="52">a</E> = volume of absorbing solution used for color development (10 mL).</FP>
          <FP SOURCE="FP-1">All other parameters are defined in equation 14.</FP>
          

          <P>Calculate a calibration equation and a calibration factor (B<E T="52">t</E>) according to Section 10.2 adhering to all the specified criteria.</P>
          <P>11.0 <E T="03">Sample Preparation and Analysis.</E>
          </P>
          <P>11.1 <E T="03">Sample Preparation.</E> Remove the samples from the shipping container. If the shipment period exceeded 12 hours from the completion of sampling, verify that the temperature is below 10 °C. Also, compare the solution level to the temporary level mark on the absorber. If either the temperature is above 10 °C or there was significant loss (more than 10 mL) of the sample during shipping, make an appropriate notation in the record and invalidate the sample. Prepare the samples for analysis as follows:</P>
          <P>1. For 30-minute or 1-hour samples: Quantitatively transfer the entire 10 mL amount of absorbing solution to a 25-mL volumetric flask and rinse with a small amount (&lt;5 mL) of distilled water.</P>

          <P>2. For 24-hour samples: If the volume of the sample is less than the original 50-mL volume (permanent mark on the absorber), adjust the volume back to the original volume with distilled water to compensate for water lost to evaporation during sampling. If the final volume is greater than the original volume, the volume must be measured using a graduated cylinder. To analyze, pipet 10 mL <PRTPAGE P="22"/>of the solution into a 25-mL volumetric flask.</P>
          <P>11.2 <E T="03">Sample Analysis.</E> For each set of determinations, prepare a reagent blank by adding 10 mL TCM absorbing solution to a 25-mL volumetric flask, and two control standards containing approximately 5 and 15 µg SO<E T="52">2</E>, respectively. The control standards are prepared according to Section 10.2 or 10.3. The analysis is carried out as follows:</P>
          <P>1. Allow the sample to stand 20 minutes after the completion of sampling to allow any ozone to decompose (if applicable).</P>
          <P>2. To each 25-mL volumetric flask containing reagent blank, sample, or control standard, add 1 mL of 0.6% sulfamic acid (Section 8.2.1) and allow to react for 10 min.</P>
          <P>3. Accurately pipet 2 mL of 0.2% formaldehyde solution (Section 8.2.2) and then 5 mL of pararosaniline solution (Section 8.2.13) into each flask. Start a laboratory timer set at 30 minutes.</P>
          <P>4. Bring each flask to volume with recently boiled and cooled distilled water and mix thoroughly.</P>
          <P>5. During the 30 minutes, the solutions must be in a temperature controlled environment in the range of 20° to 30 °C maintained to ±1 °C. This temperature must also be within 1 °C of that used during calibration.</P>

          <P>6. After 30 minutes and before 60 minutes, determine the corrected absorbances (equation 10) of each solution at 548 nm using 1-cm optical path length cells against a distilled water reference (Section 10.1). (<E T="03">Distilled water is used as a reference instead of the reagent blank because of the sensitivity of the reagent blank to temperature.)</E>
          </P>
          <P>7. Do not allow the colored solution to stand in the cells because a film may be deposited. Clean the cells with isopropyl alcohol after use.</P>
          <P>8. The reagent blank must be within 0.03 absorbance units of the intercept of the calibration equation determined in Section 10.</P>
          <P>11.3 <E T="03">Absorbance range.</E> If the absorbance of the sample solution ranges between 1.0 and 2.0, the sample can be diluted 1:1 with a portion of the reagent blank and the absorbance redetermined within 5 minutes. Solutions with higher absorbances can be diluted up to sixfold with the reagent blank in order to obtain scale readings of less than 1.0 absorbance unit. However, it is recommended that a smaller portion (&lt;10 mL) of the original sample be reanalyzed (if possible) if the sample requires a dilution greater than 1:1.</P>
          <P>11.4 <E T="03">Reaqent disposal.</E> All reagents containing mercury compounds must be stored and disposed of using one of the procedures contained in Section 13. Until disposal, the discarded solutions can be stored in closed glass containers and should be left in a fume hood.</P>
          <P>12.0 <E T="03">Calculations.</E>
          </P>
          <P>12.1 <E T="03">Calibration Slope, Intercept, and Correlation Coefficient.</E> The method of least squares is used to calculate a calibration equation in the form of:</P>
          <MATH DEEP="12" SPAN="1">
            <MID>EC08NO91.012</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">y = corrected absorbance,</FP>
          <FP SOURCE="FP-1">m = slope, absorbance unit/µg SO<E T="52">2</E>,</FP>
          <FP SOURCE="FP-1">x = micrograms of SO<E T="52">2</E>,</FP>
          <FP SOURCE="FP-1">b = y intercept (absorbance units).</FP>
          
          <P>The slope (m), intercept (b), and correlation coefficient (r) are calculated as follows:</P>
          <MATH DEEP="22" SPAN="1">
            <MID>ER31AU93.018</MID>
          </MATH>
          <MATH DEEP="21" SPAN="1">
            <MID>ER31AU93.019</MID>
          </MATH>
          <MATH DEEP="25" SPAN="1">
            <MID>ER31AU93.020</MID>
          </MATH>
          <FP>where n is the number of calibration points.</FP>
          <P>A data form (Figure 5) is supplied for easily organizing calibration data when the slope, intercept, and correlation coefficient are calculated by hand.</P>
          <P>12.2 <E T="03">Total Sample Volume.</E> Determine the sampling volume at standard conditions as follows:</P>
          <MATH DEEP="25" SPAN="1">
            <MID>ER31AU93.021</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">V<E T="52">std</E> = sampling volume in std L,</FP>
          <FP SOURCE="FP-1">Q<E T="52">i</E> = standard flow rate determined at the initiation of sampling in std L/min,</FP>
          <FP SOURCE="FP-1">Q<E T="52">f</E> = standard flow rate determined at the completion of sampling is std L/min, and</FP>
          <FP SOURCE="FP-1">t = total sampling time, min.</FP>
          
          <P>12.3 <E T="03">Sulfur Dioxide Concentration.</E> Calculate and report the concentration of each sample as follows:</P>
          <MATH DEEP="32" SPAN="1">
            <MID>ER31AU93.022</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">A = corrected absorbance of the sample solution, from equation (10);</FP>
          <FP SOURCE="FP-1">A<E T="52">o</E> = corrected absorbance of the reagent blank, using equation (10);</FP>
          <FP SOURCE="FP-1">B<E T="52">X</E> = calibration factor equal to B<E T="52">s</E>, B<E T="52">g</E>, or B<E T="52">t</E> depending on the calibration procedure used, the reciprocal of the slope of the calibration equation;</FP>
          <FP SOURCE="FP-1">V<E T="52">a</E> = volume of absorber solution analyzed, mL;</FP>
          <FP SOURCE="FP-1">V<E T="52">b</E> = total volume of solution in absorber (see 11.1-2), mL; and</FP>
          <FP SOURCE="FP-1">V<E T="52">std</E> = standard air volume sampled, std L (from Section 12.2).<PRTPAGE P="23"/>
          </FP>
          <GPOTABLE CDEF="s5,r5,r5,r5,r5,4" COLS="6" OPTS="L2">
            <TTITLE>Data Form</TTITLE>
            <TDESC>[For hand calculations]</TDESC>
            <BOXHD>
              <CHED H="1">Calibration point no.</CHED>
              <CHED H="1">Micro- grams So<E T="52">2</E>
              </CHED>
              <CHED H="1">Absor- bance units</CHED>
              <CHED H="1"/>
              <CHED H="1"/>
              <CHED H="1"/>
            </BOXHD>
            <ROW>
              <ENT I="22"/>
              <ENT O="oi0">(x)</ENT>
              <ENT O="oi0">(y)</ENT>
              <ENT O="oi0">x<SU>2</SU>
              </ENT>
              <ENT O="oi0">xy</ENT>
              <ENT O="oi0">y<SU>2</SU>
              </ENT>
            </ROW>
            <ROW>
              <ENT I="01">1</ENT>
              <ENT/>
              <ENT/>
              <ENT/>
              <ENT/>
              <ENT/>
            </ROW>
            <ROW>
              <ENT I="01">2</ENT>
              <ENT/>
              <ENT/>
              <ENT/>
              <ENT/>
              <ENT/>
            </ROW>
            <ROW>
              <ENT I="01">3</ENT>
              <ENT/>
              <ENT/>
              <ENT/>
              <ENT/>
              <ENT/>
            </ROW>
            <ROW>
              <ENT I="01">4</ENT>
              <ENT/>
              <ENT/>
              <ENT/>
              <ENT/>
              <ENT/>
            </ROW>
            <ROW>
              <ENT I="01">5</ENT>
              <ENT/>
              <ENT/>
              <ENT/>
              <ENT/>
              <ENT/>
            </ROW>
            <ROW>
              <ENT I="01">6</ENT>
              <ENT/>
              <ENT/>
              <ENT/>
              <ENT/>
              <ENT/>
            </ROW>
          </GPOTABLE>
          <FP>Σ x=___Σ y=___Σ x<SU>2</SU>=___Σxy___Σy<SU>2</SU>___</FP>
          <FP>n=___ (number of pairs of coordinates.)</FP>
          <FP SOURCE="FP-DASH"/>
          
          <FP>
            <E T="04">Figure 5.</E> Data form for hand calculations.</FP>
          

          <P>12.4 Control Standards. Calculate the analyzed micrograms of SO<E T="52">2</E> in each control standard as follows:</P>
          <MATH DEEP="15" SPAN="1">
            <MID>EC08NO91.070</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">C<E T="52">q</E> = analyzed µg SO<E T="52">2</E> in each control standard,</FP>
          <FP SOURCE="FP-1">A = corrected absorbance of the control standard, and</FP>
          <FP SOURCE="FP-1">A<E T="52">o</E> = corrected absorbance of the reagent blank.</FP>
          
          <P>The difference between the true and analyzed values of the control standards must not be greater than 1 µg. If the difference is greater than 1 µg, the source of the discrepancy must be identified and corrected.</P>

          <P>12.5 Conversion of µg/m<SU>3</SU> to ppm (v/v). If desired, the concentration of sulfur dioxide at reference conditions can be converted to ppm SO<E T="52">2</E> (v/v) as follows:</P>
          <MATH DEEP="25" SPAN="1">
            <MID>ER31AU93.023</MID>
          </MATH>
          <P>13.0 The TCM absorbing solution and any reagents containing mercury compounds must be treated and disposed of by one of the methods discussed below. Both methods remove greater than 99.99 percent of the mercury.</P>
          <P>13.1 <E T="03">Disposal of Mercury-Containing Solutions.</E>
          </P>
          <P>13.2 <E T="03">Method for Forming an Amalgam.</E>
          </P>
          <P>1. Place the waste solution in an uncapped vessel in a hood.</P>
          <P>2. For each liter of waste solution, add approximately 10 g of sodium carbonate until neutralization has occurred (NaOH may have to be used).</P>
          <P>3. Following neutralization, add 10 g of granular zinc or magnesium.</P>
          <P>4. Stir the solution in a hood for 24 hours. Caution must be exercised as hydrogen gas is evolved by this treatment process.</P>
          <P>5. After 24 hours, allow the solution to stand without stirring to allow the mercury amalgam (solid black material) to settle to the bottom of the waste receptacle.</P>
          <P>6. Upon settling, decant and discard the supernatant liquid.</P>
          <P>7. Quantitatively transfer the solid material to a container and allow to dry.</P>
          <P>8. The solid material can be sent to a mercury reclaiming plant. It must not be discarded.</P>
          <P>13.3 <E T="03">Method Using Aluminum Foil Strips.</E>
          </P>
          <P>1. Place the waste solution in an uncapped vessel in a hood.</P>
          <P>2. For each liter of waste solution, add approximately 10 g of aluminum foil strips. If all the aluminum is consumed and no gas is evolved, add an additional 10 g of foil. Repeat until the foil is no longer consumed and allow the gas to evolve for 24 hours.</P>
          <P>3. Decant the supernatant liquid and discard.</P>
          <P>4. Transfer the elemental mercury that has settled to the bottom of the vessel to a storage container.</P>
          <P>5. The mercury can be sent to a mercury reclaiming plant. It must not be discarded.</P>
          <P>14.0 <E T="03">References for SO</E>
            <E T="52">2</E>
            <E T="03">Method.</E>
          </P>
          <P>1. Quality Assurance Handbook for Air Pollution Measurement Systems, Volume I, Principles. EPA-600/9-76-005, U.S. Environmental Protection Agency, Research Triangle Park, NC 27711, 1976.</P>
          <P>2. Quality Assurance Handbook for Air Pollution Measurement Systems, Volume II, Ambient Air Specific Methods. EPA-600/4-77-027a, U.S. Environmental Protection Agency, Research Triangle Park, NC 27711, 1977.</P>

          <P>3. Dasqupta, P. K., and K. B. DeCesare. Stability of Sulfur Dioxide in Formaldehyde and Its Anomalous Behavior in Tetrachloromercurate (II). Submitted for publication in <E T="03">Atmospheric Environment,</E> 1982.</P>
          <P>4. West, P. W., and G. C. Gaeke. Fixation of Sulfur Dioxide as Disulfitomercurate (II) and Subsequent Colorimetric Estimation. Anal. Chem., 28:1816, 1956.</P>
          <P>5. Ephraim, F. Inorganic Chemistry. P. C. L. Thorne and E. R. Roberts, Eds., 5th Edition, Interscience, 1948, p. 562.</P>
          <P>6. Lyles, G. R., F. B. Dowling, and V. J. Blanchard. Quantitative Determination of Formaldehyde in the Parts Per Hundred Million Concentration Level. J. Air. Poll. Cont. Assoc., Vol. 15(106), 1965.</P>
          <P>7. McKee, H. C., R. E. Childers, and O. Saenz, Jr. Collaborative Study of Reference Method for Determination of Sulfur Dioxide in the Atmosphere (Pararosaniline Method). EPA-APTD-0903, U.S. Environmental Protection Agency, Research Triangle Park, NC 27711, September 1971.</P>

          <P>8. Urone, P., J. B. Evans, and C. M. Noyes. Tracer Techniques in Sulfur—Air Pollution Studies Apparatus and Studies of Sulfur Dioxide Colorimetric and Conductometric Methods. Anal. Chem., 37: 1104, 1965.<PRTPAGE P="24"/>
          </P>
          <P>9. Bostrom, C. E. The Absorption of Sulfur Dioxide at Low Concentrations (pphm) Studied by an Isotopic Tracer Method. Intern. J. Air Water Poll., 9:333, 1965.</P>
          <P>10. Scaringelli, F. P., B. E. Saltzman, and S. A. Frey. Spectrophotometric Determination of Atmospheric Sulfur Dioxide. Anal. Chem., 39: 1709, 1967.</P>
          <P>11. Pate, J. B., B. E. Ammons, G. A. Swanson, and J. P. Lodge, Jr. Nitrite Interference in Spectrophotometric Determination of Atmospheric Sulfur Dioxide. Anal. Chem., 37:942, 1965.</P>
          <P>12. Zurlo, N., and A. M. Griffini. Measurement of the Sulfur Dioxide Content of the Air in the Presence of Oxides of Nitrogen and Heavy Metals. Medicina Lavoro, 53:330, 1962.</P>
          <P>13. Rehme, K. A., and F. P. Scaringelli. Effect of Ammonia on the Spectrophotometric Determination of Atmospheric Concentrations of Sulfur Dioxide. Anal. Chem., 47:2474, 1975.</P>
          <P>14. McCoy, R. A., D. E. Camann, and H. C. McKee. Collaborative Study of Reference Method for Determination of Sulfur Dioxide in the Atmosphere (Pararosaniline Method) (24-Hour Sampling). EPA-650/4-74-027, U.S. Environmental Protection Agency, Research Triangle Park, NC 27711, December 1973.</P>
          <P>15. Fuerst, R. G. Improved Temperature Stability of Sulfur Dioxide Samples Collected by the Federal Reference Method. EPA-600/4-78-018, U.S. Environmental Protection Agency, Research Triangle Park, NC 27711, April 1978.</P>
          <P>16. Scaringelli, F. P., L. Elfers, D. Norris, and S. Hochheiser. Enhanced Stability of Sulfur Dioxide in Solution. Anal. Chem., 42:1818, 1970.</P>
          <P>17. Martin, B. E. Sulfur Dioxide Bubbler Temperature Study. EPA-600/4-77-040, U.S. Environmental Protection Agency, Research Triangle Park, NC 27711, August 1977.</P>
          <P>18. American Society for Testing and Materials. ASTM Standards, Water; Atmospheric Analysis. Part 23. Philadelphia, PA, October 1968, p. 226.</P>
          <P>19. O'Keeffe, A. E., and G. C. Ortman. Primary Standards for Trace Gas Analysis. Anal. Chem., 38:760, 1966.</P>
          <P>20. Scaringelli, F. P., S. A. Frey, and B. E. Saltzman. Evaluation of Teflon Permeation Tubes for Use with Sulfur Dioxide. Amer. Ind. Hygiene Assoc. J., 28:260, 1967.</P>
          <P>21. Scaringelli, F. P., A. E. O'Keeffe, E. Rosenberg, and J. P. Bell, Preparation of Known Concentrations of Gases and Vapors With Permeation Devices Calibrated Gravimetrically. Anal. Chem., 42:871, 1970.</P>
          <P>22. A Procedure for Establishing Traceability of Gas Mixtures to Certain National Bureau of Standards Standard Reference Materials. EPA-600/7-81-010, U.S. Environmental Protection Agency, Environmental Monitoring Systems Laboratory (MD-77), Research Triangle Park, NC 27711, January 1981.</P>
          <CITA>[47 FR 54899, Dec. 6, 1982; 48 FR 17355, Apr. 22, 1983]</CITA>
        </APPENDIX>
        <APPENDIX>
          <EAR>Pt. 50, App. B</EAR>
          <HD SOURCE="HED">Appendix B to Part 50—Reference Method for the Determination of Suspended Particulate Matter in the Atmosphere (High-Volume Method)</HD>
          <P>1.0 <E T="03">Applicability.</E>
          </P>
          <P>1.1 This method provides a measurement of the mass concentration of total suspended particulate matter (TSP) in ambient air for determining compliance with the primary and secondary national ambient air quality standards for particulate matter as specified in § 50.6 and § 50.7 of this chapter. The measurement process is nondestructive, and the size of the sample collected is usually adequate for subsequent chemical analysis. Quality assurance procedures and guidance are provided in part 58, appendixes A and B, of this chapter and in References 1 and 2.</P>
          <P>2.0 <E T="03">Principle.</E>
          </P>

          <P>2.1 An air sampler, properly located at the measurement site, draws a measured quantity of ambient air into a covered housing and through a filter during a 24-hr (nominal) sampling period. The sampler flow rate and the geometry of the shelter favor the collection of particles up to 25-50 µm (aerodynamic diameter), depending on wind speed and direction.(<E T="03">3</E>) The filters used are specified to have a minimum collection efficiency of 99 percent for 0.3 µm (DOP) particles (see Section 7.1.4).</P>
          <P>2.2 The filter is weighed (after moisture equilibration) before and after use to determine the net weight (mass) gain. The total volume of air sampled, corrected to EPA standard conditions (25 °C, 760 mm Hg [101 kPa]), is determined from the measured flow rate and the sampling time. The concentration of total suspended particulate matter in the ambient air is computed as the mass of collected particles divided by the volume of air sampled, corrected to standard conditions, and is expressed in micrograms per standard cubic meter (µg/std m<SU>3</SU>). For samples collected at temperatures and pressures significantly different than standard conditions, these corrected concentrations may differ substantially from actual concentrations (micrograms per actual cubic meter), particularly at high elevations. The actual particulate matter concentration can be calculated from the corrected concentration using the actual temperature and pressure during the sampling period.</P>
          <P>3.0 <E T="03">Range.</E>
          </P>

          <P>3.1 The approximate concentration range of the method is 2 to 750 µg/std m<SU>3</SU>. The upper limit is determined by the point at which the sampler can no longer maintain the specified <PRTPAGE P="25"/>flow rate due to the increased pressure drop of the loaded filter. This point is affected by particle size distribution, moisture content of the collected particles, and variability from filter to filter, among other things. The lower limit is determined by the sensitivity of the balance (see Section 7.10) and by inherent sources of error (see Section 6).</P>

          <P>3.2 At wind speeds between 1.3 and 4.5 m/sec (3 and 10 mph), the high-volume air sampler has been found to collect particles up to 25 to 50 µm, depending on wind speed and direction.(<E T="03">3</E>) For the filter specified in Section 7.1, there is effectively no lower limit on the particle size collected.</P>
          <P>4.0 <E T="03">Precision.</E>
          </P>

          <P>4.1 Based upon collaborative testing, the relative standard deviation (coefficient of variation) for single analyst precision (repeatability) of the method is 3.0 percent. The corresponding value for interlaboratory precision (reproducibility) is 3.7 percent.(<E T="03">4</E>)</P>
          <P>5.0 <E T="03">Accuracy.</E>
          </P>
          <P>5.1 The absolute accuracy of the method is undefined because of the complex nature of atmospheric particulate matter and the difficulty in determining the “true” particulate matter concentration. This method provides a measure of particulate matter concentration suitable for the purpose specified under Section 1.0, Applicability.</P>
          <P>6.0 <E T="03">Inherent Sources of Error.</E>
          </P>
          <P>6.1 <E T="03">Airflow variation.</E> The weight of material collected on the filter represents the (integrated) sum of the product of the instantaneous flow rate times the instantaneous particle concentration. Therefore, dividing this weight by the average flow rate over the sampling period yields the true particulate matter concentration only when the flow rate is constant over the period. The error resulting from a nonconstant flow rate depends on the magnitude of the instantaneous changes in the flow rate and in the particulate matter concentration. Normally, such errors are not large, but they can be greatly reduced by equipping the sampler with an automatic flow controlling mechanism that maintains constant flow during the sampling period. Use of a contant flow controller is recommended.*<FTREF/>
          </P>
          <FTNT>
            <P>*At elevated altitudes, the effectiveness of automatic flow controllers may be reduced because of a reduction in the maximum sampler flow.</P>
          </FTNT>
          <P>6.2 <E T="03">Air volume measurement.</E> If the flow rate changes substantially or nonuniformly during the sampling period, appreciable error in the estimated air volume may result from using the average of the presampling and postsampling flow rates. Greater air volume measurement accuracy may be achieved by (1) equipping the sampler with a flow controlling mechanism that maintains constant air flow during the sampling period,* (2) using a calibrated, continuous flow rate recording device to record the actual flow rate during the samping period and integrating the flow rate over the period, or (3) any other means that will accurately measure the total air volume sampled during the sampling period. Use of a continuous flow recorder is recommended, particularly if the sampler is not equipped with a constant flow controller.</P>
          <P>6.3 <E T="03">Loss of volatiles.</E> Volatile particles collected on the filter may be lost during subsequent sampling or during shipment and/or storage of the filter prior to the postsampling weighing.(<E T="03">5</E>) Although such losses are largely unavoidable, the filter should be reweighed as soon after sampling as practical.</P>
          <P>6.4 <E T="03">Artifact particulate matter.</E> Artifact particulate matter can be formed on the surface of alkaline glass fiber filters by oxidation of acid gases in the sample air, resulting in a higher than true TSP determination.(<E T="03">6 7</E>) This effect usually occurs early in the sample period and is a function of the filter pH and the presence of acid gases. It is generally believed to account for only a small percentage of the filter weight gain, but the effect may become more significant where relatively small particulate weights are collected.</P>
          <P>6.5 <E T="03">Humidity.</E> Glass fiber filters are comparatively insensitive to changes in relative humidity, but collected particulate matter can be hygroscopic.(<E T="03">8</E>) The moisture conditioning procedure minimizes but may not completely eliminate error due to moisture.</P>
          <P>6.6 <E T="03">Filter handling.</E> Careful handling of the filter between the presampling and postsampling weighings is necessary to avoid errors due to loss of fibers or particles from the filter. A filter paper cartridge or cassette used to protect the filter can minimize handling errors. (See Reference 2, Section 2).</P>
          <P>6.7 <E T="03">Nonsampled particulate matter.</E> Particulate matter may be deposited on the filter by wind during periods when the sampler is inoperative. (<E T="03">9</E>) It is recommended that errors from this source be minimized by an automatic mechanical device that keeps the filter covered during nonsampling periods, or by timely installation and retrieval of filters to minimize the nonsampling periods prior to and following operation.</P>
          <P>6.8 <E T="03">Timing errors.</E> Samplers are normally controlled by clock timers set to start and stop the sampler at midnight. Errors in the nominal 1,440-min sampling period may result from a power interruption during the sampling period or from a discrepancy between the start or stop time recorded on the filter information record and the actual start or stop time of the sampler. Such discrepancies may be caused by (1) poor resolution of the timer set-points, (2) timer error due to power interruption, (3) missetting of <PRTPAGE P="26"/>the timer, or (4) timer malfunction. In general, digital electronic timers have much better set-point resolution than mechanical timers, but require a battery backup system to maintain continuity of operation after a power interruption. A continuous flow recorder or elapsed time meter provides an indication of the sampler run-time, as well as indication of any power interruption during the sampling period and is therefore recommended.</P>
          <P>6.9 <E T="03">Recirculation of sampler exhaust.</E> Under stagnant wind conditions, sampler exhaust air can be resampled. This effect does not appear to affect the TSP measurement substantially, but may result in increased carbon and copper in the collected sample. (<E T="03">10</E>) This problem can be reduced by ducting the exhaust air well away, preferably downwind, from the sampler.</P>
          <P>7.0 <E T="03">Apparatus.</E>
          </P>
          <P>(See References 1 and 2 for quality assurance information.)</P>
          <NOTE>
            <HD SOURCE="HED">Note:</HD>
            <P>Samplers purchased prior to the effective date of this amendment are not subject to specifications preceded by (†).</P>
          </NOTE>
          <P>7.1 <E T="03">Filter.</E> (Filters supplied by the Environmental Protection Agency can be assumed to meet the following criteria. Additional specifications are required if the sample is to be analyzed chemically.)</P>
          <P>7.1.1 <E T="03">Size:</E> 20.3 ± 0.2 × 25.4 ± 0.2 cm (nominal 8 × 10 in).</P>
          <P>7.1.2 <E T="03">Nominal exposed area:</E> 406.5 cm<SU>2</SU> (63 in<SU>2</SU>).</P>
          <P>7.1.3. <E T="03">Material:</E> Glass fiber or other relatively inert, nonhygroscopic material. (<E T="03">8</E>)</P>
          <P>7.1.4 <E T="03">Collection efficiency:</E> 99 percent minimum as measured by the DOP test (ASTM-2986) for particles of 0.3 µm diameter.</P>
          <P>7.1.5 <E T="03">Recommended pressure drop range:</E> 42-54 mm Hg (5.6-7.2 kPa) at a flow rate of 1.5 std m<SU>3</SU>/min through the nominal exposed area.</P>
          <P>7.1.6 <E T="03">pH:</E> 6 to 10. (<E T="03">11</E>)</P>
          <P>7.1.7 <E T="03">Integrity:</E> 2.4 mg maximum weight loss. (<E T="03">11</E>)</P>
          <P>7.1.8 <E T="03">Pinholes:</E> None.</P>
          <P>7.1.9 <E T="03">Tear strength:</E> 500 g minimum for 20 mm wide strip cut from filter in weakest dimension. (See ASTM Test D828-60).</P>
          <P>7.1.10 <E T="03">Brittleness:</E> No cracks or material separations after single lengthwise crease.</P>
          <P>7.2 <E T="03">Sampler.</E> The air sampler shall provide means for drawing the air sample, via reduced pressure, through the filter at a uniform face velocity.</P>
          <P>7.2.1 The sampler shall have suitable means to:</P>
          <P>a. Hold and seal the filter to the sampler housing.</P>
          <P>b. Allow the filter to be changed conveniently.</P>
          <P>c. Preclude leaks that would cause error in the measurement of the air volume passing through the filter.</P>
          <P>d. (†)<FTREF/> Manually adjust the flow rate to accommodate variations in filter pressure drop and site line voltage and altitude. The adjustment may be accomplished by an automatic flow controller or by a manual flow adjustment device. Any manual adjustment device must be designed with positive detents or other means to avoid unintentional changes in the setting.</P>
          <FTNT>
            <P>(†) See note at beginning of Section 7 of this appendix.</P>
          </FTNT>
          <P>7.2.2 <E T="03">Minimum sample flow rate, heavily loaded filter:</E> 1.1 m<SU>3</SU>/min (39 ft<SU>3</SU>/min).‡<FTREF/>
          </P>
          <FTNT>

            <P>‡ These specifications are in actual air volume units; to convert to EPA standard air volume units, multiply the specifications by (P<E T="52">b</E>/P<E T="52">std</E>)(298/T) where P<E T="52">b</E> and T are the barometric pressure in mm Hg (or kPa) and the temperature in K at the sampler, and P<E T="52">std</E> is 760 mm Hg (or 101 kPa).</P>
          </FTNT>
          <P>7.2.3 <E T="03">Maximum sample flow rate, clean filter:</E> 1.7 m<SU>3</SU>/min (60 ft<SU>3</SU>/min).‡</P>
          <P>7.2.4 <E T="03">Blower Motor:</E> The motor must be capable of continuous operation for 24-hr periods.</P>
          <P>7.3 <E T="03">Sampler shelter.</E>
          </P>
          <P>7.3.1 The sampler shelter shall:</P>
          <P>a. Maintain the filter in a horizontal position at least 1 m above the sampler supporting surface so that sample air is drawn downward through the filter.</P>
          <P>b. Be rectangular in shape with a gabled roof, similar to the design shown in Figure 1.</P>
          <P>c. Cover and protect the filter and sampler from precipitation and other weather.</P>
          <P>d. Discharge exhaust air at least 40 cm from the sample air inlet.</P>
          <P>e. Be designed to minimize the collection of dust from the supporting surface by incorporating a baffle between the exhaust outlet and the supporting surface.</P>

          <P>7.3.2 The sampler cover or roof shall overhang the sampler housing somewhat, as shown in Figure 1, and shall be mounted so as to form an air inlet gap between the cover and the sampler housing walls. <E T="51">†</E> This sample air inlet should be approximately uniform on all sides of the sampler. <E T="51">†</E> The area of the sample air inlet must be sized to provide an effective particle capture air velocity of between 20 and 35 cm/sec at the recommended operational flow rate. The capture velocity is the sample air flow rate divided by the inlet area measured in a horizontal plane at the lower edge of the cover. <E T="51">†</E> Ideally, the inlet area and operational flow rate should be selected to obtain a capture air velocity of 25 ±2 cm/sec.</P>
          <P>7.4 <E T="03">Flow rate measurement devices.</E>
          </P>

          <P>7.4.1 The sampler shall incorporate a flow rate measurement device capable of indicating the total sampler flow rate. Two common types of flow indicators covered in the calibration procedure are (1) an electronic mass flowmeter and (2) an orifice or orifices <PRTPAGE P="27"/>located in the sample air stream together with a suitable pressure indicator such as a manometer, or aneroid pressure gauge. A pressure recorder may be used with an orifice to provide a continuous record of the flow. Other types of flow indicators (including rotameters) having comparable precision and accuracy are also acceptable.</P>
          <P>7.4.2 † The flow rate measurement device must be capable of being calibrated and read in units corresponding to a flow rate which is readable to the nearest 0.02 std m<SU>3</SU>/min over the range 1.0 to 1.8 std m<SU>3</SU>/min.</P>
          <P>7.5 <E T="03">Thermometer,</E> to indicate the approximate air temperature at the flow rate measurement orifice, when temperature corrections are used.</P>
          <P>7.5.1 <E T="03">Range:</E> −40° to +50 °C (223-323 K).</P>
          <P>7.5.2 <E T="03">Resolution:</E> 2 °C (2 K).</P>
          <P>7.6 <E T="03">Barometer,</E> to indicate barometric pressure at the flow rate measurement orifice, when pressure corrections are used.</P>
          <P>7.6.1 <E T="03">Range:</E> 500 to 800 mm Hg (66-106 kPa).</P>
          <P>7.6.2 <E T="03">Resolution:</E> ±5 mm Hg (0.67 kPa).</P>
          <P>7.7 <E T="03">Timing/control device.</E>
          </P>
          <P>7.7.1 The timing device must be capable of starting and stopping the sampler to obtain an elapsed run-time of 24 hr ±1 hr (1,440 ±60 min).</P>
          <P>7.7.2 <E T="03">Accuracy of time setting:</E> ±30 min, or better. (See Section 6.8).</P>
          <P>7.8 <E T="03">Flow rate transfer standard,</E> traceable to a primary standard. (See Section 9.2.)</P>
          <P>7.8.1 <E T="03">Approximate range:</E> 1.0 to 1.8 m<SU>3</SU>/min.</P>
          <P>7.8.2 <E T="03">Resolution:</E> 0.02 m<SU>3</SU>/min.</P>
          <P>7.8.3 <E T="03">Reproducibility:</E> ±2 percent (2 times coefficient of variation) over normal ranges of ambient temperature and pressure for the stated flow rate range. (See Reference 2, Section 2.)</P>
          <P>7.8.4 <E T="03">Maximum pressure drop at 1.7 std m</E>
            <SU>3</SU>/min; 50 cm H<E T="52">2</E> O (5 kPa).</P>
          <P>7.8.5 The flow rate transfer standard must connect without leaks to the inlet of the sampler and measure the flow rate of the total air sample.</P>
          <P>7.8.6 The flow rate transfer standard must include a means to vary the sampler flow rate over the range of 1.0 to 1.8 m<SU>3</SU>/min (35-64 ft<SU>3</SU>/min) by introducing various levels of flow resistance between the sampler and the transfer standard inlet.</P>
          <P>7.8.7 The conventional type of flow transfer standard consists of: An orifice unit with adapter that connects to the inlet of the sampler, a manometer or other device to measure orifice pressure drop, a means to vary the flow through the sampler unit, a thermometer to measure the ambient temperature, and a barometer to measure ambient pressure. Two such devices are shown in Figures 2a and 2b. Figure 2a shows multiple fixed resistance plates, which necessitate disassembly of the unit each time the flow resistance is changed. A preferable design, illustrated in Figure 2b, has a variable flow restriction that can be adjusted externally without disassembly of the unit. Use of a conventional, orifice-type transfer standard is assumed in the calibration procedure (Section 9). However, the use of other types of transfer standards meeting the above specifications, such as the one shown in Figure 2c, may be approved; see the note following Section 9.1.</P>
          <P>7.9 <E T="03">Filter conditioning environment</E>
          </P>
          <P>7.9.1 <E T="03">Controlled temperature:</E> between 15° and 30 °C with less than ±3 °C variation during equilibration period.</P>
          <P>7.9.2 <E T="03">Controlled humidity:</E> Less than 50 percent relative humidity, constant within ±5 percent.</P>
          <P>7.10 <E T="03">Analytical balance.</E>
          </P>
          <P>7.10.1 <E T="03">Sensitivity:</E> 0.1 mg.</P>
          <P>7.10.2 Weighing chamber designed to accept an unfolded 20.3×25.4 cm (8×10 in) filter.</P>
          <P>7.11 <E T="03">Area light source,</E> similar to X-ray film viewer, to backlight filters for visual inspection.</P>
          <P>7.12 <E T="03">Numbering device,</E> capable of printing identification numbers on the filters before they are placed in the filter conditioning environment, if not numbered by the supplier.</P>
          <P>8.0 <E T="03">Procedure.</E>
          </P>
          <P>(See References 1 and 2 for quality assurance information.)</P>
          <P>8.1 Number each filter, if not already numbered, near its edge with a unique identification number.</P>
          <P>8.2 Backlight each filter and inspect for pinholes, particles, and other imperfections; filters with visible imperfections must not be used.</P>
          <P>8.3 Equilibrate each filter in the conditioning environment for at least 24-hr.</P>

          <P>8.4 Following equilibration, weigh each filter to the nearest milligram and record this tare weight (W<E T="52">i</E>) with the filter identification number.</P>
          <P>8.5 Do not bend or fold the filter before collection of the sample.</P>
          <P>8.6 Open the shelter and install a numbered, preweighed filter in the sampler, following the sampler manufacturer's instructions. During inclement weather, precautions must be taken while changing filters to prevent damage to the clean filter and loss of sample from or damage to the exposed filter. Filter cassettes that can be loaded and unloaded in the laboratory may be used to minimize this problem (See Section 6.6).</P>
          <P>8.7 Close the shelter and run the sampler for at least 5 min to establish run-temperature conditions.</P>
          <P>8.8 Record the flow indicator reading and, if needed, the barometric pressure (P<SU>3</SU>
            <E T="52">3</E>) and the ambient temperature (T<SU>3</SU>
            <E T="52">3</E>) see NOTE following step 8.12). Stop the sampler. Determine the sampler flow rate (see Section 10.1); if it is outside the acceptable range (1.1 to 1.7 m<SU>3</SU>/min [39-60 ft<SU>3</SU>/min]), use a different filter, or adjust the sampler flow rate. Warning: Substantial flow adjustments may affect the <PRTPAGE P="28"/>calibration of the orifice-type flow indicators and may necessitate recalibration.</P>
          <P>8.9 Record the sampler identification information (filter number, site location or identification number, sample date, and starting time).</P>
          <P>8.10 Set the timer to start and stop the sampler such that the sampler runs 24-hrs, from midnight to midnight (local time).</P>
          <P>8.11 As soon as practical following the sampling period, run the sampler for at least 5 min to again establish run-temperature conditions.</P>
          <P>8.12 Record the flow indicator reading and, if needed, the barometric pressure (P<SU>3</SU>
            <E T="52">3</E>) and the ambient temperature (T<SU>3</SU>
            <E T="52">3</E>).</P>
          <NOTE>
            <HD SOURCE="HED">Note:</HD>

            <P>No onsite pressure or temperature measurements are necessary if the sampler flow indicator does not require pressure or temperature corrections (e.g., a mass flowmeter) or if average barometric pressure and seasonal average temperature for the site are incorporated into the sampler calibration (see step 9.3.9). For individual pressure and temperature corrections, the ambient pressure and temperature can be obtained by onsite measurements or from a nearby weather station. Barometric pressure readings obtained from airports must be station pressure, not corrected to sea level, and may need to be corrected for differences in elevation between the sampler site and the airport. For samplers having flow recorders but not constant flow controllers, the average temperature and pressure at the site <E T="03">during the sampling period</E> should be estimated from weather bureau or other available data.</P>
          </NOTE>
          <P>8.13 Stop the sampler and carefully remove the filter, following the sampler manufacturer's instructions. Touch only the outer edges of the filter. See the precautions in step 8.6.</P>
          <P>8.14 Fold the filter in half lengthwise so that only surfaces with collected particulate matter are in contact and place it in the filter holder (glassine envelope or manila folder).</P>
          <P>8.15 Record the ending time or elapsed time on the filter information record, either from the stop set-point time, from an elapsed time indicator, or from a continuous flow record. The sample period must be 1,440 ±60 min. for a valid sample.</P>
          <P>8.16 Record on the filter information record any other factors, such as meteorological conditions, construction activity, fires or dust storms, etc., that might be pertinent to the measurement. If the sample is known to be defective, void it at this time.</P>
          <P>8.17 Equilibrate the exposed filter in the conditioning environment for at least 24-hrs.</P>
          <P>8.18 Immediately after equilibration, reweigh the filter to the nearest milligram and record the gross weight with the filter identification number. See Section 10 for TSP concentration calculations.</P>
          <P>9.0 <E T="03">Calibration.</E>
          </P>
          <P>9.1 Calibration of the high volume sampler's flow indicating or control device is necessary to establish traceability of the field measurement to a primary standard via a flow rate transfer standard. Figure 3a illustrates the certification of the flow rate transfer standard and Figure 3b illustrates its use in calibrating a sampler flow indicator. Determination of the corrected flow rate from the sampler flow indicator, illustrated in Figure 3c, is addressed in Section 10.1</P>
          <NOTE>
            <HD SOURCE="HED">Note:</HD>
            <P>The following calibration procedure applies to a conventional orifice-type flow transfer standard and an orifice-type flow indicator in the sampler (the most common types). For samplers using a pressure recorder having a square-root scale, 3 other acceptable calibration procedures are provided in Reference 12. Other types of transfer standards may be used if the manufacturer or user provides an appropriately modified calibration procedure that has been approved by EPA under Section 2.8 of appendix C to part 58 of this chapter.</P>
          </NOTE>
          <P>9.2 <E T="03">Certification of the flow rate transfer standard.</E>
          </P>
          <P>9.2.1 <E T="03">Equipment required:</E> Positive displacement standard volume meter traceable to the National Bureau of Standards (such as a Roots meter or equivalent), stop-watch, manometer, thermometer, and barometer.</P>
          <P>9.2.2 Connect the flow rate transfer standard to the inlet of the standard volume meter. Connect the manometer to measure the pressure at the inlet of the standard volume meter. Connect the orifice manometer to the pressure tap on the transfer standard. Connect a high-volume air pump (such as a high-volume sampler blower) to the outlet side of the standard volume meter. See Figure 3a.</P>
          <P>9.2.3 Check for leaks by temporarily clamping both manometer lines (to avoid fluid loss) and blocking the orifice with a large-diameter rubber stopper, wide cellophane tape, or other suitable means. Start the high-volume air pump and note any change in the standard volume meter reading. The reading should remain constant. If the reading changes, locate any leaks by listening for a whistling sound and/or retightening all connections, making sure that all gaskets are properly installed.</P>
          <P>9.2.4 After satisfactorily completing the leak check as described above, unclamp both manometer lines and zero both manometers.</P>

          <P>9.2.5 Achieve the appropriate flow rate through the system, either by means of the variable flow resistance in the transfer standard or by varying the voltage to the air pump. (Use of resistance plates as shown in Figure 1a is discouraged because the above leak check must be repeated each time a new resistance plate is installed.) At least five different but constant flow rates, evenly distributed, with at least three in the specified <PRTPAGE P="29"/>flow rate interval (1.1 to 1.7 m<SU>3</SU>/min [39-60 ft<SU>3</SU>/min]), are required.</P>
          <P>9.2.6 Measure and record the certification data on a form similar to the one illustrated in Figure 4 according to the following steps.</P>
          <P>9.2.7 Observe the barometric pressure and record as P<E T="52">1</E> (item 8 in Figure 4).</P>

          <P>9.2.8 Read the ambient temperature in the vicinity of the standard volume meter and record it as T<E T="52">1</E> (item 9 in Figure 4).</P>
          <P>9.2.9 Start the blower motor, adjust the flow, and allow the system to run for at least 1 min for a constant motor speed to be attained.</P>

          <P>9.2.10 Observe the standard volume meter reading and simultaneously start a stopwatch. Record the initial meter reading (V<E T="52">i</E>) in column 1 of Figure 4.</P>
          <P>9.2.11 Maintain this constant flow rate until at least 3 m<SU>3</SU> of air have passed through the standard volume meter. Record the standard volume meter inlet pressure manometer reading as ΔP (column 5 in Figure 4), and the orifice manometer reading as ΔH (column 7 in Figure 4). Be sure to indicate the correct units of measurement.</P>

          <P>9.2.12 After at least 3 m<SU>3</SU> of air have passed through the system, observe the standard volume meter reading while simultaneously stopping the stopwatch. Record the final meter reading (V<E T="52">f</E>) in column 2 and the elapsed time (t) in column 3 of Figure 4.</P>

          <P>9.2.13 Calculate the volume measured by the standard volume meter at meter conditions of temperature and pressures as V<E T="52">m</E>=V<E T="52">f</E>−V<E T="52">i</E>. Record in column 4 of Figure 4.</P>
          <P>9.2.14 Correct this volume to standard volume (std m<SU>3</SU>) as follows:</P>
          <MATH DEEP="29" SPAN="1">
            <MID>ER31AU93.024</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">V<E T="52">std</E> = standard volume, std m<SU>3</SU>;</FP>
          <FP SOURCE="FP-1">V<E T="52">m</E> = actual volume measured by the standard volume meter;</FP>
          <FP SOURCE="FP-1">P<E T="52">1</E> = barometric pressure during calibration, mm Hg or kPa;</FP>
          <FP SOURCE="FP-1">ΔP = differential pressure at inlet to volume meter, mm Hg or kPa;</FP>
          <FP SOURCE="FP-1">P<E T="52">std</E> = 760 mm Hg or 101 kPa;</FP>
          <FP SOURCE="FP-1">T<E T="52">std</E> = 298 K;</FP>
          <FP SOURCE="FP-1">T<E T="52">1</E> = ambient temperature during calibration, K.</FP>
          <FP SOURCE="FP-1">Calculate the standard flow rate (std m<SU>3</SU>/min) as follows:</FP>
          <MATH DEEP="23" SPAN="1">
            <MID>EC08NO91.013</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">Q<E T="52">std</E> = standard volumetric flow rate, std m<SU>3</SU>/min</FP>
          <FP SOURCE="FP-1">t = elapsed time, minutes.</FP>
          
          <P>Record Q<E T="52">std</E> to the nearest 0.01 std m<SU>3</SU>/min in column 6 of Figure 4.</P>
          <P>9.2.15 Repeat steps 9.2.9 through 9.2.14 for at least four additional constant flow rates, evenly spaced over the approximate range of 1.0 to 1.8 std m<SU>3</SU>/min (35-64 ft<SU>3</SU>/min).</P>
          <P>9.2.16 For each flow, compute
          </P>
          <FP SOURCE="FP-1">√ΔΔH (P<E T="52">1</E>/P<E T="52">std</E>)(298/T<E T="52">1</E>)</FP>
          
          <FP>(column 7a of Figure 4) and plot these value against Q<E T="52">std</E> as shown in Figure 3a. Be sure to use consistent units (mm Hg or kPa) for barometric pressure. Draw the orifice transfer standard certification curve or calculate the linear least squares slope (m) and intercept (b) of the certification curve:</FP>
          
          <FP SOURCE="FP-1">√ΔΔH (P<E T="52">1</E>/P<E T="52">std</E>)(298/T<E T="52">1</E>)</FP>
          
          <FP>=mQ<E T="52">std</E>+b. See Figures 3 and 4. A certification graph should be readable to 0.02 std m<SU>3</SU>/min.</FP>
          <P>9.2.17 Recalibrate the transfer standard annually or as required by applicable quality control procedures. (See Reference 2.)</P>
          <P>9.3 <E T="03">Calibration of sampler flow indicator.</E>
            
          </P>
          <NOTE>
            <HD SOURCE="HED">Note:</HD>
            <P>For samplers equipped with a flow controlling device, the flow controller must be disabled to allow flow changes during calibration of the sampler's flow indicator, or the alternate calibration of the flow controller given in 9.4 may be used. For samplers using an orifice-type flow indicator downstream of the motor, do not vary the flow rate by adjusting the voltage or power supplied to the sampler.</P>
          </NOTE>
          
          <P>9.3.1 A form similar to the one illustrated in Figure 5 should be used to record the calibration data.</P>
          <P>9.3.2 Connect the transfer standard to the inlet of the sampler. Connect the orifice manometer to the orifice pressure tap, as illustrated in Figure 3b. Make sure there are no leaks between the orifice unit and the sampler.</P>
          <P>9.3.3 Operate the sampler for at least 5 minutes to establish thermal equilibrium prior to the calibration.</P>
          <P>9.3.4 Measure and record the ambient temperature, T<E T="52">2</E>, and the barometric pressure, P<E T="52">2</E>, during calibration.</P>
          <P>9.3.5 Adjust the variable resistance or, if applicable, insert the appropriate resistance plate (or no plate) to achieve the desired flow rate.</P>
          <P>9.3.6 Let the sampler run for at least 2 min to re-establish the run-temperature conditions. Read and record the pressure drop across the orifice (ΔH) and the sampler flow rate indication (I) in the appropriate columns of Figure 5.</P>
          <P>9.3.7 Calculate √ΔΔH(P<E T="52">2</E>/P<E T="52">std</E>)(298/T<E T="52">2</E>) and determine the flow rate at standard conditions (Q<E T="52">std</E>) either graphically from the certification curve or by calculating Q<E T="52">std</E> from the least square slope and intercept of the transfer standard's transposed certification curve: Q<E T="52">std</E>=1/m √ΔH(P<E T="52">2</E>/P<E T="52">std</E>)(298/T<E T="52">2</E>)−b. Record the value of Q<E T="52">std</E> on Figure 5.<PRTPAGE P="30"/>
          </P>
          <P>9.3.8 Repeat steps 9.3.5, 9.3.6, and 9.3.7 for several additional flow rates distributed over a range that includes 1.1 to 1.7 std m<SU>3</SU>/min.</P>

          <P>9.3.9 Determine the calibration curve by plotting values of the appropriate expression involving I, selected from table 1, against Q<E T="52">std</E>. The choice of expression from table 1 depends on the flow rate measurement device used (see Section 7.4.1) and also on whether the calibration curve is to incorporate geographic average barometric pressure (P<E T="52">a</E>) and seasonal average temperature (T<E T="52">a</E>) for the site to approximate actual pressure and temperature. Where P<E T="52">a</E> and T<E T="52">a</E> can be determined for a site for a seasonal period such that the actual barometric pressure and temperature at the site do not vary by more than ±60 mm Hg (8 kPa) from P<E T="52">a</E> or ±15 °C from T<E T="52">a</E>, respectively, then using P<E T="52">a</E> and T<E T="52">a</E> avoids the need for subsequent pressure and temperature calculation when the sampler is used. The geographic average barometric pressure (P<E T="52">a</E>) may be estimated from an altitude-pressure table or by making an (approximate) elevation correction of −26 mm Hg (−3.46 kPa) for each 305 m (1,000 ft) above sea level (760 mm Hg or 101 kPa). The seasonal average temperature (T<E T="52">a</E>) may be estimated from weather station or other records. Be sure to use consistent units (mm Hg or kPa) for barometric pressure.</P>

          <P>9.3.10 Draw the sampler calibration curve or calculate the linear least squares slope (m), intercept (b), and correlation coefficient of the calibration curve: [Expression from table 1]= mQ<E T="52">std</E>+b. See Figures 3 and 5. Calibration curves should be readable to 0.02 std m<SU>3</SU>/min.</P>
          <P>9.3.11 For a sampler equipped with a flow controller, the flow controlling mechanism should be re-enabled and set to a flow near the lower flow limit to allow maximum control range. The sample flow rate should be verified at this time with a clean filter installed. Then add two or more filters to the sampler to see if the flow controller maintains a constant flow; this is particularly important at high altitudes where the range of the flow controller may be reduced.</P>
          <P>9.4 Alternate calibration of flow-controlled samplers. A flow-controlled sampler may be calibrated solely at its controlled flow rate, provided that previous operating history of the sampler demonstrates that the flow rate is stable and reliable. In this case, the flow indicator may remain uncalibrated but should be used to indicate any relative change between initial and final flows, and the sampler should be recalibrated more often to minimize potential loss of samples because of controller malfunction.</P>
          <P>9.4.1 Set the flow controller for a flow near the lower limit of the flow range to allow maximum control range.</P>
          <P>9.4.2 Install a clean filter in the sampler and carry out steps 9.3.2, 9.3.3, 9.3.4, 9.3.6, and 9.3.7.</P>
          <P>9.4.3 Following calibration, add one or two additional clean filters to the sampler, reconnect the transfer standard, and operate the sampler to verify that the controller maintains the same calibrated flow rate; this is particularly important at high altitudes where the flow control range may be reduced.</P>
          <GPH DEEP="200" SPAN="2">
            <GID>50-723.eps</GID>
          </GPH>
          <GPH DEEP="217" SPAN="2">
            <PRTPAGE P="31"/>
            <GID>50-724.eps</GID>
          </GPH>
          <P>10.0 <E T="03">Calculations of TSP Concentration.</E>
          </P>
          <P>10.1 Determine the average sampler flow rate during the sampling period according to either 10.1.1 or 10.1.2 below.</P>

          <P>10.1.1 For a sampler without a continuous flow recorder, determine the appropriate expression to be used from table 2 corresponding to the one from table 1 used in step 9.3.9. Using this appropriate expression, determine Q<E T="52">std</E> for the initial flow rate from the sampler calibration curve, either graphically or from the transposed regression equation:
          </P>
          <FP>Q<E T="52">std</E> =</FP>
          <FP>1/m ([Appropriate expression from table 2]−b)</FP>
          
          <FP>Similarly, determine Q<E T="52">std</E> from the final flow reading, and calculate the average flow Q<E T="52">std</E> as one-half the sum of the initial and final flow rates.</FP>

          <P>10.1.2 For a sampler with a continuous flow recorder, determine the average flow rate device reading, I, for the period. Determine the appropriate expression from table 2 corresponding to the one from table 1 used in step 9.3.9. Then using this expression and the average flow rate reading, determine Q<E T="52">std</E> from the sampler calibration curve, either graphically or from the transposed regression equation:
          </P>
          <FP>Q<E T="52">std</E> =</FP>
          
          <FP>1/m ([Appropriate expression from table 2]−b)</FP>

          <P>If the trace shows substantial flow change during the sampling period, greater accuracy may be achieved by dividing the sampling period into intervals and calculating an average reading before determining Q<E T="52">std</E>.</P>
          <P>10.2 Calculate the total air volume sampled as:
          </P>
          <FP SOURCE="FP-1">V−Q<E T="52">std</E>× t</FP>
          
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">V = total air volume sampled, in standard volume units, std m<SU>3</SU>/;</FP>
          <FP SOURCE="FP-1">Q<E T="52">std</E> = average standard flow rate, std m<SU>3</SU>/min;</FP>
          <FP SOURCE="FP-1">t = sampling time, min.</FP>
          
          <P>10.3 Calculate and report the particulate matter concentration as:</P>
          <MATH DEEP="22" SPAN="1">
            <MID>ER31AU93.025</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">TSP = mass concentration of total suspended particulate matter, µg/std m<SU>3</SU>;</FP>
          <FP SOURCE="FP-1">W<E T="52">i</E> = initial weight of clean filter, g;</FP>
          <FP SOURCE="FP-1">W<E T="52">f</E> = final weight of exposed filter, g;</FP>
          <FP SOURCE="FP-1">V = air volume sampled, converted to standard conditions, std m<SU>3</SU>,</FP>
          <FP SOURCE="FP-1">10<SU>6</SU> = conversion of g to µg.</FP>
          

          <P>10.4 If desired, the actual particulate matter concentration (see Section 2.2) can be calculated as follows:
          </P>
          <FP SOURCE="FP-1">(TSP)<E T="52">a</E>=TSP (P<E T="52">3</E>/P<E T="52">std</E>)(298/T<E T="52">3</E>)</FP>
          
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">(TSP)<E T="52">a</E> = actual concentration at field conditions, µg/m<SU>3</SU>;<PRTPAGE P="32"/>
          </FP>
          <FP SOURCE="FP-1">TSP = concentration at standard conditions, µg/std m<SU>3</SU>;</FP>
          <FP SOURCE="FP-1">P<E T="52">3</E> = average barometric pressure during sampling period, mm Hg;</FP>
          <FP SOURCE="FP-1">P<E T="52">std</E> = 760 mn Hg (or 101 kPa);</FP>
          <FP SOURCE="FP-1">T<E T="52">3</E> = average ambient temperature during sampling period, K.</FP>
          
          <P>11.0 <E T="03">References.</E>
          </P>
          <P>1. Quality Assurance Handbook for Air Pollution Measurement Systems, Volume I, Principles. EPA-600/9-76-005, U.S. Environmental Protection Agency, Research Triangle Park, NC 27711, 1976.</P>
          <P>2. Quality Assurance Handbook for Air Pollution Measurement Systems, Volume II, Ambient Air Specific Methods. EPA-600/4-77-027a, U.S. Environmental Protection Agency, Research Triangle Park, NC 27711, 1977.</P>

          <P>3. Wedding, J. B., A. R. McFarland, and J. E. Cernak. Large Particle Collection Characteristics of Ambient Aerosol Samplers. Environ. Sci. Technol. <E T="03">11:</E>387-390, 1977.</P>
          <P>4. McKee, H. C., et al. Collaborative Testing of Methods to Measure Air Pollutants, I. The High-Volume Method for Suspended Particulate Matter. J. Air Poll. Cont. Assoc., 22 (342), 1972.</P>
          <P>5. Clement, R. E., and F. W. Karasek. Sample Composition Changes in Sampling and Analysis of Organic Compounds in Aerosols. The Intern. J. Environ. Anal. Chem., 7:109, 1979.</P>
          <P>6. Lee, R. E., Jr., and J. Wagman. A Sampling Anomaly in the Determination of Atmospheric Sulfuric Concentration. Am. Ind. Hygiene Assoc. J., 27:266, 1966.</P>
          <P>7. Appel, B. R., et al. Interference Effects in Sampling Particulate Nitrate in Ambient Air. Atmospheric Environment, 13:319, 1979.</P>
          <P>8. Tierney, G. P., and W. D. Conner. Hygroscopic Effects on Weight Determinations of Particulates Collected on Glass-Fiber Filters. Am. Ind. Hygiene Assoc. J., 28:363, 1967.</P>
          <P>9. Chahal, H. S., and D. J. Romano. High-Volume Sampling Effect of Windborne Particulate Matter Deposited During Idle Periods. J. Air Poll. Cont. Assoc., Vol. 26 (885), 1976.</P>
          <P>10. Patterson, R. K. Aerosol Contamination from High-Volume Sampler Exhaust. J. Air Poll. Cont. Assoc., Vol. 30 (169), 1980.</P>
          <P>11. EPA Test Procedures for Determining pH and Integrity of High-Volume Air Filters. QAD/M-80.01. Available from the Methods Standardization Branch, Quality Assurance Division, Environmental Monitoring Systems Laboratory (MD-77), U.S. Environmental Protection Agency, Research Triangle Park, NC 27711, 1980.</P>
          <P>12. Smith, F., P. S. Wohlschlegel, R. S. C. Rogers, and D. J. Mulligan. Investigation of Flow Rate Calibration Procedures Associated with the High-Volume Method for Determination of Suspended Particulates. EPA-600/4-78-047, U.S. Environmental Protection Agency, Research Triangle Park, NC, June 1978.</P>
          <GPH DEEP="262" SPAN="1">
            <GID>50-725.eps</GID>
          </GPH>
          <GPH DEEP="464" SPAN="2">
            <PRTPAGE P="33"/>
            <GID>50-726.eps</GID>
          </GPH>
          <GPH DEEP="446" SPAN="2">
            <PRTPAGE P="34"/>
            <GID>50-727.eps</GID>
          </GPH>
          <GPH DEEP="493" SPAN="2">
            <PRTPAGE P="35"/>
            <GID>50-728.eps</GID>
          </GPH>
          <GPH DEEP="388" SPAN="2">
            <PRTPAGE P="36"/>
            <GID>50-729.eps</GID>
          </GPH>
          <CITA>[47 FR 54912, Dec. 6, 1982; 48 FR 17355, Apr. 22, 1983]</CITA>
        </APPENDIX>
        <APPENDIX>
          <EAR>Pt. 50, App. C</EAR>
          <HD SOURCE="HED">Appendix C to Part 50—Measurement Principle and Calibration Procedure for the Measurement of Carbon Monoxide in the Atmosphere (Non-Dispersive Infrared Photometry)</HD>
          <HD SOURCE="HD1">Measurement Principle</HD>

          <P>1. Measurements are based on the absorption of infrared radiation by carbon monoxide (CO) in a non-dispersive photometer. Infrared energy from a source is passed through a cell containing the gas sample to be analyzed, and the quantitative absorption of energy by CO in the sample cell is measured by a suitable detector. The photometer is sensitized to CO by employing CO gas in either the detector or in a filter cell in the optical path, thereby limiting the measured absorption to one or more of the characteristic wavelengths at which CO strongly absorbs. Optical filters or other means may <PRTPAGE P="37"/>also be used to limit sensitivity of the photometer to a narrow band of interest. Various schemes may be used to provide a suitable zero reference for the photometer. The measured absorption is converted to an electrical output signal, which is related to the concentration of CO in the measurement cell.</P>
          <P>2. An analyzer based on this principle will be considered a reference method only if it has been designated as a reference method in accordance with part 53 of this chapter.</P>
          <P>3. Sampling considerations.</P>
          <P>The use of a particle filter on the sample inlet line of an NDIR CO analyzer is optional and left to the discretion of the user or the manufacturer. Use of filter should depend on the analyzer's susceptibility to interference, malfunction, or damage due to particles.</P>
          <HD SOURCE="HD1">Calibration Procedure</HD>
          <P>1. <E T="03">Principle.</E> Either of two methods may be used for dynamic multipoint calibration of CO analyzers:</P>
          <P>(1) One method uses a single certified standard cylinder of CO, diluted as necessary with zero air, to obtain the various calibration concentrations needed.</P>
          <P>(2) The other method uses individual certified standard cylinders of CO for each concentration needed. Additional information on calibration may be found in Section 2.0.9 of Reference 1.</P>
          <P>2. <E T="03">Apparatus.</E> The major components and typical configurations of the calibration systems for the two calibration methods are shown in Figures 1 and 2.</P>
          <P>2.1 Flow controller(s). Device capable of adjusting and regulating flow rates. Flow rates for the dilution method (Figure 1) must be regulated to ±1%.</P>
          <P>2.2 Flow meter(s). Calibrated flow meter capable of measuring and monitoring flow rates. Flow rates for the dilution method (Figure 1) must be measured with an accuracy of ±2% of the measured value.</P>
          <P>2.3 Pressure regulator(s) for standard CO cylinder(s). Regulator must have nonreactive diaphragm and internal parts and a suitable delivery pressure.</P>
          <P>2.4 Mixing chamber. A chamber designed to provide thorough mixing of CO and diluent air for the dilution method.</P>
          <P>2.5 Output manifold. The output manifold should be of sufficient diameter to insure an insignificant pressure drop at the analyzer connection. The system must have a vent designed to insure atmospheric pressure at the manifold and to prevent ambient air from entering the manifold.</P>
          <P>3. <E T="03">Reagents.</E>
          </P>
          <P>3.1 CO concentration standard(s). Cylinder(s) of CO in air containing appropriate concentrations(s) of CO suitable for the selected operating range of the analyzer under calibration; CO standards for the dilution method may be contained in a nitrogen matrix if the zero air dilution ratio is not less than 100:1. The assay of the cylinder(s) must be traceable either to a National Bureau of Standards (NBS) CO in air Standard Reference Material (SRM) or to an NBS/EPA-approved commercially available Certified Reference Material (CRM). CRM's are described in Reference 2, and a list of CRM sources is available from the address shown for Reference 2. A recommended protocol for certifying CO gas cylinders against either a CO SRM or a CRM is given in Reference 1. CO gas cylinders should be recertified on a regular basis as determined by the local quality control program.</P>
          <P>3.2 Dilution gas (zero air). Air, free of contaminants which will cause a detectable response on the CO analyzer. The zero air should contain &lt;0.1 ppm CO. A procedure for generating zero air is given in Reference 1.</P>
          <P>4. <E T="03">Procedure Using Dynamic Dilution Method.</E>
          </P>
          <P>4.1 Assemble a dynamic calibration system such as the one shown in Figure 1. All calibration gases including zero air must be introduced into the sample inlet of the analyzer system. For specific operating instructions refer to the manufacturer's manual.</P>
          <P>4.2 Insure that all flowmeters are properly calibrated, under the conditions of use, if appropriate, against an authoritative standard such as a soap-bubble meter or wet-test meter. All volumetric flowrates should be corrected to 25 °C and 760 mm Hg (101 kPa). A discussion on calibration of flowmeters is given in Reference 1.</P>
          <P>4.3 Select the operating range of the CO analyzer to be calibrated.</P>
          <P>4.4 Connect the signal output of the CO analyzer to the input of the strip chart recorder or other data collection device. All adjustments to the analyzer should be based on the appropriate strip chart or data device readings. References to analyzer responses in the procedure given below refer to recorder or data device responses.</P>

          <P>4.5 Adjust the calibration system to deliver zero air to the output manifold. The total air flow must exceed the total demand of the analyzer(s) connected to the output manifold to insure that no ambient air is pulled into the manifold vent. Allow the analyzer to sample zero air until a stable respose is obtained. After the response has stabilized, adjust the analyzer zero control. Offsetting the analyzer zero adjustments to +5 percent of scale is recommended to facilitate observing negative zero drift. Record the stable zero air response as Z<E T="52">CO</E>.</P>

          <P>4.6 Adjust the zero air flow and the CO flow from the standard CO cylinder to provide a diluted CO concentration of approximately 80 percent of the upper range limit (URL) of the operating range of the analyzer. The total air flow must exceed the total demand of the analyzer(s) connected to the output manifold to insure that no ambient air is <PRTPAGE P="38"/>pulled into the manifold vent. The exact CO concentration is calculated from:</P>
          <MATH DEEP="28" SPAN="1">
            <MID>ER31AU93.026</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">[CO]<E T="52">OUT</E> = diluted CO concentration at the output manifold, ppm;</FP>
          <FP SOURCE="FP-1">[CO]<E T="52">STD</E> = concentration of the undiluted CO standard, ppm;</FP>
          <FP SOURCE="FP-1">F<E T="52">CO</E> = flow rate of the CO standard corrected to 25 °C and 760 mm Hg, (101 kPa), L/min; and</FP>
          <FP SOURCE="FP-1">F<E T="52">D</E> = flow rate of the dilution air corrected to 25 °C and 760 mm Hg, (101 kPa), L/min.</FP>
          

          <P>Sample this CO concentration until a stable response is obtained. Adjust the analyzer span control to obtain a recorder response as indicated below:
          </P>
          <FP>Recorder response (percent scale) =</FP>
          
          <MATH DEEP="25" SPAN="1">
            <MID>ER31AU93.027</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">URL = nominal upper range limit of the analyzer's operating range, and</FP>
          <FP SOURCE="FP-1">Z<E T="52">CO</E> = analyzer response to zero air, % scale.</FP>
          

          <P>If substantial adjustment of the analyzer span control is required, it may be necessary to recheck the zero and span adjustments by repeating Steps 4.5 and 4.6. Record the CO concentration and the analyzer's response. 4.7 Generate several additional concentrations (at least three evenly spaced points across the remaining scale are suggested to verify linearity) by decreasing F<E T="52">CO</E> or increasing F<E T="52">D</E>. Be sure the total flow exceeds the analyzer's total flow demand. For each concentration generated, calculate the exact CO concentration using Equation (1). Record the concentration and the analyzer's response for each concentration. Plot the analyzer responses versus the corresponding CO concentrations and draw or calculate the calibration curve.</P>
          <P>5. <E T="03">Procedure Using Multiple Cylinder Method.</E> Use the procedure for the dynamic dilution method with the following changes:</P>
          <P>5.1 Use a multi-cylinder system such as the typical one shown in Figure 2.</P>
          <P>5.2 The flowmeter need not be accurately calibrated, provided the flow in the output manifold exceeds the analyzer's flow demand.</P>
          <P>5.3 The various CO calibration concentrations required in Steps 4.6 and 4.7 are obtained without dilution by selecting the appropriate certified standard cylinder.</P>
          <HD SOURCE="HD1">References</HD>
          <P>1. Quality Assurance Handbook for Air Pollution Measurement Systems, Volume II—Ambient Air Specific Methods, EPA-600/4-77-027a, U.S. Environmental Protection Agency, Environmental Monitoring Systems Laboratory, Research Triangle Park, NC 27711, 1977.</P>
          <P>2. A procedure for Establishing Traceability of Gas Mixtures to Certain National Bureau of Standards Standard Reference Materials. EPA-600/7-81-010, U.S. Environmental Protection Agency, Environmental Monitoring Systems Laboratory (MD-77), Research Triangle Park, NC 27711, January 1981.</P>
          <GPH DEEP="500" SPAN="2">
            <PRTPAGE P="39"/>
            <GID>50-732.eps</GID>
          </GPH>
          <GPH DEEP="500" SPAN="2">
            <PRTPAGE P="40"/>
            <GID>50-733.eps</GID>
          </GPH>
          <CITA>[47 FR 54922, Dec. 6, 1982; 48 FR 17355, Apr. 22, 1983]</CITA>
        </APPENDIX>
        <APPENDIX>
          <PRTPAGE P="41"/>
          <EAR>Pt. 50, App. D</EAR>
          <HD SOURCE="HED">Appendix D to Part 50—Measurement Principle and Calibration Procedure for the Measurement of Ozone in the Atmosphere</HD>
          <HD SOURCE="HD1">Measurement Principle</HD>
          <P>1. Ambient air and ethylene are delivered simultaneously to a mixing zone where the ozone in the air reacts with the ethylene to emit light, which is detected by a photomultiplier tube. The resulting photocurrent is amplified and is either read directly or displayed on a recorder.</P>
          <P>2. An analyzer based on this principle will be considered a reference method only if it has been designated as a reference method in accordance with part 53 of this chapter and calibrated as follows:</P>
          <HD SOURCE="HD1">Calibration Procedure</HD>
          <P>1. <E T="03">Principle.</E> The calibration procedure is based on the photometric assay of ozone (O<E T="52">3</E>) concentrations in a dynamic flow system. The concentration of O<E T="52">3</E> in an absorption cell is determined from a measurement of the amount of 254 nm light absorbed by the sample. This determination requires knowledge of (1) the absorption coefficient (α) of O<E T="52">3</E> at 254 nm, (2) the optical path length (<E T="03">l</E>) through the sample, (3) the transmittance of the sample at a wavelength of 254 nm, and (4) the temperature (T) and pressure (P) of the sample. The transmittance is defined as the ratio I/I<E T="52">0</E>, where I is the intensity of light which passes through the cell and is sensed by the detector when the cell contains an O<E T="52">3</E> sample, and I<E T="52">0</E> is the intensity of light which passes through the cell and is sensed by the detector when the cell contains zero air. It is assumed that all conditions of the system, except for the contents of the absorption cell, are identical during measurement of I and I<E T="52">0</E>. The quantities defined above are related by the Beer-Lambert absorption law,</P>
          <MATH DEEP="28" SPAN="1">
            <MID>ER31AU93.028</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">α = absorption coefficient of O<E T="52">3</E> at 254 nm=308 ±4 atm−1 cm<E T="51">−1</E> at 0 °C and 760 torr.<SU>3</SU>
            <E T="51">(1, 2, 3, 4, 5, 6, 7)</E>
          </FP>
          <FP SOURCE="FP-1">
            <E T="03">c</E> = O<E T="52">3</E> concentration in atmospheres</FP>
          <FP SOURCE="FP-1">
            <E T="03">l</E> = optical path length in cm</FP>
          
          <P>In practice, a stable O<E T="52">3</E> generator is used to produce O<E T="52">3</E> concentrations over the required range. Each O<E T="52">3</E> concentration is determined from the measurement of the transmittance (I/I<E T="52">0</E>) of the sample at 254 nm with a photometer of path length <E T="03">l</E> and calculated from the equation,</P>
          <MATH DEEP="50" SPAN="1">
            <MID>ER31AU93.029</MID>
          </MATH>
          <FP>The calculated O<E T="52">3</E> concentrations must be corrected for O<E T="52">3</E> losses which may occur in the photometer and for the temperature and pressure of the sample.</FP>
          <P>2. <E T="03">Applicability.</E> This procedure is applicable to the calibration of ambient air O<E T="52">3</E> analyzers, either directly or by means of a transfer standard certified by this procedure. Transfer standards must meet the requirements and specifications set forth in Reference 8.</P>
          <P>3. <E T="03">Apparatus.</E> A complete UV calibration system consists of an ozone generator, an output port or manifold, a photometer, an appropriate source of zero air, and other components as necessary. The configuration must provide a stable ozone concentration at the system output and allow the photometer to accurately assay the output concentration to the precision specified for the photometer (3.1). Figure 1 shows a commonly used configuration and serves to illustrate the calibration procedure which follows. Other configurations may require appropriate variations in the procedural steps. All connections between components in the calibration system downstream of the O<E T="52">3</E> generator should be of glass, Teflon, or other relatively inert materials. Additional information regarding the assembly of a UV photometric calibration apparatus is given in Reference 9. For certification of transfer standards which provide their own source of O<E T="52">3</E>, the transfer standard may replace the O<E T="52">3</E> generator and possibly other components shown in Figure 1; see Reference 8 for guidance.</P>
          <P>3.1 <E T="03">UV photometer.</E> The photometer consists of a low-pressure mercury discharge lamp, (optional) collimation optics, an absorption cell, a detector, and signal-processing electronics, as illustrated in Figure 1. It must be capable of measuring the transmittance, I/I<E T="52">0</E>, at a wavelength of 254 nm with sufficient precision such that the standard deviation of the concentration measurements does not exceed the greater of 0.005 ppm or 3% of the concentration. Because the low-pressure mercury lamp radiates at several wavelengths, the photometer must incorporate suitable means to assure that no O<E T="52">3</E> is generated in the cell by the lamp, and that at least 99.5% of the radiation sensed by the detector is 254 nm radiation. (This can be readily achieved by prudent selection of optical filter and detector response characteristics.) The length of the light path through the absorption cell must be known with an accuracy of at least 99.5%. In addition, the cell and associated plumbing must be designed to <PRTPAGE P="42"/>minimize loss of O<E T="52">3</E> from contact with cell walls and gas handling components. See Reference 9 for additional information.</P>
          <P>3.2 <E T="03">Air flow controllers.</E> Devices capable of regulating air flows as necessary to meet the output stability and photometer precision requirements.</P>
          <P>3.3 <E T="03">Ozone generator.</E> Device capable of generating stable levels of O<E T="52">3</E> over the required concentration range.</P>
          <P>3.4 <E T="03">Output manifold.</E> The output manifold should be constructed of glass, Teflon, or other relatively inert material, and should be of sufficient diameter to insure a negligible pressure drop at the photometer connection and other output ports. The system must have a vent designed to insure atmospheric pressure in the manifold and to prevent ambient air from entering the manifold.</P>
          <P>3.5 <E T="03">Two-way valve.</E> Manual or automatic valve, or other means to switch the photometer flow between zero air and the O<E T="52">3</E> concentration.</P>
          <P>3.6 <E T="03">Temperature indicator.</E> Accurate to ±1 °C.</P>
          <P>3.7 <E T="03">Barometer or pressure indicator.</E> Accurate to ±2 torr.</P>
          <P>4. <E T="03">Reagents.</E>
          </P>
          <P>4.1 <E T="03">Zero air.</E> The zero air must be free of contaminants which would cause a detectable response from the O<E T="52">3</E> analyzer, and it should be free of NO, C<E T="52">2</E> H<E T="52">4</E>, and other species which react with O<E T="52">3</E>. A procedure for generating suitable zero air is given in Reference 9. As shown in Figure 1, the zero air supplied to the photometer cell for the I<E T="52">0</E> reference measurement must be derived from the same source as the zero air used for generation of the ozone concentration to be assayed (I measurement). When using the photometer to certify a transfer standard having its own source of ozone, see Reference 8 for guidance on meeting this requirement.</P>
          <P>5. <E T="03">Procedure.</E>
          </P>
          <P>5.1 <E T="03">General operation.</E> The calibration photometer must be dedicated exclusively to use as a calibration standard. It should always be used with clean, filtered calibration gases, and never used for ambient air sampling. Consideration should be given to locating the calibration photometer in a clean laboratory where it can be stationary, protected from physical shock, operated by a responsible analyst, and used as a common standard for all field calibrations via transfer standards.</P>
          <P>5.2 <E T="03">Preparation.</E> Proper operation of the photometer is of critical importance to the accuracy of this procedure. The following steps will help to verify proper operation. The steps are not necessarily required prior to each use of the photometer. Upon initial operation of the photometer, these steps should be carried out frequently, with all quantitative results or indications recorded in a chronological record either in tabular form or plotted on a graphical chart. As the performance and stability record of the photometer is established, the frequency of these steps may be reduced consistent with the documented stability of the photometer.</P>
          <P>5.2.1 <E T="03">Instruction manual:</E> Carry out all set up and adjustment procedures or checks as described in the operation or instruction manual associated with the photometer.</P>
          <P>5.2.2 <E T="03">System check:</E> Check the photometer system for integrity, leaks, cleanliness, proper flowrates, etc. Service or replace filters and zero air scrubbers or other consumable materials, as necessary.</P>
          <P>5.2.3 <E T="03">Linearity:</E> Verify that the photometer manufacturer has adequately established that the linearity error of the photometer is less than 3%, or test the linearity by dilution as follows: Generate and assay an O<E T="52">3</E> concentration near the upper range limit of the system (0.5 or 1.0 ppm), then accurately dilute that concentration with zero air and reassay it. Repeat at several different dilution ratios. Compare the assay of the original concentration with the assay of the diluted concentration divided by the dilution ratio, as follows</P>
          <MATH DEEP="28" SPAN="1">
            <MID>ER31AU93.030</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">E = linearity error, percent</FP>
          <FP SOURCE="FP-1">A<E T="52">1</E> = assay of the original concentration</FP>
          <FP SOURCE="FP-1">A<E T="52">2</E> = assay of the diluted concentration</FP>
          <FP SOURCE="FP-1">R = dilution ratio = flow of original concentration divided by the total flow</FP>
          
          <P>The linearity error must be less than 5%. Since the accuracy of the measured flow-rates will affect the linearity error as measured this way, the test is not necessarily conclusive. Additional information on verifying linearity is contained in Reference 9.</P>
          <P>5.2.4 <E T="03">Intercomparison:</E> When possible, the photometer should be occasionally intercompared, either directly or via transfer standards, with calibration photometers used by other agencies or laboratories.</P>
          <P>5.2.5 <E T="03">Ozone losses:</E> Some portion of the O<E T="52">3</E> may be lost upon contact with the photometer cell walls and gas handling components. The magnitude of this loss must be determined and used to correct the calculated O<E T="52">3</E> concentration. This loss must not exceed 5%. Some guidelines for quantitatively determining this loss are discussed in Reference 9.</P>
          <P>5.3 <E T="03">Assay of O</E>
            <E T="52">3</E> concentrations.</P>
          <P>5.3.1 Allow the photometer system to warm up and stabilizer.</P>

          <P>5.3.2 Verify that the flowrate through the photometer absorption cell, F allows the cell to be flushed in a reasonably short period of time (2 liter/min is a typical flow). The precision of the measurements is inversely related to the time required for flushing, since the photometer drift error increases with time.<PRTPAGE P="43"/>
          </P>
          <P>5.3.3 Insure that the flowrate into the output manifold is at least 1 liter/min greater than the total flowrate required by the photometer and any other flow demand connected to the manifold.</P>
          <P>5.3.4 Insure that the flowrate of zero air, F<E T="52">z</E>, is at least 1 liter/min greater than the flowrate required by the photometer.</P>

          <P>5.3.5 With zero air flowing in the output manifold, actuate the two-way valve to allow the photometer to sample first the manifold zero air, then F<E T="52">z</E>. The two photometer readings must be equal (I=I<E T="52">o</E>).</P>
          <NOTE>
            <HD SOURCE="HED">Note:</HD>
            <P>In some commercially available photometers, the operation of the two-way valve and various other operations in section 5.3 may be carried out automatically by the photometer.</P>
          </NOTE>
          <P>5.3.6 Adjust the O<E T="52">3</E> generator to produce an O<E T="52">3</E> concentration as needed.</P>

          <P>5.3.7 Actuate the two-way valve to allow the photometer to sample zero air until the absorption cell is thoroughly flushed and record the stable measured value of I<E T="52">o</E>.</P>
          <P>5.3.8 Actuate the two-way valve to allow the photometer to sample the ozone concentration until the absorption cell is thoroughly flushed and record the stable measured value of I.</P>
          <P>5.3.9 Record the temperature and pressure of the sample in the photometer absorption cell. (See Reference 9 for guidance.)</P>
          <P>5.3.10 Calculate the O<E T="52">3</E> concentration from equation 4. An average of several determinations will provide better precision.</P>
          <MATH DEEP="024" SPAN="1">
            <MID>ER31AU93.032</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">[O<E T="52">3</E>]<E T="52">OUT</E> = O<E T="52">3</E> concentration, ppm</FP>
          <FP SOURCE="FP-1">α = absorption coefficient of O<E T="52">3</E> at 254 nm=308 atm<E T="51">−1</E> cm<E T="51">−1</E> at 0 °C and 760 torr</FP>
          <FP SOURCE="FP-1">
            <E T="03">l</E> = optical path length, cm</FP>
          <FP SOURCE="FP-1">T = sample temperature, K</FP>
          <FP SOURCE="FP-1">P = sample pressure, torr</FP>
          <FP SOURCE="FP-1">L = correction factor for O<E T="52">3</E> losses from 5.2.5=(1-fraction O<E T="52">3</E> lost).</FP>
          
          <NOTE>
            <HD SOURCE="HED">Note:</HD>

            <P>Some commercial photometers may automatically evaluate all or part of equation 4. It is the operator's responsibility to verify that all of the information required for equation 4 is obtained, either automatically by the photometer or manually. For “automatic” photometers which evaluate the first term of equation 4 based on a linear approximation, a manual correction may be required, particularly at higher O<E T="52">3</E> levels. See the photometer instruction manual and Reference 9 for guidance.</P>
          </NOTE>
          <P>5.3.11 Obtain additional O<E T="52">3</E> concentration standards as necessary by repeating steps 5.3.6 to 5.3.10 or by Option 1.</P>
          <P>5.4 <E T="03">Certification of transfer standards.</E> A transfer standard is certified by relating the output of the transfer standard to one or more ozone standards as determined according to section 5.3. The exact procedure varies depending on the nature and design of the transfer standard. Consult Reference 8 for guidance.</P>
          <P>5.5 <E T="03">Calibration of ozone analyzers.</E> Ozone analyzers are calibrated as follows, using ozone standards obtained directly according to section 5.3 or by means of a certified transfer standard.</P>
          <P>5.5.1 Allow sufficient time for the O<E T="52">3</E> analyzer and the photometer or transfer standard to warmup and stabilize.</P>
          <P>5.5.2 Allow the O<E T="52">3</E> analyzer to sample zero air until a stable response is obtained and adjust the O<E T="52">3</E> analyzer's zero control. Offsetting the analyzer's zero adjustment to +5% of scale is recommended to facilitate observing negative zero drift. Record the stable zero air response as “Z”.</P>
          <P>5.5.3 Generate an O<E T="52">3</E> concentration standard of approximately 80% of the desired upper range limit (URL) of the O<E T="52">3</E> analyzer. Allow the O<E T="52">3</E> analyzer to sample this O<E T="52">3</E> concentration standard until a stable response is obtained.</P>
          <P>5.5.4 Adjust the O<E T="52">3</E> analyzer's span control to obtain a convenient recorder response as indicated below:</P>
          <P>recorder response (%scale) =</P>
          <MATH DEEP="21" SPAN="1">
            <MID>ER31AU93.033</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">URL = upper range limit of the O<E T="52">3</E> analyzer, ppm</FP>
          <FP SOURCE="FP-1">Z = recorder response with zero air, % scale</FP>
          
          <P>Record the O<E T="52">3</E> concentration and the corresponding analyzer response. If substantial adjustment of the span control is necessary, recheck the zero and span adjustments by repeating steps 5.5.2 to 5.5.4.</P>
          <P>5.5.5 Generate several other O<E T="52">3</E> concentration standards (at least 5 others are recommended) over the scale range of the O<E T="52">3</E> analyzer by adjusting the O<E T="52">3</E> source or by Option 1. For each O<E T="52">3</E> concentration standard, record the O<E T="52">3</E> and the corresponding analyzer response.</P>
          <P>5.5.6 Plot the O<E T="52">3</E> analyzer responses versus the corresponding O<E T="52">3</E> concentrations and draw the O<E T="52">3</E> analyzer's calibration curve or calculate the appropriate response factor.</P>
          <P>5.5.7 <E T="03">Option 1:</E> The various O<E T="52">3</E> concentrations required in steps 5.3.11 and 5.5.5 may be obtained by dilution of the O<E T="52">3</E> concentration generated in steps 5.3.6 and 5.5.3. With this option, accurate flow measurements are required. The dynamic calibration system may be modified as shown in Figure 2 to allow for dilution air to be metered in downstream of the O<E T="52">3</E> generator. A mixing chamber between the O<E T="52">3</E> generator and the output manifold is also required. The flowrate through the O<E T="52">3</E> generator (F<E T="52">o</E>) and the dilution air flowrate <PRTPAGE P="44"/>(F<E T="52">D</E>) are measured with a reliable flow or volume standard traceable to NBS. Each O<E T="52">3</E> concentration generated by dilution is calculated from:</P>
          <MATH DEEP="36" SPAN="1">
            <MID>ER31AU93.031</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">[O<E T="52">3</E>]′<E T="52">OUT</E> = diluted O<E T="52">3</E> concentration, ppm</FP>
          <FP SOURCE="FP-1">F<E T="52">0</E> = flowrate through the O<E T="52">3</E> generator, liter/min</FP>
          <FP SOURCE="FP-1">F<E T="52">D</E> = diluent air flowrate, liter/min</FP>
          <HD SOURCE="HD1">References</HD>

          <P>1. E.C.Y. Inn and Y. Tanaka, “Absorption coefficient of Ozone in the Ultraviolet and Visible Regions”, <E T="03">J. Opt. Soc. Am., 43,</E> 870 (1953).</P>

          <P>2. A. G. Hearn, “Absorption of Ozone in the Ultraviolet and Visible Regions of the Spectrum”, <E T="03">Proc. Phys. Soc.</E> (London), <E T="03">78,</E> 932 (1961).</P>

          <P>3. W. B. DeMore and O. Raper, “Hartley Band Extinction Coefficients of Ozone in the Gas Phase and in Liquid Nitrogen, Carbon Monoxide, and Argon”, <E T="03">J. Phys. Chem., 68,</E> 412 (1964).</P>

          <P>4. M. Griggs, “Absorption Coefficients of Ozone in the Ultraviolet and Visible Regions”, <E T="03">J. Chem. Phys., 49,</E> 857 (1968).</P>

          <P>5. K. H. Becker, U. Schurath, and H. Seitz, “Ozone Olefin Reactions in the Gas Phase. 1. Rate Constants and Activation Energies”, <E T="03">Int'l Jour. of Chem. Kinetics,</E> VI, 725 (1974).</P>

          <P>6. M. A. A. Clyne and J. A. Coxom, “Kinetic Studies of Oxy-halogen Radical Systems”, <E T="03">Proc. Roy. Soc., A303,</E> 207 (1968).</P>

          <P>7. J. W. Simons, R. J. Paur, H. A. Webster, and E. J. Bair, “Ozone Ultraviolet Photolysis. VI. The Ultraviolet Spectrum”, <E T="03">J. Chem. Phys., 59,</E> 1203 (1973).</P>
          <P>8. Transfer Standards for Calibration of Ambient Air Monitoring Analyzers for Ozone, EPA publication number EPA-600/4-79-056, EPA, National Exposure Research Laboratory, Department E, (MD-77B), Research Triangle Park, NC 27711.</P>
          <P>9. Technical Assistance Document for the Calibration of Ambient Ozone Monitors, EPA publication number EPA-600/4-79-057, EPA, National Exposure Research Laboratory, Department E, (MD-77B), Research Triangle Park, NC 27711.</P>
          <GPH DEEP="500" SPAN="2">
            <PRTPAGE P="45"/>
            <GID>50-738.eps</GID>
          </GPH>
          <CITA>[44 FR 8224, Feb. 8, 1979, as amended at 62 FR 38895, July 18, 1997]</CITA>
        </APPENDIX>
        <APPENDIX>
          <PRTPAGE P="46"/>
          <RESERVED>Appendix E to Part 50 [Reserved]</RESERVED>
        </APPENDIX>
        <APPENDIX>
          <EAR>Pt. 50, App. F</EAR>
          <HD SOURCE="HED">Appendix F to Part 50—Measurement Principle and Calibration Procedure for the Measurement of Nitrogen Dioxide in the Atmosphere (Gas Phase Chemiluminescence)</HD>
          <HD SOURCE="HD1">Principle and Applicability</HD>
          <P>1. Atmospheric concentrations of nitrogen dioxide (NO<E T="52">2</E>) are measured indirectly by photometrically measuring the light intensity, at wavelengths greater than 600 nanometers, resulting from the chemiluminescent reaction of nitric oxide (NO) with ozone (O<E T="52">3</E>). (<E T="03">1,2,3</E>) NO<E T="52">2</E> is first quantitatively reduced to NO(<E T="03">4,5,6</E>) by means of a converter. NO, which commonly exists in ambient air together with NO<E T="52">2</E>, passes through the converter unchanged causing a resultant total NO<E T="52">X</E> concentration equal to NO+NO<E T="52">2</E>. A sample of the input air is also measured without having passed through the converted. This latter NO measurement is subtracted from the former measurement (NO+NO<E T="52">2</E>) to yield the final NO<E T="52">2</E> measurement. The NO and NO+NO<E T="52">2</E> measurements may be made concurrently with dual systems, or cyclically with the same system provided the cycle time does not exceed 1 minute.</P>
          <P>2. <E T="03">Sampling considerations.</E>
          </P>
          <P>2.1 Chemiluminescence NO/NO<E T="52">X</E>/NO<E T="52">2</E> analyzers will respond to other nitrogen containing compounds, such as peroxyacetyl nitrate (PAN), which might be reduced to NO in the thermal converter. (<E T="03">7</E>) Atmospheric concentrations of these potential interferences are generally low relative to NO<E T="52">2</E> and valid NO<E T="52">2</E> measurements may be obtained. In certain geographical areas, where the concentration of these potential interferences is known or suspected to be high relative to NO<E T="52">2</E>, the use of an equivalent method for the measurement of NO<E T="52">2</E> is recommended.</P>

          <P>2.2 The use of integrating flasks on the sample inlet line of chemiluminescence NO/NO<E T="52">X</E>/NO<E T="52">2</E> analyzers is optional and left to couraged. The sample residence time between the sampling point and the analyzer should be kept to a minimum to avoid erroneous NO<E T="52">2</E> measurements resulting from the reaction of ambient levels of NO and O<E T="52">3</E> in the sampling system.</P>

          <P>2.3 The use of particulate filters on the sample inlet line of chemiluminescence NO/NO<E T="52">X</E>/NO<E T="52">2</E> analyzers is optional and left to the discretion of the user or the manufacturer.</P>

          <FP>Use of the filter should depend on the analyzer's susceptibility to interference, malfunction, or damage due to particulates. Users are cautioned that particulate matter concentrated on a filter may cause erroneous NO<E T="52">2</E> measurements and therefore filters should be changed frequently.</FP>
          <P>3. An analyzer based on this principle will be considered a reference method only if it has been designated as a reference method in accordance with part 53 of this chapter.</P>
          <HD SOURCE="HD1">Calibration</HD>
          <P>1. <E T="03">Alternative A</E>—Gas phase titration (GPT) of an NO standard with O<E T="52">3</E>.</P>
          <P>
            <E T="03">Major equipment required:</E> Stable O<E T="52">3</E> generator. Chemiluminescence NO/NO<E T="52">X</E>/NO<E T="52">2</E> analyzer with strip chart recorder(s). NO concentration standard.</P>
          <P>1.1 <E T="03">Principle.</E> This calibration technique is based upon the rapid gas phase reaction between NO and O<E T="52">3</E> to produce stoichiometric quantities of NO<E T="52">2</E> in accordance with the following equation: (<E T="03">8</E>)</P>
          <MATH DEEP="12" SPAN="1">
            <MID>EC08NO91.075</MID>
          </MATH>

          <FP>The quantitative nature of this reaction is such that when the NO concentration is known, the concentration of NO<E T="52">2</E> can be determined. Ozone is added to excess NO in a dynamic calibration system, and the NO channel of the chemiluminescence NO/NO<E T="52">X</E>/NO<E T="52">2</E> analyzer is used as an indicator of changes in NO concentration. Upon the addition of O<E T="52">3</E>, the decrease in NO concentration observed on the calibrated NO channel is equivalent to the concentration of NO<E T="52">2</E> produced. The amount of NO<E T="52">2</E> generated may be varied by adding variable amounts of O<E T="52">3</E> from a stable uncalibrated O<E T="52">3</E> generator. (<E T="03">9</E>)</FP>
          <P>1.2 <E T="03">Apparatus.</E> Figure 1, a schematic of a typical GPT apparatus, shows the suggested configuration of the components listed below. All connections between components in the calibration system downstream from the O<E T="52">3</E> generator should be of glass, Teflon<E T="51">®</E>, or other non-reactive material.</P>
          <P>1.2.1 <E T="03">Air flow controllers.</E> Devices capable of maintaining constant air flows within ±2% of the required flowrate.</P>
          <P>1.2.2 <E T="03">NO flow controller.</E> A device capable of maintaining constant NO flows within ±2% of the required flowrate. Component parts in contact with the NO should be of a non-reactive material.</P>
          <P>1.2.3 <E T="03">Air flowmeters.</E> Calibrated flowmeters capable of measuring and monitoring air flowrates with an accuracy of ±2% of the measured flowrate.</P>
          <P>1.2.4 <E T="03">NO flowmeter.</E> A calibrated flowmeter capable of measuring and monitoring NO flowrates with an accuracy of ±2% of the measured flowrate. (Rotameters have been reported to operate unreliably when measuring low NO flows and are not recommended.)</P>
          <P>1.2.5 <E T="03">Pressure regulator for standard NO cylinder.</E> This regulator must have a nonreactive diaphragm and internal parts and a suitable delivery pressure.</P>
          <P>1.2.6 <E T="03">Ozone generator.</E> The generator must be capable of generating sufficient and stable levels of O<E T="52">3</E> for reaction with NO to generate <PRTPAGE P="47"/>NO<E T="52">2</E> concentrations in the range required. Ozone generators of the electric discharge type may produce NO and NO<E T="52">2</E> and are not recommended.</P>
          <P>1.2.7 <E T="03">Valve.</E> A valve may be used as shown in Figure 1 to divert the NO flow when zero air is required at the manifold. The valve should be constructed of glass, Teflon<E T="51">®</E>, or other nonreactive material.</P>
          <P>1.2.8 <E T="03">Reaction chamber.</E> A chamber, constructed of glass, Teflon<E T="51">®</E>, or other nonreactive material, for the quantitative reaction of O<E T="52">3</E> with excess NO. The chamber should be of sufficient volume (<E T="03">V</E>
            <E T="54">RC</E>) such that the residence time (<E T="03">t</E>
            <E T="52">R</E>) meets the requirements specified in 1.4. For practical reasons, t<E T="54">R</E> should be less than 2 minutes.</P>
          <P>1.2.9 <E T="03">Mixing chamber.</E> A chamber constructed of glass, Teflon<E T="51">®</E>, or other nonreactive material and designed to provide thorough mixing of reaction products and diluent air. The residence time is not critical when the dynamic parameter specification given in 1.4 is met.</P>
          <P>1.2.10 <E T="03">Output manifold.</E> The output manifold should be constructed of glass, Teflon<E T="51">®</E>, or other non-reactive material and should be of sufficient diameter to insure an insignificant pressure drop at the analyzer connection. The system must have a vent designed to insure atmospheric pressure at the manifold and to prevent ambient air from entering the manifold.</P>
          <P>1.3 <E T="03">Reagents.</E>
          </P>
          <P>1.3.1 <E T="03">NO concentration standard.</E> Gas cylinder standard containing 50 to 100 ppm NO in N<E T="52">2</E> with less than 1 ppm NO<E T="52">2</E>. This standard must be traceable to a National Bureau of Standards (NBS) NO in N<E T="52">2</E> Standard Reference Material (SRM 1683 or SRM 1684), an NBS NO<E T="52">2</E> Standard Reference Material (SRM 1629), or an NBS/EPA-approved commercially available Certified Reference Material (CRM). CRM's are described in Reference 14, and a list of CRM sources is available from the address shown for Reference 14. A recommended protocol for certifying NO gas cylinders against either an NO SRM or CRM is given in section 2.0.7 of Reference 15. Reference 13 gives procedures for certifying an NO gas cylinder against an NBS NO<E T="52">2</E> SRM and for determining the amount of NO<E T="52">2</E> impurity in an NO cylinder.</P>
          <P>1.3.2 <E T="03">Zero air.</E> Air, free of contaminants which will cause a detectable response on the NO/NO<E T="52">X</E>/NO<E T="52">2</E> analyzer or which might react with either NO, O<E T="52">3</E>, or NO<E T="52">2</E> in the gas phase titration. A procedure for generating zero air is given in reference 13.</P>
          <P>1.4 <E T="03">Dynamic parameter specification.</E>
          </P>
          <P>1.4.1 The O<E T="52">3</E> generator air flowrate (F<E T="52">0</E>) and NO flowrate (F<E T="52">NO</E>) (see Figure 1) must be adjusted such that the following relationship holds:</P>
          <MATH DEEP="12" SPAN="1">
            <MID>EC08NO91.076</MID>
          </MATH>
          <MATH DEEP="31" SPAN="1">
            <MID>EC08NO91.077</MID>
          </MATH>
          <MATH DEEP="27" SPAN="1">
            <MID>EC08NO91.078</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">
            <E T="03">P</E>
            <E T="54">R</E> = dynamic parameter specification, determined empirically, to insure complete reaction of the available O<E T="52">3</E>, ppm-minute</FP>
          <FP SOURCE="FP-1">[NO]<E T="54">RC</E> = NO concentration in the reaction chamber, ppm</FP>
          <FP SOURCE="FP-1">
            <E T="54">R</E> = residence time of the reactant gases in the reaction chamber, minute</FP>
          <FP SOURCE="FP-1">[NO]<E T="52">STD</E> = concentration of the undiluted NO standard, ppm</FP>
          <FP SOURCE="FP-1">
            <E T="03">F</E>
            <E T="52">NO</E> = NO flowrate, scm<SU>3</SU>/min</FP>
          <FP SOURCE="FP-1">
            <E T="03">F</E>
            <E T="52">O</E> = O<E T="52">3</E> generator air flowrate, scm<SU>3</SU>/min</FP>
          <FP SOURCE="FP-1">
            <E T="03">V</E>
            <E T="54">RC</E> = volume of the reaction chamber, scm<SU>3</SU>
          </FP>
          
          <P>1.4.2 The flow conditions to be used in the GPT system are determined by the following procedure:</P>
          <P>(a) Determine <E T="03">F</E>
            <E T="54">T</E>, the total flow required at the output manifold (<E T="03">F</E>
            <E T="54">T</E>=analyzer demand plus 10 to 50% excess).</P>
          <P>(b) Establish [NO]<E T="52">OUT</E> as the highest NO concentration (ppm) which will be required at the output manifold. [NO]<E T="52">OUT</E> should be approximately equivalent to 90% of the upper range limit (<E T="03">URL</E>) of the NO<E T="52">2</E> concentration range to be covered.</P>
          <P>(c) Determine F<E T="52">NO</E> as</P>
          <MATH DEEP="27" SPAN="1">
            <MID>EC08NO91.079</MID>
          </MATH>

          <P>(d) Select a convenient or available reaction chamber volume. Initially, a trial <E T="03">V</E>
            <E T="54">RC</E> may be selected to be in the range of approximately 200 to 500 scm<SU>3</SU>.</P>
          <P>(e) Compute FO as</P>
          <MATH DEEP="38" SPAN="1">
            <MID>50-754.eps</MID>
          </MATH>
          <P>(f) Compute <E T="03">t</E>
            <E T="52">R</E> as</P>
          <MATH DEEP="27" SPAN="1">
            <MID>EC08NO91.080</MID>
          </MATH>
          <FP>Verify that <E T="03">t</E>
            <E T="54">R</E> &lt; 2 minutes. If not, select a reaction chamber with a smaller <E T="03">V</E>
            <E T="54">RC</E>.</FP>
          <P>(g) Compute the diluent air flowrate as</P>
          <MATH DEEP="12" SPAN="1">
            <MID>EC08NO91.081</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">
            <E T="03">F</E>
            <E T="54">D</E> = diluent air flowrate, scm<SU>3</SU>/min</FP>
          
          <P>(h) If <E T="03">F</E>
            <E T="54">O</E> turns out to be impractical for the desired system, select a reaction chamber <PRTPAGE P="48"/>having a different <E T="03">V</E>
            <E T="54">RC</E> and recompute <E T="03">F</E>
            <E T="54">O</E> and <E T="03">F</E>
            <E T="54">D</E>.</P>
          <NOTE>
            <HD SOURCE="HED">Note:</HD>

            <P>A dynamic parameter lower than 2.75 ppm-minutes may be used if it can be determined empirically that quantitative reaction of O<E T="52">3</E> with NO occurs. A procedure for making this determination as well as a more detailed discussion of the above requirements and other related considerations is given in reference 13.</P>
          </NOTE>
          <P>1.5 <E T="03">Procedure.</E>
          </P>
          <P>1.5.1 Assemble a dynamic calibration system such as the one shown in Figure 1.</P>
          <P>1.5.2 Insure that all flowmeters are calibrated under the conditions of use against a reliable standard such as a soap-bubble meter or wet-test meter. All volumetric flowrates should be corrected to 25 °C and 760 mm Hg. A discussion on the calibration of flowmeters is given in reference 13.</P>
          <P>1.5.3 Precautions must be taken to remove O<E T="52">2</E> and other contaminants from the NO pressure regulator and delivery system prior to the start of calibration to avoid any conversion of the standard NO to NO<E T="52">2</E>. Failure to do so can cause significant errors in calibration. This problem may be minimized by (1) carefully evacuating the regulator, when possible, after the regulator has been connected to the cylinder and before opening the cylinder valve; (2) thoroughly flushing the regulator and delivery system with NO after opening the cylinder valve; (3) not removing the regulator from the cylinder between calibrations unless absolutely necessary. Further discussion of these procedures is given in reference 13.</P>
          <P>1.5.4 Select the operating range of the NO/NO<E T="52">X</E>/NO<E T="52">2</E> analyzer to be calibrated. In order to obtain maximum precision and accuracy for NO<E T="52">2</E> calibration, all three channels of the analyzer should be set to the same range. If operation of the NO and NO<E T="52">X</E> channels on higher ranges is desired, subsequent recalibration of the NO and NO<E T="52">X</E> channels on the higher ranges is recommended.</P>
          <NOTE>
            <HD SOURCE="HED">Note:</HD>

            <P>Some analyzer designs may require identical ranges for NO, NO<E T="52">X</E>, and NO<E T="52">2</E> during operation of the analyzer.</P>
          </NOTE>
          <P>1.5.5 Connect the recorder output cable(s) of the NO/NO<E T="52">X</E>/NO<E T="52">2</E> analyzer to the input terminals of the strip chart recorder(s). All adjustments to the analyzer should be performed based on the appropriate strip chart readings. References to analyzer responses in the procedures given below refer to recorder responses.</P>
          <P>1.5.6 Determine the GPT flow conditions required to meet the dynamic parameter specification as indicated in 1.4.</P>
          <P>1.5.7 Adjust the diluent air and O<E T="52">3</E> generator air flows to obtain the flows determined in section 1.4.2. The total air flow must exceed the total demand of the analyzer(s) connected to the output manifold to insure that no ambient air is pulled into the manifold vent. Allow the analyzer to sample zero air until stable NO, NO<E T="52">X</E>, and NO<E T="52">2</E> responses are obtained. After the responses have stabilized, adjust the analyzer zero control(s).</P>
          <NOTE>
            <HD SOURCE="HED">Note:</HD>

            <P>Some analyzers may have separate zero controls for NO, NO<E T="52">X</E>, and NO<E T="52">2</E>. Other analyzers may have separate zero controls only for NO and NO<E T="52">X</E>, while still others may have only one zero control common to all three channels.</P>
          </NOTE>

          <P>Offsetting the analyzer zero adjustments to +5 percent of scale is recommended to facilitate observing negative zero drift. Record the stable zero air responses as Z<E T="52">NO</E>, <E T="04">Znox</E>, and <E T="04">Zno2</E>.</P>
          <P>1.5.8 <E T="03">Preparation of NO and NO</E>
            <E T="52">X</E>
            <E T="03">calibration curves.</E>
          </P>
          <P>1.5.8.1 <E T="03">Adjustment of NO span control.</E> Adjust the NO flow from the standard NO cylinder to generate an NO concentration of approximately 80 percent of the upper range limit (<E T="03">URL</E>) of the NO range. This exact NO concentration is calculated from:</P>
          <MATH DEEP="28" SPAN="1">
            <MID>ER31AU93.044</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">[NO]<E T="54">OUT</E> = diluted NO concentration at the output manifold, ppm</FP>
          
          <FP>Sample this NO concentration until the NO and NO<E T="52">X</E> responses have stabilized. Adjust the NO span control to obtain a recorder response as indicated below:</FP>
          
          <FP>recorder response (percent scale) =</FP>
          <MATH DEEP="30" SPAN="1">
            <MID>ER31AU93.045</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">
            <E T="03">URL</E> = nominal upper range limit of the NO channel, ppm</FP>
          <NOTE>
            <HD SOURCE="HED">Note:</HD>

            <P>Some analyzers may have separate span controls for NO, NO<E T="52">X</E>, and NO<E T="52">2</E>. Other analyzers may have separate span controls only for NO and NO<E T="52">X</E>, while still others may have only one span control common to all three channels. When only one span control is available, the span adjustment is made on the NO channel of the analyzer.</P>
          </NOTE>
          <FP>If substantial adjustment of the NO span control is necessary, it may be necessary to recheck the zero and span adjustments by repeating steps 1.5.7 and 1.5.8.1. Record the NO concentration and the analyzer's NO response.</FP>
          <P>1.5.8.2 <E T="03">Adjustment of NO</E>
            <E T="52">X</E>
            <E T="03">span control.</E> When adjusting the analyzer's NO<E T="52">X</E> span control, the presence of any NO<E T="52">2</E> impurity in the standard NO cylinder must be taken into account. Procedures for determining the amount of NO<E T="52">2</E> impurity in the standard NO cylinder are given in reference 13. The exact NO<E T="52">X</E> concentration is calculated from:</P>
          <MATH DEEP="32" SPAN="1">
            <PRTPAGE P="49"/>
            <MID>ER31AU93.046</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">[NO<E T="52">X</E>]<E T="52">OUT</E> = diluted NO<E T="52">X</E> concentration at the output manifold, ppm</FP>
          <FP SOURCE="FP-1">[NO<E T="52">2</E>]<E T="52">IMP</E> = concentration of NO<E T="52">2</E> impurity in the standard NO cylinder, ppm</FP>
          
          <FP>Adjust the NO<E T="52">X</E> span control to obtain a recorder response as indicated below:</FP>
          
          <FP>recorder response (% scale) =</FP>
          <MATH DEEP="30" SPAN="1">
            <MID>ER31AU93.047</MID>
          </MATH>
          <NOTE>
            <HD SOURCE="HED">Note:</HD>

            <P>If the analyzer has only one span control, the span adjustment is made on the NO channel and no further adjustment is made here for NO<E T="52">X</E>.</P>
          </NOTE>
          
          <FP>If substantial adjustment of the NO<E T="52">X</E> span control is necessary, it may be necessary to recheck the zero and span adjustments by repeating steps 1.5.7 and 1.5.8.2. Record the NO<E T="52">X</E> concentration and the analyzer's NO<E T="52">X</E> response.</FP>

          <P>1.5.8.3 Generate several additional concentrations (at least five evenly spaced points across the remaining scale are suggested to verify linearity) by decreasing F<E T="52">NO</E> or increasing F<E T="52">D</E>. For each concentration generated, calculate the exact NO and NO<E T="52">X</E> concentrations using equations (9) and (11) respectively. Record the analyzer's NO and NO<E T="52">X</E> responses for each concentration. Plot the analyzer responses versus the respective calculated NO and NO<E T="52">X</E> concentrations and draw or calculate the NO and NO<E T="52">X</E> calibration curves. For subsequent calibrations where linearity can be assumed, these curves may be checked with a two-point calibration consisting of a zero air point and NO and NO<E T="52">X</E> concentrations of approximately 80% of the <E T="03">URL</E>.</P>
          <P>1.5.9 <E T="03">Preparation of NO</E>
            <E T="54">2</E>
            <E T="03">calibration curve.</E>
          </P>
          <P>1.5.9.1 Assuming the NO<E T="52">2</E> zero has been properly adjusted while sampling zero air in step 1.5.7, adjust F<E T="52">O</E> and F<E T="52">D</E> as determined in section 1.4.2. Adjust F<E T="52">NO</E> to generate an NO concentration near 90% of the <E T="03">URL</E> of the NO range. Sample this NO concentration until the NO and NO<E T="52">X</E> responses have stabilized. Using the NO calibration curve obtained in section 1.5.8, measure and record the NO concentration as [NO]<E T="52">orig</E>. Using the NO<E T="52">X</E> calibration curve obtained in section 1.5.8, measure and record the NO<E T="52">X</E> concentration as [NO<E T="52">X</E>]<E T="52">orig</E>.</P>
          <P>1.5.9.2 Adjust the O<E T="52">3</E> generator to generate sufficient O<E T="52">3</E> to produce a decrease in the NO concentration equivalent to approximately 80% of the URL of the NO<E T="52">2</E> range. The decrease must not exceed 90% of the NO concentration determined in step 1.5.9.1. After the analyzer responses have stabilized, record the resultant NO and NO<E T="52">X</E> concentrations as [NO]<E T="52">rem</E> and [NO<E T="52">X</E>]<E T="52">rem</E>.</P>
          <P>1.5.9.3 Calculate the resulting NO<E T="52">2</E> concentration from:</P>
          <MATH DEEP="30" SPAN="2">
            <MID>EC08NO91.082</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">[NO<E T="52">2</E>]<E T="52">OUT</E> = diluted NO<E T="52">2</E> concentration at the output manifold, ppm</FP>
          <FP SOURCE="FP-1">[NO]<E T="52">orig</E> = original NO concentration, prior to addition of O<E T="52">3</E>, ppm</FP>
          <FP SOURCE="FP-1">[NO]<E T="52">rem</E> = NO concentration remaining after addition of O<E T="52">3</E>, ppm</FP>
          
          <FP>Adjust the NO<E T="52">2</E> span control to obtain a recorder response as indicated below:</FP>
          
          <FP>recorder response (% scale) =</FP>
          <MATH DEEP="22" SPAN="1">
            <MID>ER31AU93.048</MID>
          </MATH>
          <NOTE>
            <HD SOURCE="HED">Note:</HD>

            <P>If the analyzer has only one or two span controls, the span adjustments are made on the NO channel or NO and NO<E T="52">X</E> channels and no further adjustment is made here for NO<E T="52">2</E>.</P>
          </NOTE>
          <FP>If substantial adjustment of the NO<E T="52">2</E> span control is necessary, it may be necessary to recheck the zero and span adjustments by repeating steps 1.5.7 and 1.5.9.3. Record the NO<E T="52">2</E> concentration and the corresponding analyzer NO<E T="52">2</E> and NO<E T="52">X</E> responses.</FP>
          <P>1.5.9.4 Maintaining the same F<E T="52">NO</E>, F<E T="52">O</E>, and F<E T="52">D</E> as in section 1.5.9.1, adjust the ozone generator to obtain several other concentrations of NO<E T="52">2</E> over the NO<E T="52">2</E> range (at least five evenly spaced points across the remaining scale are suggested). Calculate each NO<E T="52">2</E> concentration using equation (13) and record the corresponding analyzer NO<E T="52">2</E> and NO<E T="52">X</E> responses. Plot the analyzer's NO<E T="52">2</E> responses versus the corresponding calculated NO<E T="52">2</E> concentrations and draw or calculate the NO<E T="52">2</E> calibration curve.</P>
          <P>1.5.10 <E T="03">Determination of converter efficiency.</E>
          </P>
          <P>1.5.10.1 For each NO<E T="52">2</E> concentration generated during the preparation of the NO<E T="52">2</E> calibration curve (see section 1.5.9) calculate the concentration of NO<E T="52">2</E> converted from:</P>
          <MATH DEEP="23" SPAN="2">
            <PRTPAGE P="50"/>
            <MID>EC08NO91.083</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">[NO<E T="52">2</E>]<E T="52">CONV</E> = concentration of NO<E T="52">2</E> converted, ppm</FP>
          <FP SOURCE="FP-1">[NO<E T="52">X</E>]<E T="52">orig</E> = original NO<E T="52">X</E> concentration prior to addition of O<E T="52">3</E>, ppm</FP>
          <FP SOURCE="FP-1">[NO<E T="52">X</E>]<E T="52">rem</E> = NO<E T="52">X</E> concentration remaining after addition of O<E T="52">3</E>, ppm</FP>
          
          <NOTE>
            <HD SOURCE="HED">Note:</HD>
            <P>Supplemental information on calibration and other procedures in this method are given in reference 13.</P>
          </NOTE>
          <FP>Plot [NO<E T="52">2</E>]<E T="52">CONV</E> (y-axis) versus [NO<E T="52">2</E>]<E T="52">OUT</E> (x-axis) and draw or calculate the converter efficiency curve. The slope of the curve times 100 is the average converter efficiency, E<E T="52">C</E> The average converter efficiency must be greater than 96%; if it is less than 96%, replace or service the converter.</FP>
          <P>2. <E T="03">Alternative B</E>—NO<E T="52">2</E> permeation device.</P>
          <P>
            <E T="03">Major equipment required:</E>
          </P>
          <P>Stable O<E T="52">3</E> generator.</P>
          <P>Chemiluminescence NO/NO<E T="54">X</E>/NO<E T="52">2</E> analyzer with strip chart recorder(s).</P>
          <P>NO concentration standard.</P>
          <P>NO<E T="52">2</E> concentration standard.</P>
          <P>2.1 <E T="03">Principle.</E> Atmospheres containing accurately known concentrations of nitrogen dioxide are generated by means of a permeation device. (<E T="03">10</E>) The permeation device emits NO<E T="52">2</E> at a known constant rate provided the temperature of the device is held constant (±0.1 °C) and the device has been accurately calibrated at the temperature of use. The NO<E T="52">2</E> emitted from the device is diluted with zero air to produce NO<E T="52">2</E> concentrations suitable for calibration of the NO<E T="52">2</E> channel of the NO/NO<E T="54">X</E>/NO<E T="52">2</E> analyzer. An NO concentration standard is used for calibration of the NO and NO<E T="54">X</E> channels of the analyzer.</P>
          <P>2.2 <E T="03">Apparatus.</E> A typical system suitable for generating the required NO and NO<E T="52">2</E> concentrations is shown in Figure 2. All connections between components downstream from the permeation device should be of glass, Teflon<E T="51">®</E>, or other non-reactive material.</P>
          <P>2.2.1 <E T="03">Air flow controllers.</E> Devices capable of maintaining constant air flows within ±2% of the required flowrate.</P>
          <P>2.2.2 <E T="03">NO flow controller.</E> A device capable of maintaining constant NO flows within ±2% of the required flowrate. Component parts in contact with the NO must be of a non-reactive material.</P>
          <P>2.2.3 <E T="03">Air flowmeters.</E> Calibrated flowmeters capable of measuring and monitoring air flowrates with an accuracy of ±2% of the measured flowrate.</P>
          <P>2.2.4 <E T="03">NO flowmeter.</E> A calibrated flowmeter capable of measuring and monitoring NO flowrates with an accuracy of ±2% of the measured flowrate. (Rotameters have been reported to operate unreliably when measuring low NO flows and are not recommended.)</P>
          <P>2.2.5 <E T="03">Pressure regulator for standard NO cylinder.</E> This regulator must have a non-reactive diaphragm and internal parts and a suitable delivery pressure.</P>
          <P>2.2.6 <E T="03">Drier.</E> Scrubber to remove moisture from the permeation device air system. The use of the drier is optional with NO<E T="52">2</E> permeation devices not sensitive to moisture. (Refer to the supplier's instructions for use of the permeation device.)</P>
          <P>2.2.7 <E T="03">Constant temperature chamber.</E> Chamber capable of housing the NO<E T="52">2</E> permeation device and maintaining its temperature to within ±0.1 °C.</P>
          <P>2.2.8 <E T="03">Temperature measuring device.</E> Device capable of measuring and monitoring the temperature of the NO<E T="52">2</E> permeation device with an accuracy of ±0.05 °C.</P>
          <P>2.2.9 <E T="03">Valves.</E> A valve may be used as shown in Figure 2 to divert the NO<E T="52">2</E> from the permeation device when zero air or NO is required at the manifold. A second valve may be used to divert the NO flow when zero air or NO<E T="52">2</E> is required at the manifold.</P>
          <P>The valves should be constructed of glass, Teflon<E T="51">®</E>, or other nonreactive material.</P>
          <P>2.2.10 <E T="03">Mixing chamber.</E> A chamber constructed of glass, Teflon<E T="51">®</E>, or other nonreactive material and designed to provide thorough mixing of pollutant gas streams and diluent air.</P>
          <P>2.2.11 <E T="03">Output manifold.</E> The output manifold should be constructed of glass, Teflon<E T="51">®</E>, or other non-reactive material and should be of sufficient diameter to insure an insignificant pressure drop at the analyzer connection. The system must have a vent designed to insure atmospheric pressure at the manifold and to prevent ambient air from entering the manifold.</P>
          <P>2.3 <E T="03">Reagents.</E>
          </P>
          <P>2.3.1 <E T="03">Calibration standards.</E> Calibration standards are required for both NO and NO<E T="52">2</E>. The reference standard for the calibration may be either an NO or NO<E T="52">2</E> standard, and must be traceable to a National Bureau of Standards (NBS) NO in N<E T="52">2</E> Standard Reference Material (SRM 1683 or SRM 1684), and NBS NO<E T="52">2</E> Standard Reference Material (SRM 1629), or an NBS/EPA-approved commercially available Certified Reference Material (CRM). CRM's are described in Reference 14, and a list of CRM sources is available from the address shown for Reference 14. Reference 15 gives recommended procedures for certifying an NO gas cylinder against an NO <PRTPAGE P="51"/>SRM or CRM and for certifying an NO<E T="52">2</E> permeation device against an NO<E T="52">2</E> SRM. Reference 13 contains procedures for certifying an NO gas cylinder against an NO<E T="52">2</E> SRM and for certifying an NO<E T="52">2</E> permeation device against an NO SRM or CRM. A procedure for determining the amount of NO<E T="52">2</E> impurity in an NO cylinder is also contained in Reference 13. The NO or NO<E T="52">2</E> standard selected as the reference standard must be used to certify the other standard to ensure consistency between the two standards.</P>
          <P>2.3.1.1 <E T="03">NO</E>
            <E T="52">2</E>
            <E T="03">Concentration standard.</E> A permeation device suitable for generating NO<E T="52">2</E> concentrations at the required flow-rates over the required concentration range. If the permeation device is used as the reference standard, it must be traceable to an SRM or CRM as specified in 2.3.1. If an NO cylinder is used as the reference standard, the NO<E T="52">2</E> permeation device must be certified against the NO standard according to the procedure given in Reference 13. The use of the permeation device should be in strict accordance with the instructions supplied with the device. Additional information regarding the use of permeation devices is given by Scaringelli et al. (11) and Rook et al. (12).</P>
          <P>2.3.1.2 <E T="03">NO Concentration standard.</E> Gas cylinder containing 50 to 100 ppm NO in N<E T="52">2</E> with less than 1 ppm NO<E T="52">2</E>. If this cylinder is used as the reference standard, the cylinder must be traceable to an SRM or CRM as specified in 2.3.1. If an NO<E T="52">2</E> permeation device is used as the reference standard, the NO cylinder must be certified against the NO<E T="52">2</E> standard according to the procedure given in Reference 13. The cylinder should be recertified on a regular basis as determined by the local quality control program.</P>
          <P>2.3.3 <E T="03">Zero air.</E> Air, free of contaminants which might react with NO or NO<E T="52">2</E> or cause a detectable response on the NO/NO<E T="54">X</E>/NO<E T="52">2</E> analyzer. When using permeation devices that are sensitive to moisture, the zero air passing across the permeation device must be dry to avoid surface reactions on the device. (Refer to the supplier's instructions for use of the permeation device.) A procedure for generating zero air is given in reference 13.</P>
          <P>2.4 <E T="03">Procedure.</E>
          </P>
          <P>2.4.1 Assemble the calibration apparatus such as the typical one shown in Figure 2.</P>
          <P>2.4.2 Insure that all flowmeters are calibrated under the conditions of use against a reliable standard such as a soap bubble meter or wet-test meter. All volumetric flowrates should be corrected to 25 °C and 760 mm Hg. A discussion on the calibration of flowmeters is given in reference 13.</P>

          <P>2.4.3 Install the permeation device in the constant temperature chamber. Provide a small fixed air flow (200-400 scm<SU>3</SU>/min) across the device. The permeation device should always have a continuous air flow across it to prevent large buildup of NO<E T="52">2</E> in the system and a consequent restabilization period. Record the flowrate as FP. Allow the device to stabilize at the calibration temperature for at least 24 hours. The temperature must be adjusted and controlled to within ±0.1 °C or less of the calibration temperature as monitored with the temperature measuring device.</P>
          <P>2.4.4 Precautions must be taken to remove O<E T="52">2</E> and other contaminants from the NO pressure regulator and delivery system prior to the start of calibration to avoid any conversion of the standard NO to NO<E T="52">2</E>. Failure to do so can cause significant errors in calibration. This problem may be minimized by</P>
          <P>(1) Carefully evacuating the regulator, when possible, after the regulator has been connected to the cylinder and before opening the cylinder valve;</P>
          <P>(2) Thoroughly flushing the regulator and delivery system with NO after opening the cylinder valve;</P>
          <P>(3) Not removing the regulator from the cylinder between calibrations unless absolutely necessary. Further discussion of these procedures is given in reference 13.</P>
          <P>2.4.5 Select the operating range of the NO/NO<E T="54">X</E> NO<E T="52">2</E> analyzer to be calibrated. In order to obtain maximum precision and accuracy for NO<E T="52">2</E> calibration, all three channels of the analyzer should be set to the same range. If operation of the NO and NO<E T="54">X</E> channels on higher ranges is desired, subsequent recalibration of the NO and NO<E T="54">X</E> channels on the higher ranges is recommended.</P>
          <NOTE>
            <HD SOURCE="HED">Note:</HD>

            <P>Some analyzer designs may require identical ranges for NO, NO<E T="54">X</E>, and NO<E T="52">2</E> during operation of the analyzer.</P>
          </NOTE>
          <P>2.4.6 Connect the recorder output cable(s) of the NO/NO<E T="54">X</E>/NO<E T="52">2</E> analyzer to the input terminals of the strip chart recorder(s). All adjustments to the analyzer should be performed based on the appropriate strip chart readings. References to analyzer responses in the procedures given below refer to recorder responses.</P>

          <P>2.4.7 Switch the valve to vent the flow from the permeation device and adjust the diluent air flowrate, F<E T="54">D</E>, to provide zero air at the output manifold. The total air flow must exceed the total demand of the analyzer(s) connected to the output manifold to insure that no ambient air is pulled into the manifold vent. Allow the analyzer to sample zero air until stable NO, NO<E T="54">X</E>, and NO<E T="52">2</E> responses are obtained. After the responses have stabilized, adjust the analyzer zero control(s).</P>
          <NOTE>
            <HD SOURCE="HED">Note:</HD>

            <P>Some analyzers may have separate zero controls for NO, NO<E T="54">X</E>, and NO<E T="52">2</E>. Other analyzers may have separate zero controls only for NO and NO<E T="54">X</E>, while still others may have only one zero common control to all three channels.</P>
          </NOTE>

          <FP>Offsetting the analyzer zero adjustments to +5% of scale is recommended to facilitate observing negative zero drift. Record the stable zero air responses as Z<E T="52">NO</E>, Z<E T="52">NO</E>
            <E T="54">X</E>, and Z<E T="52">NO</E>
            <E T="52">2</E>.<PRTPAGE P="52"/>
          </FP>
          <P>2.4.8 <E T="03">Preparation of NO and NO</E>
            <E T="54">X</E>
            <E T="03">calibration curves.</E>
          </P>
          <P>2.4.8.1 <E T="03">Adjustment of NO span control.</E> Adjust the NO flow from the standard NO cylinder to generate an NO concentration of approximately 80% of the upper range limit (URL) of the NO range. The exact NO concentration is calculated from:</P>
          <MATH DEEP="28" SPAN="1">
            <MID>ER31AU93.049</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">[NO]<E T="52">OUT</E> = diluted NO concentration at the output manifold, ppm</FP>
          <FP SOURCE="FP-1">
            <E T="03">F</E>
            <E T="52">NO</E> = NO flowrate, scm<SU>3</SU>/min</FP>
          <FP SOURCE="FP-1">[NO]<E T="52">STD</E>=concentration of the undiluted NO standard, ppm</FP>
          <FP SOURCE="FP-1">
            <E T="03">F</E>
            <E T="54">D</E> = diluent air flowrate, scm<SU>3</SU>/min</FP>
          
          <FP>Sample this NO concentration until the NO and NO<E T="54">X</E> responses have stabilized. Adjust the NO span control to obtain a recorder response as indicated below:</FP>
          
          <FP>recorder response (% scale) =</FP>
          <MATH DEEP="30" SPAN="1">
            <MID>ER31AU93.050</MID>
          </MATH>
          <MATH DEEP="30" SPAN="1">
            <MID>ER31AU93.051</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">
            <E T="03">URL</E> = nominal upper range limit of the NO channel, ppm</FP>
          
          <NOTE>
            <HD SOURCE="HED">Note:</HD>

            <P>Some analyzers may have separate span controls for NO, NO<E T="54">X</E>, and NO<E T="52">2</E>. Other analyzers may have separate span controls only for NO and NO<E T="54">X</E>, while still others may have only one span control common to all three channels. When only one span control is available, the span adjustment is made on the NO channel of the analyzer.</P>
          </NOTE>
          
          <FP>If substantial adjustment of the NO span control is necessary, it may be necessary to recheck the zero and span adjustments by repeating steps 2.4.7 and 2.4.8.1. Record the NO concentration and the analyzer's NO response.</FP>
          <P>2.4.8.2 <E T="03">Adjustment of NO</E>
            <E T="54">X</E>
            <E T="03">span control.</E> When adjusting the analyzer's NO<E T="54">X</E> span control, the presence of any NO<E T="52">2</E> impurity in the standard NO cylinder must be taken into account. Procedures for determining the amount of NO<E T="52">2</E> impurity in the standard NO cylinder are given in reference 13. The exact NO<E T="54">X</E> concentration is calculated from:</P>
          <MATH DEEP="30" SPAN="1">
            <MID>ER31AU93.052</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">[NO<E T="52">X</E>]<E T="52">OUT</E> = diluted NO<E T="52">X</E> cencentration at the output manifold, ppm</FP>
          <FP SOURCE="FP-1">[NO<E T="52">2</E>]<E T="52">IMP</E> = concentration of NO<E T="52">2</E> impurity in the standard NO cylinder, ppm</FP>
          
          <FP>Adjust the NO<E T="54">X</E> span control to obtain a convenient recorder response as indicated below:</FP>
          
          <FP>recorder response (% scale)</FP>
          <MATH DEEP="30" SPAN="1">
            <MID>ER31AU93.053</MID>
          </MATH>
          <NOTE>
            <HD SOURCE="HED">Note:</HD>

            <P>If the analyzer has only one span control, the span adjustment is made on the NO channel and no further adjustment is made here for NO<E T="52">X</E>.</P>
          </NOTE>
          <FP>If substantial adjustment of the NO<E T="52">X</E> span control is necessary, it may be necessary to recheck the zero and span adjustments by repeating steps 2.4.7 and 2.4.8.2. Record the NO<E T="52">X</E> concentration and the analyzer's NO<E T="52">X</E> response.</FP>

          <P>2.4.8.3 Generate several additional concentrations (at least five evenly spaced points across the remaining scale are suggested to verify linearity) by decreasing F<E T="52">NO</E> or increasing <E T="03">F</E>
            <E T="54">D.</E> For each concentration generated, calculate the exact NO and NO<E T="52">X</E> concentrations using equations (16) and (18) respectively. Record the analyzer's NO and NO<E T="52">X</E> responses for each concentration. Plot the analyzer responses versus the respective calculated NO and NO<E T="52">X</E> concentrations and draw or calculate the NO and NO<E T="52">X</E> calibration curves. For subsequent calibrations where linearity can be assumed, these curves may be checked with a two-point calibration consisting of a zero point and NO and NO<E T="52">X</E> concentrations of approximately 80 percent of the URL.</P>
          <P>2.4.9 <E T="03">Preparation of NO</E>
            <E T="52">2</E>
            <E T="03">calibration curve.</E>
          </P>
          <P>2.4.9.1 Remove the NO flow. Assuming the NO<E T="52">2</E> zero has been properly adjusted while sampling zero air in step 2.4.7, switch the valve to provide NO<E T="52">2</E> at the output manifold.</P>
          <P>2.4.9.2 Adjust <E T="03">F</E>
            <E T="54">D</E> to generate an NO<E T="52">2</E> concentration of approximately 80 percent of the <E T="03">URL</E> of the NO<E T="52">2</E> range. The total air flow must exceed the demand of the analyzer(s) under calibration. The actual concentration of NO<E T="52">2</E> is calculated from:</P>
          <MATH DEEP="28" SPAN="1">
            <MID>ER31AU93.054</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">[NO<E T="52">2</E>]<E T="52">OUT</E> = diluted NO<E T="52">2</E> concentration at the output manifold, ppm</FP>
          <FP SOURCE="FP-1">
            <E T="03">R</E> = permeation rate, µg/min</FP>
          <FP SOURCE="FP-1">
            <E T="03">K</E> = 0.532 µl NO<E T="52">2</E>/µg NO<E T="52">2</E> (at 25 °C and 760 mm Hg)</FP>
          <FP SOURCE="FP-1">
            <E T="03">F</E>
            <E T="54">p</E> = air flowrate across permeation device, scm<SU>3</SU>/min</FP>
          <FP SOURCE="FP-1">
            <E T="03">F</E>
            <E T="54">D</E> = diluent air flowrate, scm<SU>3</SU>/min</FP>
          
          <PRTPAGE P="53"/>
          <FP>Sample this NO<E T="52">2</E> concentration until the NO<E T="52">X</E> and NO<E T="52">2</E> responses have stabilized. Adjust the NO<E T="52">2</E> span control to obtain a recorder response as indicated below:</FP>
          
          <FP>recorder response (% scale)</FP>
          <MATH DEEP="30" SPAN="1">
            <MID>ER31AU93.055</MID>
          </MATH>
          <NOTE>
            <HD SOURCE="HED">Note:</HD>

            <P>If the analyzer has only one or two span controls, the span adjustments are made on the NO channel or NO and NO<E T="52">X</E> channels and no further adjustment is made here for NO<E T="52">2</E>.</P>
          </NOTE>
          
          <FP>If substantial adjustment of the NO<E T="52">2</E> span control is necessary it may be necessary to recheck the zero and span adjustments by repeating steps 2.4.7 and 2.4.9.2. Record the NO<E T="52">2</E> concentration and the analyzer's NO<E T="52">2</E> response. Using the NO<E T="52">X</E> calibration curve obtained in step 2.4.8, measure and record the NO<E T="52">X</E> concentration as [NO<E T="52">X</E>]<E T="52">M</E>.</FP>
          <P>2.4.9.3 Adjust <E T="03">F</E>
            <E T="54">D</E> to obtain several other concentrations of NO<E T="52">2</E> over the NO<E T="52">2</E> range (at least five evenly spaced points across the remaining scale are suggested). Calculate each NO<E T="52">2</E> concentration using equation (20) and record the corresponding analyzer NO<E T="52">2</E> and NO<E T="52">X</E> responses. Plot the analyzer's NO<E T="52">2</E> responses versus the corresponding calculated NO<E T="52">2</E> concentrations and draw or calculate the NO<E T="52">2</E> calibration curve.</P>
          <P>2.4.10 <E T="03">Determination of converter efficiency.</E>
          </P>
          <P>2.4.10.1 Plot [NO<E T="52">X</E>]<E T="52">M</E> (y-axis) versus [NO<E T="52">2</E>]<E T="52">OUT</E> (x-axis) and draw or calculate the converter efficiency curve. The slope of the curve times 100 is the average converter efficiency, <E T="03">E</E>
            <E T="54">C.</E> The average converter efficiency must be greater than 96 percent; if it is less than 96 percent, replace or service the converter.</P>
          <NOTE>
            <HD SOURCE="HED">Note:</HD>
            <P>Supplemental information on calibration and other procedures in this method are given in reference 13.</P>
          </NOTE>
          <P>3. <E T="03">Frequency of calibration.</E> The frequency of calibration, as well as the number of points necessary to establish the calibration curve and the frequency of other performance checks, will vary from one analyzer to another. The user's quality control program should provide guidelines for initial establishment of these variables and for subsequent alteration as operational experience is accumulated. Manufacturers of analyzers should include in their instruction/operation manuals information and guidance as to these variables and on other matters of operation, calibration, and quality control.</P>
          <HD SOURCE="HD1">References</HD>
          <P>1. A. Fontijn, A. J. Sabadell, and R. J. Ronco, “Homogeneous Chemiluminescent Measurement of Nitric Oxide with Ozone,” Anal. Chem., 42, 575 (1970).</P>
          <P>2. D. H. Stedman, E. E. Daby, F. Stuhl, and H. Niki, “Analysis of Ozone and Nitric Oxide by a Chemiluminiscent Method in Laboratory and Atmospheric Studies of Photochemical Smog,” J. Air Poll. Control Assoc., 22, 260 (1972).</P>
          <P>3. B. E. Martin, J. A. Hodgeson, and R. K. Stevens, “Detection of Nitric Oxide Chemiluminescence at Atmospheric Pressure,” Presented at 164th National ACS Meeting, New York City, August 1972.</P>
          <P>4. J. A. Hodgeson, K. A. Rehme, B. E. Martin, and R. K. Stevens, “Measurements for Atmospheric Oxides of Nitrogen and Ammonia by Chemiluminescence,” Presented at 1972 APCA Meeting, Miami, FL, June 1972.</P>
          <P>5. R. K. Stevens and J. A. Hodgeson, “Applications of Chemiluminescence Reactions to the Measurement of Air Pollutants,” Anal. Chem., 45, 443A (1973).</P>

          <P>6. L. P. Breitenbach and M. Shelef, “Development of a Method for the Analysis of NO<E T="52">2</E> and NH<E T="52">3</E> by NO-Measuring Instruments,” J. Air Poll. Control Assoc., 23, 128 (1973).</P>

          <P>7. A. M. Winer, J. W. Peters, J. P. Smith, and J. N. Pitts, Jr., “Response of Commercial Chemiluminescent NO-NO<E T="52">2</E> Analyzers to Other Nitrogen-Containing Compounds,” Environ. Sci. Technol., 8, 1118 (1974).</P>
          <P>8. K. A. Rehme, B. E. Martin, and J. A. Hodgeson, Tentative Method for the Calibration of Nitric Oxide, Nitrogen Dioxide, and Ozone Analyzers by Gas Phase Titration,” EPA-R2-73-246, March 1974.</P>
          <P>9. J. A. Hodgeson, R. K. Stevens, and B. E. Martin, “A Stable Ozone Source Applicable as a Secondary Standard for Calibration of Atmospheric Monitors,” ISA Transactions, 11, 161 (1972).</P>
          <P>10. A. E. O'Keeffe and G. C. Ortman, “Primary Standards for Trace Gas Analysis,” Anal. Chem., 38, 760 (1966).</P>
          <P>11. F. P. Scaringelli, A. E. O'Keeffe, E. Rosenberg, and J. P. Bell, “Preparation of Known Concentrations of Gases and Vapors with Permeation Devices Calibrated Gravimetrically,” Anal. Chem., 42, 871 (1970).</P>

          <P>12. H. L. Rook, E. E. Hughes, R. S. Fuerst, and J. H. Margeson, “Operation Characteristics of NO<E T="52">2</E> Permeation Devices,” Presented at 167th National ACS Meeting, Los Angeles, CA, April 1974.</P>
          <P>13. E. C. Ellis, “Technical Assistance Document for the Chemiluminescence Measurement of Nitrogen Dioxide,” EPA-E600/4-75-003 (Available in draft form from the United States Environmental Protection Agency, Department E (MD-76), Environmental Monitoring and Support Laboratory, Research Triangle Park, NC 27711).</P>

          <P>14. A Procedure for Establishing Traceability of Gas Mixtures to Certain National Bureau of Standards Standard Reference Materials. EPA-600/7-81-010, Joint publication by NBS and EPA. Available from the U.S. Environmental Protection Agency, Environmental Monitoring Systems Laboratory (MD-77), Research Triangle Park, NC 27711, May 1981.<PRTPAGE P="54"/>
          </P>
          <P>15. <E T="03">Quality Assurance Handbook for Air Pollution Measurement Systems, Volume II, Ambient Air Specific Methods.</E> The U.S. Environmental Protection Agency, Environmental Monitoring Systems Laboratory, Research Triangle Park, NC 27711. Publication No. EAP-600/4-77-027a.</P>
          <GPH DEEP="254" SPAN="2">
            <GID>50-761.eps</GID>
          </GPH>
          <GPH DEEP="216" SPAN="2">
            <PRTPAGE P="55"/>
            <GID>50-762.eps</GID>
          </GPH>
          <CITA>[41 FR 52688, Dec. 1, 1976, as amended at 48 FR 2529, Jan 20, 1983]</CITA>
        </APPENDIX>
        <APPENDIX>
          <EAR>Pt. 50, App. G</EAR>
          <HD SOURCE="HED">Appendix G to Part 50—Reference Method for the Determination of Lead in Suspended Particulate Matter Collected From Ambient Air</HD>
          <P>1. <E T="03">Principle and applicability.</E>
          </P>

          <P>1.1 Ambient air suspended particulate matter is collected on a glass-fiber filter for 24 hours using a high volume air sampler. The analysis of the 24-hour samples may be performed for either individual samples or composites of the samples collected over a calendar month or quarter, provided that the compositing procedure has been approved in accordance with section 2.8 of appendix C to part 58 of this chapter—<E T="03">Modifications of methods by users.</E> (Guidance or assistance in requesting approval under Section 2.8 can be obtained from the address given in section 2.7 of appendix C to part 58 of this chapter.)</P>

          <P>1.2 Lead in the particulate matter is solubilized by extraction with nitric acid (HNO<E T="52">3</E>), facilitated by heat or by a mixture of HNO<E T="52">3</E> and hydrochloric acid (HCl) facilitated by ultrasonication.</P>
          <P>1.3 The lead content of the sample is analyzed by atomic absorption spectrometry using an air-acetylene flame, the 283.3 or 217.0 nm lead absorption line, and the optimum instrumental conditions recommended by the manufacturer.</P>
          <P>1.4 The ultrasonication extraction with HNO<E T="52">3</E>/HCl will extract metals other than lead from ambient particulate matter.</P>
          <P>2. <E T="03">Range, sensitivity, and lower detectable limit.</E> The values given below are typical of the methods capabilities. Absolute values will vary for individual situations depending on the type of instrument used, the lead line, and operating conditions.</P>
          <P>2.1 <E T="03">Range.</E> The typical range of the method is 0.07 to 7.5 µg Pb/m<SU>3</SU> assuming an upper linear range of analysis of 15 µg/ml and an air volume of 2,400 m<SU>3</SU>.</P>
          <P>2.2 <E T="03">Sensitivity.</E> Typical sensitivities for a 1 percent change in absorption (0.0044 absorbance units) are 0.2 and 0.5 µg Pb/ml for the 217.0 and 283.3 nm lines, respectively.</P>
          <P>2.3 <E T="03">Lower detectable limit (LDL).</E> A typical LDL is 0.07 µg Pb/m<SU>3</SU>. The above value was calculated by doubling the between-laboratory standard deviation obtained for the lowest measurable lead concentration in a collaborative test of the method.(<E T="03">15</E>) An air volume of 2,400 m<SU>3</SU> was assumed.</P>
          <P>3. <E T="03">Interferences.</E> Two types of interferences are possible: chemical and light scattering.</P>
          <P>3.1 <E T="03">Chemical.</E> Reports on the absence (<E T="03">1, 2, 3, 4, 5</E>) of chemical interferences far outweigh those reporting their presence, (<E T="03">6</E>) therefore, no correction for chemical interferences is given here. If the analyst suspects that the sample matrix is causing a chemical interference, the interference can be verified and corrected for by carrying out the analysis <PRTPAGE P="56"/>with and without the method of standard additions.(<E T="03">7</E>)</P>
          <P>3.2 <E T="03">Light scattering.</E> Nonatomic absorption or light scattering, produced by high concentrations of dissolved solids in the sample, can produce a significant interference, especially at low lead concentrations. (<E T="03">2</E>) The interference is greater at the 217.0 nm line than at the 283.3 nm line. No interference was observed using the 283.3 nm line with a similar method.(<E T="03">1</E>)</P>
          <P>Light scattering interferences can, however, be corrected for instrumentally. Since the dissolved solids can vary depending on the origin of the sample, the correction may be necessary, especially when using the 217.0 nm line. Dual beam instruments with a continuum source give the most accurate correction. A less accurate correction can be obtained by using a nonabsorbing lead line that is near the lead analytical line. Information on use of these correction techniques can be obtained from instrument manufacturers' manuals.</P>

          <P>If instrumental correction is not feasible, the interference can be eliminated by use of the ammonium pyrrolidinecarbodithioate-methylisobutyl ketone, chelation-solvent extraction technique of sample preparation.(<E T="03">8</E>)</P>
          <P>4. <E T="03">Precision and bias.</E>
          </P>

          <P>4.1 The high-volume sampling procedure used to collect ambient air particulate matter has a between-laboratory relative standard deviation of 3.7 percent over the range 80 to 125 µg/m<SU>3</SU>.(<E T="03">9</E>) The combined extraction-analysis procedure has an average within-laboratory relative standard deviation of 5 to 6 percent over the range 1.5 to 15 µg Pb/ml, and an average between laboratory relative standard deviation of 7 to 9 percent over the same range. These values include use of either extraction procedure.</P>

          <P>4.2 Single laboratory experiments and collaborative testing indicate that there is no significant difference in lead recovery between the hot and ultrasonic extraction procedures.(<E T="03">15</E>)</P>
          <P>5. <E T="03">Apparatus.</E>
          </P>
          <P>5.1 <E T="03">Sampling.</E>
          </P>
          <P>5.1.1 <E T="03">High-Volume Sampler.</E> Use and calibrate the sampler as described in appendix B to this part.</P>
          <P>5.2 <E T="03">Analysis.</E>
          </P>
          <P>5.2.1 <E T="03">Atomic absorption spectrophotometer.</E> Equipped with lead hollow cathode or electrodeless discharge lamp.</P>
          <P>5.2.1.1 <E T="03">Acetylene.</E> The grade recommended by the instrument manufacturer should be used. Change cylinder when pressure drops below 50-100 psig.</P>
          <P>5.2.1.2 <E T="03">Air.</E> Filtered to remove particulate, oil, and water.</P>
          <P>5.2.2 <E T="03">Glassware.</E> Class A borosilicate glassware should be used throughout the analysis.</P>
          <P>5.2.2.1 <E T="03">Beakers.</E> 30 and 150 ml. graduated, Pyrex.</P>
          <P>5.2.2.2 <E T="03">Volumetric flasks.</E> 100-ml.</P>
          <P>5.2.2.3 <E T="03">Pipettes.</E> To deliver 50, 30, 15, 8, 4, 2, 1 ml.</P>
          <P>5.2.2.4 <E T="03">Cleaning.</E> All glassware should be scrupulously cleaned. The following procedure is suggested. Wash with laboratory detergent, rinse, soak for 4 hours in 20 percent (w/w) HNO<E T="52">3</E>, rinse 3 times with distilled-deionized water, and dry in a dust free manner.</P>
          <P>5.2.3 <E T="03">Hot plate.</E>
          </P>
          <P>5.2.4. <E T="03">Ultrasonication water bath, unheated.</E> Commercially available laboratory ultrasonic cleaning baths of 450 watts or higher “cleaning power,” i.e., actual ultrasonic power output to the bath have been found satisfactory.</P>
          <P>5.2.5 <E T="03">Template.</E> To aid in sectioning the glass-fiber filter. See figure 1 for dimensions.</P>
          <P>5.2.6 <E T="03">Pizza cutter.</E> Thin wheel. Thickness 1mm.</P>
          <P>5.2.7 <E T="03">Watch glass.</E>
          </P>
          <P>5.2.8 <E T="03">Polyethylene bottles.</E> For storage of samples. Linear polyethylene gives better storage stability than other polyethylenes and is preferred.</P>
          <P>5.2.9 Parafilm “M”.<SU>1</SU>
            <FTREF/> American Can Co., Marathon Products, Neenah, Wis., or equivalent.</P>
          <FTNT>
            <P>
              <SU>1</SU> Mention of commercial products does not imply endorsement by the U.S. Environmental Protection Agency.</P>
          </FTNT>
          <P>6. <E T="03">Reagents.</E>
          </P>
          <P>6.1 <E T="03">Sampling.</E>
          </P>
          <P>6.1.1 <E T="03">Glass fiber filters.</E> The specifications given below are intended to aid the user in obtaining high quality filters with reproducible properties. These specifications have been met by EPA contractors.</P>
          <P>6.1.1.1 <E T="03">Lead content.</E> The absolute lead content of filters is not critical, but low values are, of course, desirable. EPA typically obtains filters with a lead content of 75 µg/filter.</P>
          <P>It is important that the variation in lead content from filter to filter, within a given batch, be small.</P>
          <P>6.1.1.2 <E T="03">Testing.</E>
          </P>
          <P>6.1.1.2.1 For large batches of filters (&gt;500 filters) select at random 20 to 30 filters from a given batch. For small batches (&gt;500 filters) a lesser number of filters may be taken. Cut one <FR>3/4</FR>″×8″ strip from each filter anywhere in the filter. Analyze all strips, separately, according to the directions in sections 7 and 8.</P>
          <P>6.1.1.2.2 Calculate the total lead in each filter as</P>
          <MATH DEEP="26" SPAN="1">
            <MID>EC08NO91.084</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">F<E T="52">b</E> = Amount of lead per 72 square inches of filter, µg.</FP>
          
          <P>6.1.1.2.3 Calculate the mean, F<E T="52">b</E>, of the values and the relative standard deviation <PRTPAGE P="57"/>(standard deviation/mean × 100). If the relative standard deviation is high enough so that, in the analysts opinion, subtraction of F<E T="52">b</E>, (section 10.3) may result in a significant error in the µg Pb/m<SU>3</SU>, the batch should be rejected.</P>
          <P>6.1.1.2.4 For acceptable batches, use the value of F<E T="52">b</E> to correct all lead analyses (section 10.3) of particulate matter collected using that batch of filters. If the analyses are below the LDL (section 2.3) no correction is necessary.</P>
          <P>6.2 <E T="03">Analysis.</E>
          </P>
          <P>6.2.1 Concentrated (15.6 <E T="03">M)</E> HNO<E T="52">3</E>. ACS reagent grade HNO<E T="52">3</E> and commercially available redistilled HNO<E T="52">3</E> has found to have sufficiently low lead concentrations.</P>
          <P>6.2.2 Concentrated (11.7 <E T="03">M</E>) HCl. ACS reagent grade.</P>
          <P>6.2.3 <E T="03">Distilled-deionized water.</E> (D.I. water).</P>
          <P>6.2.4 3 <E T="03">M</E> HNO<E T="52">3</E>. This solution is used in the hot extraction procedure. To prepare, add 192 ml of concentrated HNO<E T="52">3</E> to D.I. water in a 1 <E T="03">l</E> volumetric flask. Shake well, cool, and dilute to volume with D.I. water. <E T="03">Caution:</E> Nitric acid fumes are toxic. Prepare in a well ventilated fume hood.</P>
          <P>6.2.5 0.45 <E T="03">M</E> HNO<E T="52">3</E>. This solution is used as the matrix for calibration standards when using the hot extraction procedure. To prepare, add 29 ml of concentrated HNO<E T="52">3</E> to D.I. water in a 1 <E T="03">l</E> volumetric flask. Shake well, cool, and dilute to volume with D.I. water.</P>
          <P>6.2.6 2.6 <E T="03">M</E> HNO<E T="52">3</E>+0 to 0.9 <E T="03">M</E> HCl. This solution is used in the ultrasonic extraction procedure. The concentration of HCl can be varied from 0 to 0.9 <E T="03">M.</E> Directions are given for preparation of a 2.6 <E T="03">M</E> HNO<E T="52">3</E>+0.9 <E T="03">M</E> HCl solution. Place 167 ml of concentrated HNO<E T="52">3</E> into a 1 <E T="03">l</E> volumetric flask and add 77 ml of concentrated HCl. Stir 4 to 6 hours, dilute to nearly 1 <E T="03">l</E> with D.I. water, cool to room temperature, and dilute to 1 <E T="03">l</E>.</P>
          <P>6.2.7 0.40 <E T="03">M</E> HNO<E T="52">3</E> + X <E T="03">M</E> HCl. This solution is used as the matrix for calibration standards when using the ultrasonic extraction procedure. To prepare, add 26 ml of concentrated HNO<E T="52">3</E>, plus the ml of HCl required, to a 1 <E T="03">l</E> volumetric flask. Dilute to nearly 1 <E T="03">l</E> with D.I. water, cool to room temperature, and dilute to 1 <E T="03">l.</E> The amount of HCl required can be determined from the following equation:</P>
          <MATH DEEP="24" SPAN="1">
            <MID>EC08NO91.085</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">y = ml of concentrated HCl required.</FP>
          <FP SOURCE="FP-1">x = molarity of HCl in 6.2.6.</FP>
          <FP SOURCE="FP-1">0.15 = dilution factor in 7.2.2.</FP>
          
          <P>6.2.8 Lead nitrate, Pb(NO<E T="52">3</E>)<E T="52">2</E>. ACS reagent grade, purity 99.0 percent. Heat for 4 hours at 120 °C and cool in a desiccator.</P>
          <P>6.3 <E T="03">Calibration standards.</E>
          </P>
          <P>6.3.1 Master standard, 1000 µg Pb/ml in HNO<E T="52">3</E>. Dissolve 1.598 g of Pb(NO<E T="52">3</E>)<E T="52">2</E> in 0.45 <E T="03">M</E> HNO<E T="52">3</E> contained in a 1 <E T="03">l</E> volumetric flask and dilute to volume with 0.45 <E T="03">M</E> HNO<E T="52">3</E>.</P>
          <P>6.3.2 Master standard, 1000 µg Pb/ml in HNO<E T="52">3</E>/HCl. Prepare as in section 6.3.1 except use the HNO<E T="52">3</E>/HCl solution in section 6.2.7.</P>
          <P>Store standards in a polyethylene bottle. Commercially available certified lead standard solutions may also be used.</P>
          <P>7. <E T="03">Procedure.</E>
          </P>
          <P>7.1 <E T="03">Sampling.</E> Collect samples for 24 hours using the procedure described in reference <E T="03">10</E> with glass-fiber filters meeting the specifications in section 6.1.1. Transport collected samples to the laboratory taking care to minimize contamination and loss of sample. (<E T="03">16).</E>
          </P>
          <P>7.2 <E T="03">Sample preparation.</E>
          </P>
          <P>7.2.1 <E T="03">Hot extraction procedure.</E>
          </P>
          <P>7.2.1.1 Cut a <FR>3/4</FR>″×8″ strip from the exposed filter using a template and a pizza cutter as described in Figures 1 and 2. Other cutting procedures may be used.</P>
          <P>Lead in ambient particulate matter collected on glass fiber filters has been shown to be uniformly distributed across the filter. <SU>1,3,11</SU> Another study <SU>12</SU> has shown that when sampling near a roadway, strip position contributes significantly to the overall variability associated with lead analyses. Therefore, when sampling near a roadway, additional strips should be analyzed to minimize this variability.</P>

          <P>7.2.1.2 Fold the strip in half twice and place in a 150-ml beaker. Add 15 ml of 3 <E T="03">M</E> HNO<E T="52">3</E> to cover the sample. The acid should completely cover the sample. Cover the beaker with a watch glass.</P>

          <P>7.2.1.3 Place beaker on the hot-plate, contained in a fume hood, and boil gently for 30 min. Do not let the sample evaporate to dryness. <E T="03">Caution:</E> Nitric acid fumes are toxic.</P>
          <P>7.2.1.4 Remove beaker from hot plate and cool to near room temperature.</P>
          <P>7.2.1.5 Quantitatively transfer the sample as follows:</P>
          <P>7.2.1.5.1 Rinse watch glass and sides of beaker with D.I. water.</P>
          <P>7.2.1.5.2 Decant extract and rinsings into a 100-ml volumetric flask.</P>

          <P>7.2.1.5.3 Add D.I. water to 40 ml mark on beaker, cover with watch glass, and set aside for a minimum of 30 minutes. This is a critical step and cannot be omitted since it allows the HNO<E T="52">3</E> trapped in the filter to diffuse into the rinse water.</P>
          <P>7.2.1.5.4 Decant the water from the filter into the volumetric flask.</P>
          <P>7.2.1.5.5 Rinse filter and beaker twice with D.I. water and add rinsings to volumetric flask until total volume is 80 to 85 ml.</P>
          <P>7.2.1.5.6 Stopper flask and shake vigorously. Set aside for approximately 5 minutes or until foam has dissipated.</P>

          <P>7.2.1.5.7 Bring solution to volume with D.I. water. Mix thoroughly.<PRTPAGE P="58"/>
          </P>
          <P>7.2.1.5.8 Allow solution to settle for one hour before proceeding with analysis.</P>
          <P>7.2.1.5.9 If sample is to be stored for subsequent analysis, transfer to a linear polyethylene bottle.</P>
          <P>7.2.2 <E T="03">Ultrasonic extraction procedure.</E>
          </P>
          <P>7.2.2.1 Cut a <FR>3/4</FR>″×8″ strip from the exposed filter as described in section 7.2.1.1.</P>

          <P>7.2.2.2 Fold the strip in half twice and place in a 30 ml beaker. Add 15 ml of the HNO<E T="52">3</E>/HCl solution in section 6.2.6. The acid should completely cover the sample. Cover the beaker with parafilm.</P>
          <P>The parafilm should be placed over the beaker such that none of the parafilm is in contact with water in the ultrasonic bath. Otherwise, rinsing of the parafilm (section 7.2.2.4.1) may contaminate the sample.</P>
          <P>7.2.2.3 Place the beaker in the ultrasonication bath and operate for 30 minutes.</P>
          <P>7.2.2.4 Quantitatively transfer the sample as follows:</P>
          <P>7.2.2.4.1 Rinse parafilm and sides of beaker with D.I. water.</P>
          <P>7.2.2.4.2 Decant extract and rinsings into a 100 ml volumetric flask.</P>
          <P>7.2.2.4.3 Add 20 ml D.I. water to cover the filter strip, cover with parafilm, and set aside for a minimum of 30 minutes. This is a critical step and cannot be omitted. The sample is then processed as in sections 7.2.1.5.4 through 7.2.1.5.9.</P>
          <NOTE>
            <HD SOURCE="HED">Note:</HD>

            <P>Samples prepared by the hot extraction procedure are now in 0.45 <E T="03">M</E> HNO<E T="52">3</E>. Samples prepared by the ultrasonication procedure are in 0.40 <E T="03">M</E> HNO<E T="52">3</E> + X <E T="03">M</E> HCl.</P>
          </NOTE>
          <P>8. <E T="03">Analysis.</E>
          </P>
          <P>8.1 Set the wavelength of the monochromator at 283.3 or 217.0 nm. Set or align other instrumental operating conditions as recommended by the manufacturer.</P>
          <P>8.2 The sample can be analyzed directly from the volumetric flask, or an appropriate amount of sample decanted into a sample analysis tube. In either case, care should be taken not to disturb the settled solids.</P>
          <P>8.3 Aspirate samples, calibration standards and blanks (section 9.2) into the flame and record the equilibrium absorbance.</P>
          <P>8.4 Determine the lead concentration in µg Pb/ml, from the calibration curve, section 9.3.</P>
          <P>8.5 Samples that exceed the linear calibration range should be diluted with acid of the same concentration as the calibration standards and reanalyzed.</P>
          <P>9. <E T="03">Calibration.</E>
          </P>
          <P>9.1 <E T="03">Working standard,</E> 20 µg Pb/ml. Prepared by diluting 2.0 ml of the master standard (section 6.3.1 if the hot acid extraction was used or section 6.3.2 if the ultrasonic extraction procedure was used) to 100 ml with acid of the same concentration as used in preparing the master standard.</P>
          <P>9.2 <E T="03">Calibration standards.</E> Prepare daily by diluting the working standard, with the same acid matrix, as indicated below. Other lead concentrations may be used.</P>
          <GPOTABLE CDEF="s50,9,9" COLS="3" OPTS="L2">
            <BOXHD>
              <CHED H="1">Volume of 20 µg/ml working standard, ml</CHED>
              <CHED H="1">Final volume, ml</CHED>
              <CHED H="1">Concentration µg Pb/ml</CHED>
            </BOXHD>
            <ROW>
              <ENT I="01">0</ENT>
              <ENT>100</ENT>
              <ENT>0</ENT>
            </ROW>
            <ROW>
              <ENT I="01">1.0</ENT>
              <ENT>200</ENT>
              <ENT>0.1</ENT>
            </ROW>
            <ROW>
              <ENT I="01">2.0</ENT>
              <ENT>200</ENT>
              <ENT>0.2</ENT>
            </ROW>
            <ROW>
              <ENT I="01">2.0</ENT>
              <ENT>100</ENT>
              <ENT>0.4</ENT>
            </ROW>
            <ROW>
              <ENT I="01">4.0</ENT>
              <ENT>100</ENT>
              <ENT>0.8</ENT>
            </ROW>
            <ROW>
              <ENT I="01">8.0</ENT>
              <ENT>100</ENT>
              <ENT>1.6</ENT>
            </ROW>
            <ROW>
              <ENT I="01">15.0</ENT>
              <ENT>100</ENT>
              <ENT>3.0</ENT>
            </ROW>
            <ROW>
              <ENT I="01">30.0</ENT>
              <ENT>100</ENT>
              <ENT>6.0</ENT>
            </ROW>
            <ROW>
              <ENT I="01">50.0</ENT>
              <ENT>100</ENT>
              <ENT>10.0</ENT>
            </ROW>
            <ROW>
              <ENT I="01">100.0</ENT>
              <ENT>100</ENT>
              <ENT>20.0</ENT>
            </ROW>
          </GPOTABLE>
          <P>9.3 <E T="03">Preparation of calibration curve.</E> Since the working range of analysis will vary depending on which lead line is used and the type of instrument, no one set of instructions for preparation of a calibration curve can be given. Select standards (plus the reagent blank), in the same acid concentration as the samples, to cover the linear absorption range indicated by the instrument manufacturer. Measure the absorbance of the blank and standards as in section 8.0. Repeat until good agreement is obtained between replicates. Plot absorbance (y-axis) versus concentration in µg Pb/ml (x-axis). Draw (or compute) a straight line through the linear portion of the curve. Do not force the calibration curve through zero. Other calibration procedures may be used.</P>
          <P>To determine stability of the calibration curve, remeasure—alternately—one of the following calibration standards for every 10th sample analyzed: Concentration ≤1 µg Pb/ml; concentration ≤10 µg Pb/ml. If either standard deviates by more than 5 percent from the value predicted by the calibration curve, recalibrate and repeat the previous 10 analyses.</P>
          <P>10. <E T="03">Calculation.</E>
          </P>
          <P>10.1 <E T="03">Measured air volume.</E> Calculate the measured air volume at Standard Temperature and Pressure as described in Reference 10.</P>
          <P>10.2 <E T="03">Lead concentration.</E> Calculate lead concentration in the air sample.</P>
          <MATH DEEP="38" SPAN="2">
            <PRTPAGE P="59"/>
            <MID>50-766.eps</MID>
          </MATH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">C = Concentration, µg Pb/sm<SU>3</SU>.</FP>
          <FP SOURCE="FP-1">µg Pb/ml = Lead concentration determined from section 8.</FP>
          <FP SOURCE="FP-1">100 ml/strip = Total sample volume.</FP>
          <FP SOURCE="FP-1">12 strips = Total useable filter area, 8″×9″. Exposed area of one strip, <FR>3/4</FR>″×7″.</FP>
          <FP SOURCE="FP-1">Filter = Total area of one strip, <FR>3/4</FR>″×8″.</FP>
          <FP SOURCE="FP-1">F<E T="52">b</E> = Lead concentration of blank filter, µg, from section 6.1.1.2.3.</FP>
          <FP SOURCE="FP-1">V<E T="52">STP</E> = Air volume from section 10.2.</FP>
          
          <P>11. <E T="03">Quality control.</E>
          </P>
          <P>
            <FR>3/4</FR>″×8″ glass fiber filter strips containing 80 to 2000 µg Pb/strip (as lead salts) and blank strips with zero Pb content should be used to determine if the method—as being used—has any bias. Quality control charts should be established to monitor differences between measured and true values. The frequency of such checks will depend on the local quality control program.</P>

          <P>To minimize the possibility of generating unreliable data, the user should follow practices established for assuring the quality of air pollution data, (<E T="03">13</E>) and take part in EPA's semiannual audit program for lead analyses.</P>
          <P>12. <E T="03">Trouble shooting.</E>
          </P>
          <P>1. During extraction of lead by the hot extraction procedure, it is important to keep the sample covered so that corrosion products—formed on fume hood surfaces which may contain lead—are not deposited in the extract.</P>
          <P>2. The sample acid concentration should minimize corrosion of the nebulizer. However, different nebulizers may require lower acid concentrations. Lower concentrations can be used provided samples and standards have the same acid concentration.</P>
          <P>3. Ashing of particulate samples has been found, by EPA and contractor laboratories, to be unnecessary in lead analyses by atomic absorption. Therefore, this step was omitted from the method.</P>
          <P>4. Filtration of extracted samples, to remove particulate matter, was specifically excluded from sample preparation, because some analysts have observed losses of lead due to filtration.</P>
          <P>5. If suspended solids should clog the nebulizer during analysis of samples, centrifuge the sample to remove the solids.</P>
          <P>13. <E T="03">Authority.</E>
          </P>
          <P>(Secs. 109 and 301(a), Clean Air Act, as amended (42 U.S.C. 7409, 7601(a)))</P>
          <P>14. <E T="03">References.</E>
          </P>

          <P>1. Scott, D. R. et al. “Atomic Absorption and Optical Emission Analysis of NASN Atmospheric Particulate Samples for Lead.” <E T="03">Envir. Sci. and Tech., 10,</E> 877-880 (1976).</P>
          <P>2. Skogerboe, R. K. et al. “Monitoring for Lead in the Environment.” pp. 57-66, Department of Chemistry, Colorado State University, Fort Collins, CO 80523. Submitted to National Science Foundation for publications, 1976.</P>

          <P>3. Zdrojewski, A. et al. “The Accurate Measurement of Lead in Airborne Particulates.” <E T="03">Inter. J. Environ. Anal. Chem., 2,</E> 63-77 (1972).</P>
          <P>4. Slavin, W., “Atomic Absorption Spectroscopy.” Published by Interscience Company, New York, NY (1968).</P>
          <P>5. Kirkbright, G. F., and Sargent, M., “Atomic Absorption and Fluorescence Spectroscopy.” Published by Academic Press, New York, NY 1974.</P>
          <P>6. Burnham, C. D. et al., “Determination of Lead in Airborne Particulates in Chicago and Cook County, IL, by Atomic Absorption Spectroscopy.” Envir. Sci. and Tech., 3, 472-475 (1969).</P>

          <P>7. “Proposed Recommended Practices for Atomic Absorption Spectrometry.” <E T="03">ASTM Book of Standards,</E> part 30, pp. 1596-1608 (July 1973).</P>

          <P>8. Koirttyohann, S. R. and Wen, J. W., “Critical Study of the APCD-MIBK Extraction System for Atomic Absorption.” <E T="03">Anal. Chem., 45,</E> 1986-1989 (1973).</P>
          <P>9. <E T="03">Collaborative Study of Reference Method for the Determination of Suspended Particulates in the Atmosphere (High Volume Method).</E> Obtainable from National Technical Information Service, Department of Commerce, Port Royal Road, Springfield, VA 22151, as PB-205-891.</P>
          <P>10. [Reserved]</P>

          <P>11. Dubois, L., et al., “The Metal Content of Urban Air.” JAPCA, <E T="03">16,</E> 77-78 (1966).</P>
          <P>12. EPA Report No. 600/4-77-034, June 1977, “Los Angeles Catalyst Study Symposium.” Page 223.</P>
          <P>13. <E T="03">Quality Assurance Handbook for Air Pollution Measurement System. Volume 1—Principles.</E> EPA-600/9-76-005, March 1976.</P>

          <P>14. Thompson, R. J. et al., “Analysis of Selected Elements in Atmospheric Particulate Matter by Atomic Absorption.” <E T="03">Atomic Absorption Newsletter, 9,</E> No. 3, May-June 1970.</P>

          <P>15. To be published. EPA, QAB, EMSL, RTP, N.C. 27711<PRTPAGE P="60"/>
          </P>
          <P>16. <E T="03">Quality Assurance Handbook for Air Pollution Measurement Systems. Volume II—Ambient Air Specific Methods.</E> EPA-600/4-77/027a, May 1977.</P>
          <GPH DEEP="329" SPAN="2">
            <GID>50-767.eps</GID>
          </GPH>
          <GPH DEEP="366" SPAN="2">
            <PRTPAGE P="61"/>
            <GID>50-768.eps</GID>
          </GPH>
          <SECAUTH>(Secs. 109, 301(a) of the Clean Air Act, as amended (42 U.S.C. 7409, 7601(a)); secs. 110, 301(a) and 319 of the Clean Air Act (42 U.S.C. 7410, 7601(a), 7619))</SECAUTH>
          <CITA>[43 FR 46258, Oct. 5, 1978; 44 FR 37915, June 29, 1979, as amended at 46 FR 44163, Sept. 3, 1981; 52 FR 24664, July 1, 1987]</CITA>
        </APPENDIX>
        <APPENDIX>
          <EAR>Pt. 50, App. H</EAR>
          <HD SOURCE="HED">Appendix H to Part 50—Interpretation of the 1-Hour Primary and Secondary National Ambient Air Quality Standards for Ozone</HD>
          <HD SOURCE="HD1">1. General</HD>

          <P>This appendix explains how to determine when the expected number of days per calendar year with maximum hourly average concentrations above 0.12 ppm (235 µg/m<SU>3</SU>) is equal to or less than 1. An expanded discussion of these procedures and associated examples are contained in the “Guideline for Interpretation of Ozone Air Quality Standards.” For purposes of clarity in the following discussion, it is convenient to use the term “exceedance” to describe a daily maximum hourly average ozone measurement that is greater than the level of the standard. Therefore, the phrase “expected number of days with maximum hourly average ozone concentrations above the level of the standard” may be simply stated as the “expected number of exceedances.”<PRTPAGE P="62"/>
          </P>
          <P>The basic principle in making this determination is relatively straightforward. Most of the complications that arise in determining the expected number of annual exceedances relate to accounting for incomplete sampling. In general, the average number of exceedances per calendar year must be less than or equal to 1. In its simplest form, the number of exceedances at a monitoring site would be recorded for each calendar year and then averaged over the past 3 calendar years to determine if this average is less than or equal to 1.</P>
          <HD SOURCE="HD1">2. Interpretation of Expected Exceedances</HD>
          <P>The ozone standard states that the expected number of exceedances per year must be less than or equal to 1. The statistical term “expected number” is basically an arithmetic average. The following example explains what it would mean for an area to be in compliance with this type of standard. Suppose a monitoring station records a valid daily maximum hourly average ozone value for every day of the year during the past 3 years. At the end of each year, the number of days with maximum hourly concentrations above 0.12 ppm is determined and this number is averaged with the results of previous years. As long as this average remains “less than or equal to 1,” the area is in compliance.</P>
          <HD SOURCE="HD1">3. Estimating the Number of Exceedances for a Year</HD>
          <P>In general, a valid daily maximum hourly average value may not be available for each day of the year, and it will be necessary to account for these missing values when estimating the number of exceedances for a particular calendar year. The purpose of these computations is to determine if the expected number of exceedances per year is less than or equal to 1. Thus, if a site has two or more observed exceedances each year, the standard is not met and it is not necessary to use the procedures of this section to account for incomplete sampling.</P>
          <P>The term “missing value” is used here in the general sense to describe all days that do not have an associated ozone measurement. In some cases, a measurement might actually have been missed but in other cases no measurement may have been scheduled for that day. A daily maximum ozone value is defined to be the highest hourly ozone value recorded for the day. This daily maximum value is considered to be valid if 75 percent of the hours from 9:01 a.m. to 9:00 p.m. (LST) were measured or if the highest hour is greater than the level of the standard.</P>
          <P>In some areas, the seasonal pattern of ozone is so pronounced that entire months need not be sampled because it is extremely unlikely that the standard would be exceeded. Any such waiver of the ozone monitoring requirement would be handled under provisions of 40 CFR, part 58. Some allowance should also be made for days for which valid daily maximum hourly values were not obtained but which would quite likely have been below the standard. Such an allowance introduces a complication in that it becomes necessary to define under what conditions a missing value may be assumed to have been less than the level of the standard. The following criterion may be used for ozone:</P>
          <P>A missing daily maximum ozone value may be assumed to be less than the level of the standard if the valid daily maxima on both the preceding day and the following day do not exceed 75 percent of the level of the standard.</P>
          <P>Let z denote the number of missing daily maximum values that may be assumed to be less than the standard. Then the following formula shall be used to estimate the expected number of exceedances for the year:</P>
          <MATH DEEP="12" SPAN="1">
            <MID>EC08NO91.086</MID>
          </MATH>
          <P>(*Indicates multiplication.)
          </P>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">e = the estimated number of exceedances for the year,</FP>
          <FP SOURCE="FP-1">N = the number of required monitoring days in the year,</FP>
          <FP SOURCE="FP-1">n = the number of valid daily maxima,</FP>
          <FP SOURCE="FP-1">v = the number of daily values above the level of the standard, and</FP>
          <FP SOURCE="FP-1">z = the number of days assumed to be less than the standard level.</FP>
          
          <P>This estimated number of exceedances shall be rounded to one decimal place (fractional parts equal to 0.05 round up).</P>
          <P>It should be noted that N will be the total number of days in the year unless the appropriate Regional Administrator has granted a waiver under the provisions of 40 CFR part 58.</P>
          <P>The above equation may be interpreted intuitively in the following manner. The estimated number of exceedances is equal to the observed number of exceedances (v) plus an increment that accounts for incomplete sampling. There were (N-n) missing values for the year but a certain number of these, namely z, were assumed to be less than the standard. Therefore, (N-n-z) missing values are considered to include possible exceedances. The fraction of measured values that are above the level of the standard is v/n. It is assumed that this same fraction applies to the (N-n-z) missing values and that (v/n)*(N-n-z) of these values would also have exceeded the level of the standard.</P>
          <CITA>[44 FR 8220, Feb. 8, 1979, as amended at 62 FR 38895, July 18, 1997]</CITA>
        </APPENDIX>
        <APPENDIX>
          <PRTPAGE P="63"/>
          <EAR>Pt. 50, App. I</EAR>
          <HD SOURCE="HED">Appendix I to Part 50—Interpretation of the 8-Hour Primary and Secondary National Ambient Air Quality Standards for Ozone</HD>
          <P>1. <E T="03">General.</E>
          </P>
          <P>This appendix explains the data handling conventions and computations necessary for determining whether the national 8-hour primary and secondary ambient air quality standards for ozone specified in § 50.10 are met at an ambient ozone air quality monitoring site. Ozone is measured in the ambient air by a reference method based on appendix D of this part. Data reporting, data handling, and computation procedures to be used in making comparisons between reported ozone concentrations and the level of the ozone standard are specified in the following sections. Whether to exclude, retain, or make adjustments to the data affected by stratospheric ozone intrusion or other natural events is subject to the approval of the appropriate Regional Administrator.</P>
          <P>2. <E T="03">Primary and Secondary Ambient Air Quality Standards for Ozone.</E>
          </P>
          <P>2.1 <E T="03">Data Reporting and Handling Conventions.</E>
          </P>
          <P>2.1.1 <E T="03">Computing 8-hour averages.</E> Hourly average concentrations shall be reported in parts per million (ppm) to the third decimal place, with additional digits to the right being truncated. Running 8-hour averages shall be computed from the hourly ozone concentration data for each hour of the year and the result shall be stored in the first, or start, hour of the 8-hour period. An 8-hour average shall be considered valid if at least 75% of the hourly averages for the 8-hour period are available. In the event that only 6 (or 7) hourly averages are available, the 8-hour average shall be computed on the basis of the hours available using 6 (or 7) as the divisor. (8-hour periods with three or more missing hours shall not be ignored if, after substituting one-half the minimum detectable limit for the missing hourly concentrations, the 8-hour average concentration is greater than the level of the standard.) The computed 8-hour average ozone concentrations shall be reported to three decimal places (the insignificant digits to the right of the third decimal place are truncated, consistent with the data handling procedures for the reported data.)</P>
          <P>2.1.2 <E T="03">Daily maximum 8-hour average concentrations.</E> (a) There are 24 possible running 8-hour average ozone concentrations for each calendar day during the ozone monitoring season. (Ozone monitoring seasons vary by geographic location as designated in part 58, appendix D to this chapter.) The daily maximum 8-hour concentration for a given calendar day is the highest of the 24 possible 8-hour average concentrations computed for that day. This process is repeated, yielding a daily maximum 8-hour average ozone concentration for each calendar day with ambient ozone monitoring data. Because the 8-hour averages are recorded in the start hour, the daily maximum 8-hour concentrations from two consecutive days may have some hourly concentrations in common. Generally, overlapping daily maximum 8-hour averages are not likely, except in those non-urban monitoring locations with less pronounced diurnal variation in hourly concentrations.</P>
          <P>(b) An ozone monitoring day shall be counted as a valid day if valid 8-hour averages are available for at least 75% of possible hours in the day (i.e., at least 18 of the 24 averages). In the event that less than 75% of the 8-hour averages are available, a day shall also be counted as a valid day if the daily maximum 8-hour average concentration for that day is greater than the level of the ambient standard.</P>
          <P>2.2 <E T="03">Primary and Secondary Standard-related Summary Statistic.</E> The standard-related summary statistic is the annual fourth-highest daily maximum 8-hour ozone concentration, expressed in parts per million, averaged over three years. The 3-year average shall be computed using the three most recent, consecutive calendar years of monitoring data meeting the data completeness requirements described in this appendix. The computed 3-year average of the annual fourth-highest daily maximum 8-hour average ozone concentrations shall be expressed to three decimal places (the remaining digits to the right are truncated.)</P>
          <P>2.3 <E T="03">Comparisons with the Primary and Secondary Ozone Standards.</E> (a) The primary and secondary ozone ambient air quality standards are met at an ambient air quality monitoring site when the 3-year average of the annual fourth-highest daily maximum 8-hour average ozone concentration is less than or equal to 0.08 ppm. The number of significant figures in the level of the standard dictates the rounding convention for comparing the computed 3-year average annual fourth-highest daily maximum 8-hour average ozone concentration with the level of the standard. The third decimal place of the computed value is rounded, with values equal to or greater than 5 rounding up. Thus, a computed 3-year average ozone concentration of 0.085 ppm is the smallest value that is greater than 0.08 ppm.</P>

          <P>(b) This comparison shall be based on three consecutive, complete calendar years of air quality monitoring data. This requirement is met for the three year period at a monitoring site if daily maximum 8-hour average concentrations are available for at least 90%, on average, of the days during the designated ozone monitoring season, with a minimum data completeness in any one year of at least 75% of the designated sampling days. When <PRTPAGE P="64"/>computing whether the minimum data completeness requirements have been met, meteorological or ambient data may be sufficient to demonstrate that meteorological conditions on missing days were not conducive to concentrations above the level of the standard. Missing days assumed less than the level of the standard are counted for the purpose of meeting the data completeness requirement, subject to the approval of the appropriate Regional Administrator.</P>
          <P>(c) Years with concentrations greater than the level of the standard shall not be ignored on the ground that they have less than complete data. Thus, in computing the 3-year average fourth maximum concentration, calendar years with less than 75% data completeness shall be included in the computation if the average annual fourth maximum 8-hour concentration is greater than the level of the standard.</P>
          <P>(d) Comparisons with the primary and secondary ozone standards are demonstrated by examples 1 and 2 in paragraphs (d)(1) and (d) (2) respectively as follows:</P>
          <P>(1) As shown in example 1, the primary and secondary standards are met at this monitoring site because the 3-year average of the annual fourth-highest daily maximum 8-hour average ozone concentrations (i.e., 0.084 ppm) is less than or equal to 0.08 ppm. The data completeness requirement is also met because the average percent of days with valid ambient monitoring data is greater than 90%, and no single year has less than 75% data completeness.</P>
          <GPOTABLE CDEF="s10,10,10,10,10,10,10" COLS="7" OPTS="L2">
            <TTITLE>Example 1. Ambient monitoring site attaining the primary and secondary ozone standards</TTITLE>
            <BOXHD>
              <CHED H="1">Year</CHED>
              <CHED H="1">Percent Valid Days</CHED>
              <CHED H="1">1st Highest Daily Max 8-hour Conc. (ppm)</CHED>
              <CHED H="1">2nd Highest Daily Max 8-hour Conc. (ppm)</CHED>
              <CHED H="1">3rd Highest Daily Max 8-hour Conc. (ppm)</CHED>
              <CHED H="1">4th Highest Daily Max 8-hour Conc. (ppm)</CHED>
              <CHED H="1">5th Highest Daily Max 8-hour Conc. (ppm)</CHED>
            </BOXHD>
            <ROW RUL="s">
              <ENT I="01">1993</ENT>
              <ENT>100%</ENT>
              <ENT>0.092</ENT>
              <ENT>0.091</ENT>
              <ENT>0.090</ENT>
              <ENT>0.088</ENT>
              <ENT>0.085</ENT>
            </ROW>
            <ROW RUL="s">
              <ENT I="01">1994</ENT>
              <ENT>96%</ENT>
              <ENT>0.090</ENT>
              <ENT>0.089</ENT>
              <ENT>0.086</ENT>
              <ENT>0.084</ENT>
              <ENT>0.080</ENT>
            </ROW>
            <ROW RUL="d">
              <ENT I="01">1995</ENT>
              <ENT>98%</ENT>
              <ENT>0.087</ENT>
              <ENT>0.085</ENT>
              <ENT>0.083</ENT>
              <ENT>0.080</ENT>
              <ENT>0.075</ENT>
            </ROW>
            <ROW>
              <ENT I="03">Average</ENT>
              <ENT>98%</ENT>
            </ROW>
          </GPOTABLE>
          <P>(2) As shown in example 2, the primary and secondary standards are not met at this monitoring site because the 3-year average of the fourth-highest daily maximum 8-hour average ozone concentrations (i.e., 0.093 ppm) is greater than 0.08 ppm. Note that the ozone concentration data for 1994 is used in these computations, even though the data capture is less than 75%, because the average fourth-highest daily maximum 8-hour average concentration is greater than 0.08 ppm.</P>
          <GPOTABLE CDEF="s10,10,10,10,10,10,10" COLS="7" OPTS="L2">
            <TTITLE>Example 2. Ambient Monitoring Site Failing to Meet the Primary and Secondary Ozone Standards</TTITLE>
            <BOXHD>
              <CHED H="1">Year</CHED>
              <CHED H="1">Percent Valid Days</CHED>
              <CHED H="1">1st Highest Daily Max 8-hour Conc. (ppm)</CHED>
              <CHED H="1">2nd Highest Daily Max 8-hour Conc. (ppm)</CHED>
              <CHED H="1">3rd Highest Daily Max 8-hour Conc. (ppm)</CHED>
              <CHED H="1">4th Highest Daily Max 8-hour Conc. (ppm)</CHED>
              <CHED H="1">5th Highest Daily Max 8-hour Conc. (ppm)</CHED>
            </BOXHD>
            <ROW RUL="s">
              <ENT I="01">1993</ENT>
              <ENT>96%</ENT>
              <ENT>0.105</ENT>
              <ENT>0.103</ENT>
              <ENT>0.103</ENT>
              <ENT>0.102</ENT>
              <ENT>0.102</ENT>
            </ROW>
            <ROW RUL="s">
              <ENT I="01">1994</ENT>
              <ENT>74%</ENT>
              <ENT>0.090</ENT>
              <ENT>0.085</ENT>
              <ENT>0.082</ENT>
              <ENT>0.080</ENT>
              <ENT>0.078</ENT>
            </ROW>
            <ROW RUL="d">
              <ENT I="01">1995</ENT>
              <ENT>98%</ENT>
              <ENT>0.103</ENT>
              <ENT>0.101</ENT>
              <ENT>0.101</ENT>
              <ENT>0.097</ENT>
              <ENT>0.095</ENT>
            </ROW>
            <ROW>
              <ENT I="03">Average</ENT>
              <ENT>89%</ENT>
            </ROW>
          </GPOTABLE>
          <P>3. <E T="03">Design Values for Primary and Secondary Ambient Air Quality Standards for Ozone.</E> The air quality design value at a monitoring site is defined as that concentration that when reduced to the level of the standard ensures that the site meets the standard. For a concentration-based standard, the air quality design value is simply the standard-related test statistic. Thus, for the primary and secondary ozone standards, the 3-year average annual fourth-highest daily maximum 8-hour average ozone concentration is also the air quality design value for the site.</P>
          <CITA>[62 FR 38895, July 18, 1997]</CITA>
        </APPENDIX>
        <APPENDIX>
          <EAR>Pt. 50, App. J</EAR>

          <HD SOURCE="HED">Appendix J to Part 50—Reference Method for the Determination of Particulate Matter as PM<E T="52">10</E> in the Atmosphere</HD>
          <P>1.0 <E T="03">Applicability.</E>
            <PRTPAGE P="65"/>
          </P>

          <P>1.1 This method provides for the measurement of the mass concentration of particulate matter with an aerodynamic diameter less than or equal to a nominal 10 micrometers (PM<E T="52">1O</E>) in ambient air over a 24-hour period for purposes of determining attainment and maintenance of the primary and secondary national ambient air quality standards for particulate matter specified in § 50.6 of this chapter. The measurement process is nondestructive, and the PM<E T="52">10</E> sample can be subjected to subsequent physical or chemical analyses. Quality assurance procedures and guidance are provided in part 58, appendices A and B, of this chapter and in References 1 and 2.</P>
          <P>2.0 <E T="03">Principle.</E>
          </P>

          <P>2.1 An air sampler draws ambient air at a constant flow rate into a specially shaped inlet where the suspended particulate matter is inertially separated into one or more size fractions within the PM<E T="52">10</E> size range. Each size fraction in the PM<E T="52">1O</E> size range is then collected on a separate filter over the specified sampling period. The particle size discrimination characteristics (sampling effectiveness and 50 percent cutpoint) of the sampler inlet are prescribed as performance specifications in part 53 of this chapter.</P>

          <P>2.2 Each filter is weighed (after moisture equilibration) before and after use to determine the net weight (mass) gain due to collected PM<E T="52">10</E>. The total volume of air sampled, corrected to EPA reference conditions (25 C, 101.3 kPa), is determined from the measured flow rate and the sampling time. The mass concentration of PM<E T="52">10</E> in the ambient air is computed as the total mass of collected particles in the PM<E T="52">10</E> size range divided by the volume of air sampled, and is expressed in micrograms per standard cubic meter (µg/std m<SU>3</SU>). For PM<E T="52">10</E> samples collected at temperatures and pressures significantly different from EPA reference conditions, these corrected concentrations sometimes differ substantially from actual concentrations (in micrograms per actual cubic meter), particularly at high elevations. Although not required, the actual PM<E T="52">10</E> concentration can be calculated from the corrected concentration, using the average ambient temperature and barometric pressure during the sampling period.</P>
          <P>2.3 A method based on this principle will be considered a reference method only if (a) the associated sampler meets the requirements specified in this appendix and the requirements in part 53 of this chapter, and (b) the method has been designated as a reference method in accordance with part 53 of this chapter.</P>
          <P>3.0 <E T="03">Range.</E>
          </P>

          <P>3.1 The lower limit of the mass concentration range is determined by the repeatability of filter tare weights, assuming the nominal air sample volume for the sampler. For samplers having an automatic filter-changing mechanism, there may be no upper limit. For samplers that do not have an automatic filter-changing mechanism, the upper limit is determined by the filter mass loading beyond which the sampler no longer maintains the operating flow rate within specified limits due to increased pressure drop across the loaded filter. This upper limit cannot be specified precisely because it is a complex function of the ambient particle size distribution and type, humidity, filter type, and perhaps other factors. Nevertheless, all samplers should be capable of measuring 24-hour PM<E T="52">10</E> mass concentrations of at least 300 µg/std m<SU>3</SU> while maintaining the operating flow rate within the specified limits.</P>
          <P>4.0 <E T="03">Precision.</E>
          </P>
          <P>4.1 The precision of PM<E T="52">10</E> samplers must be 5 µg/m<SU>3</SU> for PM<E T="52">10</E> concentrations below 80 µg/m<SU>3</SU> and 7 percent for PM<E T="52">10</E> concentrations above 80 µg/m<SU>3</SU>, as required by part 53 of this chapter, which prescribes a test procedure that determines the variation in the PM<E T="52">10</E> concentration measurements of identical samplers under typical sampling conditions. Continual assessment of precision via collocated samplers is required by part 58 of this chapter for PM<E T="52">10</E> samplers used in certain monitoring networks.</P>
          <P>5.0 <E T="03">Accuracy.</E>
          </P>

          <P>5.1 Because the size of the particles making up ambient particulate matter varies over a wide range and the concentration of particles varies with particle size, it is difficult to define the absolute accuracy of PM<E T="52">10</E> samplers. Part 53 of this chapter provides a specification for the sampling effectiveness of PM<E T="52">10</E> samplers. This specification requires that the expected mass concentration calculated for a candidate PM<E T="52">10</E> sampler, when sampling a specified particle size distribution, be within ±10 percent of that calculated for an ideal sampler whose sampling effectiveness is explicitly specified. Also, the particle size for 50 percent sampling effectivensss is required to be 10 ±0.5 micrometers. Other specifications related to accuracy apply to flow measurement and calibration, filter media, analytical (weighing) procedures, and artifact. The flow rate accuracy of PM<E T="52">10</E> samplers used in certain monitoring networks is required by part 58 of this chapter to be assessed periodically via flow rate audits.</P>
          <P>6.0 <E T="03">Potential Sources of Error.</E>
          </P>
          <P>6.1 <E T="03">Volatile Particles.</E> Volatile particles collected on filters are often lost during shipment and/or storage of the filters prior to the post-sampling weighing <SU>3</SU>. Although shipment or storage of loaded filters is sometimes unavoidable, filters should be reweighed as soon as practical to minimize these losses.</P>
          <P>6.2 <E T="03">Artifacts.</E> Positive errors in PM<E T="52">10</E> concentration measurements may result from retention of gaseous species on filters. <SU>4,5</SU> Such errors include the retention of sulfur <PRTPAGE P="66"/>dioxide and nitric acid. Retention of sulfur dioxide on filters, followed by oxidation to sulfate, is referred to as artifact sulfate formation, a phenomenon which increases with increasing filter alkalinity. <SU>6</SU> Little or no artifact sulfate formation should occur using filters that meet the alkalinity specification in section 7.2.4. Artifact nitrate formation, resulting primarily from retention of nitric acid, occurs to varying degrees on many filter types, including glass fiber, cellulose ester, and many quartz fiber filters. <SU>5,7,8,9,10</SU> Loss of true atmospheric particulate nitrate during or following sampling may also occur due to dissociation or chemical reaction. This phenomenon has been observed on Teflon<E T="51">®</E> filters <SU>8</SU> and inferred for quartz fiber filters. <SU>11,12</SU> The magnitude of nitrate artifact errors in PM<E T="52">10</E> mass concentration measurements will vary with location and ambient temperature; however, for most sampling locations, these errors are expected to be small.</P>
          <P>6.3 <E T="03">Humidity.</E> The effects of ambient humidity on the sample are unavoidable. The filter equilibration procedure in section 9.0 is designed to minimize the effects of moisture on the filter medium.</P>
          <P>6.4 <E T="03">Filter Handling.</E> Careful handling of filters between presampling and postsampling weighings is necessary to avoid errors due to damaged filters or loss of collected particles from the filters. Use of a filter cartridge or cassette may reduce the magnitude of these errors. Filters must also meet the integrity specification in section 7.2.3.</P>
          <P>6.5 <E T="03">Flow Rate Variation.</E> Variations in the sampler's operating flow rate may alter the particle size discrimination characteristics of the sampler inlet. The magnitude of this error will depend on the sensitivity of the inlet to variations in flow rate and on the particle distribution in the atmosphere during the sampling period. The use of a flow control device (section 7.1.3) is required to minimize this error.</P>
          <P>6.6 <E T="03">Air Volume Determination.</E> Errors in the air volume determination may result from errors in the flow rate and/or sampling time measurements. The flow control device serves to minimize errors in the flow rate determination, and an elapsed time meter (section 7.1.5) is required to minimize the error in the sampling time measurement.</P>
          <P>7.0 <E T="03">Apparatus.</E>
          </P>
          <P>7.1 <E T="03">PM</E>
            <E T="52">10</E>
            <E T="03">Sampler.</E>
          </P>
          <P>7.1.1 The sampler shall be designed to:</P>
          <P>a. Draw the air sample into the sampler inlet and through the particle collection filter at a uniform face velocity.</P>
          <P>b. Hold and seal the filter in a horizontal position so that sample air is drawn downward through the filter.</P>
          <P>c. Allow the filter to be installed and removed conveniently.</P>
          <P>d. Protect the filter and sampler from precipitation and prevent insects and other debris from being sampled.</P>
          <P>e. Minimize air leaks that would cause error in the measurement of the air volume passing through the filter.</P>
          <P>f. Discharge exhaust air at a sufficient distance from the sampler inlet to minimize the sampling of exhaust air.</P>
          <P>g. Minimize the collection of dust from the supporting surface.</P>
          <P>7.1.2 The sampler shall have a sample air inlet system that, when operated within a specified flow rate range, provides particle size discrimination characteristics meeting all of the applicable performance specifications prescribed in part 53 of this chapter. The sampler inlet shall show no significant wind direction dependence. The latter requirement can generally be satisfied by an inlet shape that is circularly symmetrical about a vertical axis.</P>
          <P>7.1.3 The sampler shall have a flow control device capable of maintaining the sampler's operating flow rate within the flow rate limits specified for the sampler inlet over normal variations in line voltage and filter pressure drop.</P>
          <P>7.1.4 The sampler shall provide a means to measure the total flow rate during the sampling period. A continuous flow recorder is recommended but not required. The flow measurement device shall be accurate to ±2 percent.</P>
          <P>7.1.5 A timing/control device capable of starting and stopping the sampler shall be used to obtain a sample collection period of 24 ±1 hr (1,440 ±60 min). An elapsed time meter, accurate to within ±15 minutes, shall be used to measure sampling time. This meter is optional for samplers with continuous flow recorders if the sampling time measurement obtained by means of the recorder meets the ±15 minute accuracy specification.</P>
          <P>7.1.6 The sampler shall have an associated operation or instruction manual as required by part 53 of this chapter which includes detailed instructions on the calibration, operation, and maintenance of the sampler.</P>
          <P>7.2 <E T="03">Filters.</E>
          </P>
          <P>7.2.1 <E T="03">Filter Medium.</E> No commercially available filter medium is ideal in all respects for all samplers. The user's goals in sampling determine the relative importance of various filter characteristics (e.g., cost, ease of handling, physical and chemical characteristics, etc.) and, consequently, determine the choice among acceptable filters. Furthermore, certain types of filters may not be suitable for use with some samplers, particularly under heavy loading conditions (high mass concentrations), because of high or rapid increase in the filter flow resistance that would exceed the capability of the sampler's flow control device. However, samplers equipped with automatic filter-changing <PRTPAGE P="67"/>mechanisms may allow use of these types of filters. The specifications given below are minimum requirements to ensure acceptability of the filter medium for measurement of PM<E T="52">10</E> mass concentrations. Other filter evaluation criteria should be considered to meet individual sampling and analysis objectives.</P>
          <P>7.2.2 <E T="03">Collection Efficiency.</E> ≥99 percent, as measured by the DOP test (ASTM-2986) with 0.3 µm particles at the sampler's operating face velocity.</P>
          <P>7.2.3 <E T="03">Integrity.</E> ±5 µg/m<SU>3</SU> (assuming sampler's nominal 24-hour air sample volume). Integrity is measured as the PM<E T="52">10</E> concentration equivalent corresponding to the average difference between the initial and the final weights of a random sample of test filters that are weighed and handled under actual or simulated sampling conditions, but have no air sample passed through them (i.e., filter blanks). As a minimum, the test procedure must include initial equilibration and weighing, installation on an inoperative sampler, removal from the sampler, and final equilibration and weighing.</P>
          <P>7.2.4 <E T="03">Alkalinity.</E> &lt;25 microequivalents/gram of filter, as measured by the procedure given in Reference 13 following at least two months storage in a clean environment (free from contamination by acidic gases) at room temperature and humidity.</P>
          <P>7.3 <E T="03">Flow Rate Transfer Standard.</E> The flow rate transfer standard must be suitable for the sampler's operating flow rate and must be calibrated against a primary flow or volume standard that is traceable to the National Bureau of Standards (NBS). The flow rate transfer standard must be capable of measuring the sampler's operating flow rate with an accuracy of ±2 percent.</P>
          <P>7.4 <E T="03">Filter Conditioning Environment.</E>
          </P>
          <P>7.4.1 Temperature range: 15 to 30 C.</P>
          <P>7.4.2 Temperature control: ±3 C.</P>
          <P>7.4.3 Humidity range: 20% to 45% RH.</P>
          <P>7.4.4 Humidity control: ±5% RH.</P>
          <P>7.5 <E T="03">Analytical Balance.</E> The analytical balance must be suitable for weighing the type and size of filters required by the sampler. The range and sensitivity required will depend on the filter tare weights and mass loadings. Typically, an analytical balance with a sensitivity of 0.1 mg is required for high volume samplers (flow rates &gt;0.5 m<SU>3</SU>/min). Lower volume samplers (flow rates &lt;0.5 m<SU>3</SU>/min) will require a more sensitive balance.</P>
          <P>8.0 <E T="03">Calibration.</E>
          </P>
          <P>8.1 <E T="03">General Requirements.</E>
          </P>
          <P>8.1.1 Calibration of the sampler's flow measurement device is required to establish traceability of subsequent flow measurements to a primary standard. A flow rate transfer standard calibrated against a primary flow or volume standard shall be used to calibrate or verify the accuracy of the sampler's flow measurement device.</P>

          <P>8.1.2 Particle size discrimination by inertial separation requires that specific air velocities be maintained in the sampler's air inlet system. Therefore, the flow rate through the sampler's inlet must be maintained throughout the sampling period within the design flow rate range specified by the manufacturer. Design flow rates are specified as actual volumetric flow rates, measured at existing conditions of temperature and pressure (Q<E T="52">a</E>). In contrast, mass concentrations of PM<E T="52">10</E> are computed using flow rates corrected to EPA reference conditions of temperature and pressure (Q<E T="52">std</E>).</P>
          <P>8.2 <E T="03">Flow Rate Calibration Procedure.</E>
          </P>
          <P>8.2.1 PM<E T="52">10</E> samplers employ various types of flow control and flow measurement devices. The specific procedure used for flow rate calibration or verification will vary depending on the type of flow controller and flow indicator employed. Calibration in terms of actual volumetric flow rates (Q<E T="52">a</E>) is generally recommended, but other measures of flow rate (e.g., Q<E T="52">std</E>) may be used provided the requirements of section 8.1 are met. The general procedure given here is based on actual volumetric flow units (Q<E T="52">a</E>) and serves to illustrate the steps involved in the calibration of a PM<E T="52">10</E> sampler. Consult the sampler manufacturer's instruction manual and Reference 2 for specific guidance on calibration. Reference 14 provides additional information on the use of the commonly used measures of flow rate and their interrelationships.</P>
          <P>8.2.2 Calibrate the flow rate transfer standard against a primary flow or volume standard traceable to NBS. Establish a calibration relationship (e.g., an equation or family of curves) such that traceability to the primary standard is accurate to within 2 percent over the expected range of ambient conditions (i.e., temperatures and pressures) under which the transfer standard will be used. Recalibrate the transfer standard periodically.</P>
          <P>8.2.3 Following the sampler manufacturer's instruction manual, remove the sampler inlet and connect the flow rate transfer standard to the sampler such that the transfer standard accurately measures the sampler's flow rate. Make sure there are no leaks between the transfer standard and the sampler.</P>

          <P>8.2.4 Choose a minimum of three flow rates (actual m<SU>3</SU>/min), spaced over the acceptable flow rate range specified for the inlet (see 7.1.2) that can be obtained by suitable adjustment of the sampler flow rate. In accordance with the sampler manufacturer's instruction manual, obtain or verify the calibration relationship between the flow rate (actual m<SU>3</SU>/min) as indicated by the transfer standard and the sampler's flow indicator response. Record the ambient temperature and barometric pressure. Temperature and pressure corrections to subsequent flow indicator readings may be required for certain types of <PRTPAGE P="68"/>flow measurement devices. When such corrections are necessary, correction on an individual or daily basis is preferable. However, seasonal average temperature and average barometric pressure for the sampling site may be incorporated into the sampler calibration to avoid daily corrections. Consult the sampler manufacturer's instruction manual and Reference 2 for additional guidance.</P>
          <P>8.2.5 Following calibration, verify that the sampler is operating at its design flow rate (actual m<SU>3</SU>/min) with a clean filter in place.</P>
          <P>8.2.6 Replace the sampler inlet.</P>
          <P>9.0 <E T="03">Procedure.</E>
          </P>

          <P>9.1 The sampler shall be operated in accordance with the specific guidance provided in the sampler manufacturer's instruction manual and in Reference 2. The general procedure given here assumes that the sampler's flow rate calibration is based on flow rates at ambient conditions (Q<E T="52">a</E>) and serves to illustrate the steps involved in the operation of a PM<E T="52">10</E> sampler.</P>
          <P>9.2 Inspect each filter for pinholes, particles, and other imperfections. Establish a filter information record and assign an identification number to each filter.</P>
          <P>9.3 Equilibrate each filter in the conditioning environment (see 7.4) for at least 24 hours.</P>
          <P>9.4 Following equilibration, weigh each filter and record the presampling weight with the filter identification number.</P>
          <P>9.5 Install a preweighed filter in the sampler following the instructions provided in the sampler manufacturer's instruction manual.</P>
          <P>9.6 Turn on the sampler and allow it to establish run-temperature conditions. Record the flow indicator reading and, if needed, the ambient temperature and barometric pressure. Determine the sampler flow rate (actual m<SU>3</SU>/min) in accordance with the instructions provided in the sampler manufacturer's instruction manual. NOTE.—No onsite temperature or pressure measurements are necessary if the sampler's flow indicator does not require temperature or pressure corrections or if seasonal average temperature and average barometric pressure for the sampling site are incorporated into the sampler calibration (see step 8.2.4). If individual or daily temperature and pressure corrections are required, ambient temperature and barometric pressure can be obtained by on-site measurements or from a nearby weather station. Barometric pressure readings obtained from airports must be station pressure, not corrected to sea level, and may need to be corrected for differences in elevation between the sampling site and the airport.</P>
          <P>9.7 If the flow rate is outside the acceptable range specified by the manufacturer, check for leaks, and if necessary, adjust the flow rate to the specified setpoint. Stop the sampler.</P>
          <P>9.8 Set the timer to start and stop the sampler at appropriate times. Set the elapsed time meter to zero or record the initial meter reading.</P>
          <P>9.9 Record the sample information (site location or identification number, sample date, filter identification number, and sampler model and serial number).</P>
          <P>9.10 Sample for 24 ±1 hours.</P>
          <P>9.11 Determine and record the average flow rate (Q<AC T="8"/>
            <E T="52">a</E>) in actual m<SU>3</SU>/min for the sampling period in accordance with the instructions provided in the sampler manufacturer's instruction manual. Record the elapsed time meter final reading and, if needed, the average ambient temperature and barometric pressure for the sampling period (see note following step 9.6).</P>
          <P>9.12 Carefully remove the filter from the sampler, following the sampler manufacturer's instruction manual. Touch only the outer edges of the filter.</P>
          <P>9.13 Place the filter in a protective holder or container (e.g., petri dish, glassine envelope, or manila folder).</P>
          <P>9.14 Record any factors such as meteorological conditions, construction activity, fires or dust storms, etc., that might be pertinent to the measurement on the filter information record.</P>
          <P>9.15 Transport the exposed sample filter to the filter conditioning environment as soon as possible for equilibration and subsequent weighing.</P>
          <P>9.16 Equilibrate the exposed filter in the conditioning environment for at least 24 hours under the same temperature and humidity conditions used for presampling filter equilibration (see 9.3).</P>
          <P>9.17 Immediately after equilibration, reweigh the filter and record the postsampling weight with the filter identification number.</P>
          <P>10.0 <E T="03">Sampler Maintenance.</E>
          </P>
          <P>10.1 The PM<E T="52">10</E> sampler shall be maintained in strict accordance with the maintenance procedures specified in the sampler manufacturer's instruction manual.</P>
          <P>11.0 <E T="03">Calculations.</E>
          </P>

          <P>11.1 Calculate the average flow rate over the sampling period corrected to EPA reference conditions as Q<AC T="8"/>
            <E T="52">std</E>. When the sampler's flow indicator is calibrated in actual volumetric units (Q<E T="52">a</E>), Q<AC T="8"/>
            <E T="52">std</E> is calculated as:
          </P>
          <FP SOURCE="FP-1">Q<AC T="8"/>
            <E T="52">std</E>=Q<AC T="8"/>
            <E T="52">a</E>×(P<E T="52">av</E>/T<E T="52">av</E>)(T<E T="52">std</E>/P<E T="52">std</E>)</FP>
          
          <FP>where</FP>
          
          <FP SOURCE="FP-1">Q<AC T="8"/>
            <E T="52">std</E> = average flow rate at EPA reference conditions, std m<SU>3</SU>/min;</FP>
          <FP SOURCE="FP-1">Q<AC T="8"/>
            <E T="52">a</E> = average flow rate at ambient conditions, m<SU>3</SU>/min;</FP>
          <FP SOURCE="FP-1">P<E T="52">av</E> = average barometric pressure during the sampling period or average barometric pressure for the sampling site, kPa (or mm Hg);</FP>
          <FP SOURCE="FP-1">T<E T="52">av</E> = average ambient temperature during the sampling period or seasonal average <PRTPAGE P="69"/>ambient temperature for the sampling site, K;</FP>
          <FP SOURCE="FP-1">T<E T="52">std</E> = standard temperature, defined as 298 K;</FP>
          <FP SOURCE="FP-1">P<E T="52">std</E> = standard pressure, defined as 101.3 kPa (or 760 mm Hg).</FP>
          
          <P>11.2 Calculate the total volume of air sampled as:
          </P>
          <FP SOURCE="FP-1">V<E T="52">std</E> = Q<AC T="8"/>
            <E T="52">std</E>×t</FP>
          
          <FP>where</FP>
          
          <FP SOURCE="FP-1">V<E T="52">std</E> = total air sampled in standard volume units, std m<SU>3</SU>;</FP>
          <FP SOURCE="FP-1">t = sampling time, min.</FP>
          
          <P>11.3 Calculate the PM<E T="52">10</E> concentration as:
          </P>
          <FP SOURCE="FP-1">PM<E T="52">10</E> = (W<E T="52">f</E>−W<E T="52">i</E>)×10<SU>6</SU>/V<E T="52">std</E>
          </FP>
          
          <FP>where</FP>
          
          <FP SOURCE="FP-1">PM<E T="52">10</E> = mass concentration of PM<E T="52">10</E>, µg/std m<SU>3</SU>;</FP>
          <FP SOURCE="FP-1">W<E T="52">f</E>, W<E T="52">i</E> = final and initial weights of filter collecting PM<E T="52">1O</E> particles, g;</FP>
          <FP SOURCE="FP-1">10<SU>6</SU> = conversion of g to µg.</FP>
          
          <NOTE>
            <HD SOURCE="HED">Note:</HD>
            <P>If more than one size fraction in the PM<E T="52">10</E> size range is collected by the sampler, the sum of the net weight gain by each collection filter [Σ(W<E T="52">f</E>−W<E T="52">i</E>)] is used to calculate the PM<E T="52">10</E> mass concentration.</P>
          </NOTE>
          <P>12.0 <E T="03">References.</E>
          </P>
          <P>1. Quality Assurance Handbook for Air Pollution Measurement Systems, Volume I, Principles. EPA-600/9-76-005, March 1976. Available from CERI, ORD Publications, U.S. Environmental Protection Agency, 26 West St. Clair Street, Cincinnati, OH 45268.</P>
          <P>2. Quality Assurance Handbook for Air Pollution Measurement Systems, Volume II, Ambient Air Specific Methods. EPA-600/4-77-027a, May 1977. Available from CERI, ORD Publications, U.S. Environmental Protection Agency, 26 West St. Clair Street, Cincinnati, OH 45268.</P>
          <P>3. Clement, R.E., and F.W. Karasek. Sample Composition Changes in Sampling and Analysis of Organic Compounds in Aerosols. Int. J. Environ. Analyt. Chem., 7:109, 1979.</P>
          <P>4. Lee, R.E., Jr., and J. Wagman. A Sampling Anomaly in the Determination of Atmospheric Sulfate Concentration. Amer. Ind. Hyg. Assoc. J., 27:266, 1966.</P>
          <P>5. Appel, B.R., S.M. Wall, Y. Tokiwa, and M. Haik. Interference Effects in Sampling Particulate Nitrate in Ambient Air. Atmos. Environ., 13:319, 1979.</P>
          <P>6. Coutant, R.W. Effect of Environmental Variables on Collection of Atmospheric Sulfate. Environ. Sci. Technol., 11:873, 1977.</P>
          <P>7. Spicer, C.W., and P. Schumacher. Interference in Sampling Atmospheric Particulate Nitrate. Atmos. Environ., 11:873, 1977.</P>
          <P>8. Appel, B.R., Y. Tokiwa, and M. Haik. Sampling of Nitrates in Ambient Air. Atmos. Environ., 15:283, 1981.</P>
          <P>9. Spicer, C.W., and P.M. Schumacher. Particulate Nitrate: Laboratory and Field Studies of Major Sampling Interferences. Atmos. Environ., 13:543, 1979.</P>
          <P>10. Appel, B.R. Letter to Larry Purdue, U.S. EPA, Environmental Monitoring and Support Laboratory. March 18, 1982, Docket No. A-82-37, II-I-1.</P>
          <P>11. Pierson, W.R., W.W. Brachaczek, T.J. Korniski, T.J. Truex, and J.W. Butler. Artifact Formation of Sulfate, Nitrate, and Hydrogen Ion on Backup Filters: Allegheny Mountain Experiment. J. Air Pollut. Control Assoc., 30:30, 1980.</P>
          <P>12. Dunwoody, C.L. Rapid Nitrate Loss From PM<E T="52">10</E> Filters. J. Air Pollut. Control Assoc., 36:817, 1986.</P>
          <P>13. Harrell, R.M. Measuring the Alkalinity of Hi-Vol Air Filters. EMSL/RTP-SOP-QAD-534, October 1985. Available from the U.S. Environmental Protection Agency, EMSL/QAD, Research Triangle Park, NC 27711.</P>
          <P>14. Smith, F., P.S. Wohlschlegel, R.S.C. Rogers, and D.J. Mulligan. Investigation of Flow Rate Calibration Procedures Associated With the High Volume Method for Determination of Suspended Particulates. EPA-600/4-78-047, U.S. Environmental Protection Agency, Research Triangle Park, NC 27711, 1978.</P>
          <CITA>[52 FR 24664, July 1, 1987; 52 FR 29467, Aug. 7, 1987]</CITA>
        </APPENDIX>
        <APPENDIX>
          <EAR>Pt. 50, App. K</EAR>

          <HD SOURCE="HED">Appendix K to Part 50—Interpretation of the National Ambient Air Quality Standards for PM<E T="52">10</E>
          </HD>
          <P>1.0<E T="03">General.</E>
          </P>

          <P>(a) This appendix explains the computations necessary for analyzing particulate matter data to determine attainment of the 24-hour and annual standards specified in 40 CFR 50.6. For the primary and secondary standards, particulate matter is measured in the ambient air as PM<E T="52">10</E> (particles with an aerodynamic diameter less than or equal to a nominal 10 micrometers) by a reference method based on appendix J of this part and designated in accordance with part 53 of this chapter, or by an equivalent method designated in accordance with part 53 of this chapter. The required frequency of measurements is specified in part 58 of this chapter.</P>
          <P>(b) The terms used in this appendix are defined as follows:</P>
          <P>
            <E T="03">Average</E> refers to an arithmetic mean. All particulate matter standards are expressed in terms of expected annual values: Expected number of exceedances per year for the 24-hour standards and expected annual arithmetic mean for the annual standards.</P>
          <P>
            <E T="03">Daily value</E> for PM<E T="52">10</E> refers to the 24-hour average concentration of PM<E T="52">10</E> calculated or measured from midnight to midnight (local time).</P>
          <P>
            <E T="03">Exceedance</E> means a daily value that is above the level of the 24-hour standard after <PRTPAGE P="70"/>rounding to the nearest 10 µg/m<SU>3</SU> (i.e., values ending in 5 or greater are to be rounded up).</P>
          <P>
            <E T="03">Expected annual value</E> is the number approached when the annual values from an increasing number of years are averaged, in the absence of long-term trends in emissions or meteorological conditions.</P>
          <P>
            <E T="03">Year</E> refers to a calendar year.</P>
          <P>(c) Although the discussion in this appendix focuses on monitored data, the same principles apply to modeling data, subject to EPA modeling guidelines.</P>
          <P>2.0<E T="03">Attainment Determinations.</E>
          </P>
          <P>2.1<E T="03">24-Hour Primary and Secondary Standards.</E>
          </P>
          <P>(a) Under 40 CFR 50.6(a) the 24-hour primary and secondary standards are attained when the expected number of exceedances per year at each monitoring site is less than or equal to one. In the simplest case, the number of expected exceedances at a site is determined by recording the number of exceedances in each calendar year and then averaging them over the past 3 calendar years. Situations in which 3 years of data are not available and possible adjustments for unusual events or trends are discussed in sections 2.3 and 2.4 of this appendix. Further, when data for a year are incomplete, it is necessary to compute an estimated number of exceedances for that year by adjusting the observed number of exceedances. This procedure, performed by calendar quarter, is described in section 3.0 of this appendix. The expected number of exceedances is then estimated by averaging the individual annual estimates for the past 3 years.</P>
          <P>(b) The comparison with the allowable expected exceedance rate of one per year is made in terms of a number rounded to the nearest tenth (fractional values equal to or greater than 0.05 are to be rounded up; e.g., an exceedance rate of 1.05 would be rounded to 1.1, which is the lowest rate for nonattainment).</P>
          <P>2.2<E T="03">Annual Primary and Secondary Standards.</E> Under 40 CFR 50.6(b), the annual primary and secondary standards are attained when the expected annual arithmetic mean PM<E T="52">10</E> concentration is less than or equal to the level of the standard. In the simplest case, the expected annual arithmetic mean is determined by averaging the annual arithmetic mean PM<E T="52">10</E> concentrations for the past 3 calendar years. Because of the potential for incomplete data and the possible seasonality in PM<E T="52">10</E> concentrations, the annual mean shall be calculated by averaging the four quarterly means of PM<E T="52">10</E> concentrations within the calendar year. The equations for calculating the annual arithmetic mean are given in section 4.0 of this appendix. Situations in which 3 years of data are not available and possible adjustments for unusual events or trends are discussed in sections 2.3 and 2.4 of this appendix. The expected annual arithmetic mean is rounded to the nearest 1 µg/m<SU>3</SU> before comparison with the annual standards (fractional values equal to or greater than 0.5 are to be rounded up).</P>
          <P>2.3<E T="03">Data Requirements.</E>
          </P>

          <P>(a) 40 CFR 58.13 specifies the required minimum frequency of sampling for PM<E T="52">10</E>. For the purposes of making comparisons with the particulate matter standards, all data produced by National Air Monitoring Stations (NAMS), State and Local Air Monitoring Stations (SLAMS) and other sites submitted to EPA in accordance with the part 58 requirements must be used, and a minimum of 75 percent of the scheduled PM<E T="52">10</E> samples per quarter are required.</P>
          <P>(b) To demonstrate attainment of either the annual or 24-hour standards at a monitoring site, the monitor must provide sufficient data to perform the required calculations of sections 3.0 and 4.0 of this appendix. The amount of data required varies with the sampling frequency, data capture rate and the number of years of record. In all cases, 3 years of representative monitoring data that meet the 75 percent criterion of the previous paragraph should be utilized, if available, and would suffice. More than 3 years may be considered, if all additional representative years of data meeting the 75 percent criterion are utilized. Data not meeting these criteria may also suffice to show attainment; however, such exceptions will have to be approved by the appropriate Regional Administrator in accordance with EPA guidance.</P>
          <P>(c) There are less stringent data requirements for showing that a monitor has failed an attainment test and thus has recorded a violation of the particulate matter standards. Although it is generally necessary to meet the minimum 75 percent data capture requirement per quarter to use the computational equations described in sections 3.0 and 4.0 of this appendix, this criterion does not apply when less data is sufficient to unambiguously establish nonattainment. The following examples illustrate how nonattainment can be demonstrated when a site fails to meet the completeness criteria. Nonattainment of the 24-hour primary standards can be established by the observed annual number of exceedances (e.g., four observed exceedances in a single year), or by the estimated number of exceedances derived from the observed number of exceedances and the required number of scheduled samples (e.g., two observed exceedances with every other day sampling). Nonattainment of the annual standards can be demonstrated on the basis of quarterly mean concentrations developed from observed data combined with one-half the minimum detectable concentration substituted for missing values. In both cases, expected annual values must exceed the levels allowed by the standards.</P>
          <P>2.4<E T="03">Adjustment for Exceptional Events and Trends.</E>
            <PRTPAGE P="71"/>
          </P>
          <P>(a) An exceptional event is an uncontrollable event caused by natural sources of particulate matter or an event that is not expected to recur at a given location. Inclusion of such a value in the computation of exceedances or averages could result in inappropriate estimates of their respective expected annual values. To reduce the effect of unusual events, more than 3 years of representative data may be used. Alternatively, other techniques, such as the use of statistical models or the use of historical data could be considered so that the event may be discounted or weighted according to the likelihood that it will recur. The use of such techniques is subject to the approval of the appropriate Regional Administrator in accordance with EPA guidance.</P>
          <P>(b) In cases where long-term trends in emissions and air quality are evident, mathematical techniques should be applied to account for the trends to ensure that the expected annual values are not inappropriately biased by unrepresentative data. In the simplest case, if 3 years of data are available under stable emission conditions, this data should be used. In the event of a trend or shift in emission patterns, either the most recent representative year(s) could be used or statistical techniques or models could be used in conjunction with previous years of data to adjust for trends. The use of less than 3 years of data, and any adjustments are subject to the approval of the appropriate Regional Administrator in accordance with EPA guidance.</P>
          <P>3.0<E T="03">Computational Equations for the 24-hour Standards.</E>
          </P>
          <P>3.1<E T="03">Estimating Exceedances for a Year.</E>
          </P>
          <P>(a) If PM<E T="52">10</E> sampling is scheduled less frequently than every day, or if some scheduled samples are missed, a PM<E T="52">10</E> value will not be available for each day of the year. To account for the possible effect of incomplete data, an adjustment must be made to the data collected at each monitoring location to estimate the number of exceedances in a calendar year. In this adjustment, the assumption is made that the fraction of missing values that would have exceeded the standard level is identical to the fraction of measured values above this level. This computation is to be made for all sites that are scheduled to monitor throughout the entire year and meet the minimum data requirements of section 2.3 of this appendix. Because of possible seasonal imbalance, this adjustment shall be applied on a quarterly basis. The estimate of the expected number of exceedances for the quarter is equal to the observed number of exceedances plus an increment associated with the missing data. The following equation must be used for these computations:</P>
          <HD SOURCE="HD2">Equation 1</HD>
          <GPH DEEP="19" SPAN="1">
            <GID>ER18JY97.180</GID>
          </GPH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">e<E T="52">q</E> = the estimated number of exceedances for calendar quarter q;</FP>
          <FP SOURCE="FP-1">v<E T="52">q</E> = the observed number of exceedances for calendar quarter q;</FP>
          <FP SOURCE="FP-1">N<E T="52">q</E> = the number of days in calendar quarter q;</FP>
          <FP SOURCE="FP-1">n<E T="52">q</E> = the number of days in calendar quarter q with PM<E T="52">10</E> data; and</FP>
          <FP SOURCE="FP-1">q = the index for calendar quarter, q=1, 2, 3 or 4.</FP>
          
          <P>(b) The estimated number of exceedances for a calendar quarter must be rounded to the nearest hundredth (fractional values equal to or greater than 0.005 must be rounded up).</P>
          <P>(c) The estimated number of exceedances for the year, e, is the sum of the estimates for each calendar quarter.</P>
          <HD SOURCE="HD2">Equation 2</HD>
          <GPH DEEP="31" SPAN="1">
            <GID>ER18JY97.181</GID>
          </GPH>
          <P>(d) The estimated number of exceedances for a single year must be rounded to one decimal place (fractional values equal to or greater than 0.05 are to be rounded up). The expected number of exceedances is then estimated by averaging the individual annual estimates for the most recent 3 or more representative years of data. The expected number of exceedances must be rounded to one decimal place (fractional values equal to or greater than 0.05 are to be rounded up).</P>
          <P>(e) The adjustment for incomplete data will not be necessary for monitoring or modeling data which constitutes a complete record, i.e., 365 days per year.</P>
          <P>(f) To reduce the potential for overestimating the number of expected exceedances, the correction for missing data will not be required for a calendar quarter in which the first observed exceedance has occurred if:</P>
          <P>(1) There was only one exceedance in the calendar quarter;</P>
          <P>(2) Everyday sampling is subsequently initiated and maintained for 4 calendar quarters in accordance with 40 CFR 58.13; and</P>

          <P>(3) Data capture of 75 percent is achieved during the required period of everyday sampling. In addition, if the first exceedance is observed in a calendar quarter in which the monitor is already sampling every day, no adjustment for missing data will be made to the first exceedance if a 75 percent data capture rate was achieved in the quarter in which it was observed.<PRTPAGE P="72"/>
          </P>
          <HD SOURCE="HD2">Example 1</HD>

          <P>a. During a particular calendar quarter, 39 out of a possible 92 samples were recorded, with one observed exceedance of the 24-hour standard. Using Equation 1, the estimated number of exceedances for the quarter is:
          </P>
          <FP>e<E T="52">q</E>=1×92/39=2.359 or 2.36.</FP>
          
          <P>b. If the estimated exceedances for the other 3 calendar quarters in the year were 2.30, 0.0 and 0.0, then, using Equation 2, the estimated number of exceedances for the year is 2.36=2.30=0.0=0.0 which equals 4.66 or 4.7. If no exceedances were observed for the 2 previous years, then the expected number of exceedances is estimated by: (1/3)×(4.7=0=0)=1.57 or 1.6. Since 1.6 exceeds the allowable number of expected exceedances, this monitoring site would fail the attainment test.</P>
          <HD SOURCE="HD2">Example 2</HD>

          <P>In this example, everyday sampling was initiated following the first observed exceedance as required by 40 CFR 58.13. Accordingly, the first observed exceedance would not be adjusted for incomplete sampling. During the next three quarters, 1.2 exceedances were estimated. In this case, the estimated exceedances for the year would be 1.0=1.2=0.0=0.0 which equals 2.2. If, as before, no exceedances were observed for the two previous years, then the estimated exceedances for the 3-year period would then be (1/3)×(2.2=0.0=0.0)=0.7, and the monitoring site would <E T="03">not</E> fail the attainment test.</P>
          <P>3.2 <E T="03">Adjustments for Non-Scheduled Sampling Days.</E>
          </P>
          <P>(a) If a systematic sampling schedule is used and sampling is performed on days in addition to the days specified by the systematic sampling schedule, e.g., during episodes of high pollution, then an adjustment must be made in the eqution for the estimation of exceedances. Such an adjustment is needed to eliminate the bias in the estimate of the quarterly and annual number of exceedances that would occur if the chance of an exceedance is different for scheduled than for non-scheduled days, as would be the case with episode sampling.</P>
          <P>(b) The required adjustment treats the systematic sampling schedule as a stratified sampling plan. If the period from one scheduled sample until the day preceding the next scheduled sample is defined as a sampling stratum, then there is one stratum for each scheduled sampling day. An average number of observed exceedances is computed for each of these sampling strata. With nonscheduled sampling days, the estimated number of exceedances is defined as:</P>
          <HD SOURCE="HD2">Equation 3</HD>
          <GPH DEEP="33" SPAN="1">
            <GID>ER18JY97.182</GID>
          </GPH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">e<E T="52">q</E> = the estimated number of exceedances for the quarter;</FP>
          <FP SOURCE="FP-1">N<E T="52">q</E> = the number of days in the quarter;</FP>
          <FP SOURCE="FP-1">m<E T="52">q</E> = the number of strata with samples during the quarter;</FP>
          <FP SOURCE="FP-1">v<E T="52">j</E> = the number of observed exceedances in stratum j; and</FP>
          <FP SOURCE="FP-1">k<E T="52">j</E> = the number of actual samples in stratum j.</FP>
          
          <P>(c) Note that if only one sample value is recorded in each stratum, then Equation 3 reduces to Equation 1.</P>
          <HD SOURCE="HD2">Example 3</HD>

          <P>A monitoring site samples according to a systematic sampling schedule of one sample every 6 days, for a total of 15 scheduled samples in a quarter out of a total of 92 possible samples. During one 6-day period, potential episode levels of PM<E T="52">10</E> were suspected, so 5 additional samples were taken. One of the regular scheduled samples was missed, so a total of 19 samples in 14 sampling strata were measured. The one 6-day sampling stratum with 6 samples recorded 2 exceedances. The remainder of the quarter with one sample per stratum recorded zero exceedances. Using Equation 3, the estimated number of exceedances for the quarter is:
          </P>
          <FP>e<E T="52">q</E>=(92/14)×(2/6=0=. . .=0)=2.19.</FP>
          
          <P>4.0 <E T="03">Computational Equations for Annual Standards.</E>
          </P>
          <P>4.1 <E T="03">Calculation of the Annual Arithmetic Mean.</E> (a) An annual arithmetic mean value for PM<E T="52">10</E> is determined by averaging the quarterly means for the 4 calendar quarters of the year. The following equation is to be used for calculation of the mean for a calendar quarter:</P>
          <HD SOURCE="HD2">Equation 4</HD>
          <GPH DEEP="31" SPAN="1">
            <GID>ER18JY97.183</GID>
          </GPH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">x<AC T="8"/>
            <E T="52">q</E> = the quarterly mean concentration for quarter q, q=1, 2, 3, or 4,</FP>
          <FP SOURCE="FP-1">n<E T="52">q</E> = the number of samples in the quarter, and</FP>
          <FP SOURCE="FP-1">x<E T="52">i</E> = the ith concentration value recorded in the quarter.</FP>
          

          <P>(b) The quarterly mean, expressed in µg/m<SU>3</SU>, must be rounded to the nearest tenth (fractional values of 0.05 should be rounded up).<PRTPAGE P="73"/>
          </P>
          <P>(c) The annual mean is calculated by using the following equation:</P>
          <HD SOURCE="HD2">Equation 5</HD>
          <GPH DEEP="31" SPAN="1">
            <GID>ER18JY97.184</GID>
          </GPH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">x<AC T="8"/> = the annual mean; and</FP>
          <FP SOURCE="FP-1">x<AC T="8"/>
            <E T="52">q</E> = the mean for calendar quarter q.</FP>
          
          <P>(d) The average of quarterly means must be rounded to the nearest tenth (fractional values of 0.05 should be rounded up).</P>
          <P>(e) The use of quarterly averages to compute the annual average will not be necessary for monitoring or modeling data which results in a complete record, i.e., 365 days per year.</P>
          <P>(f) The expected annual mean is estimated as the average of three or more annual means. This multi-year estimate, expressed in µg/m<SU>3</SU>, shall be rounded to the nearest integer for comparison with the annual standard (fractional values of 0.5 should be rounded up).</P>
          <HD SOURCE="HD2">Example 4</HD>

          <P>Using Equation 4, the quarterly means are calculated for each calendar quarter. If the quarterly means are 52.4, 75.3, 82.1, and 63.2 µg/m<SU>3</SU>, then the annual mean is:
          </P>
          <FP>x<AC T="8"/> = (1/4)×(52.4=75.3=82.1=63.2) = 68.25 or 68.3.</FP>
          
          <P>4.2 <E T="03">Adjustments for Non-scheduled Sampling Days.</E> (a) An adjustment in the calculation of the annual mean is needed if sampling is performed on days in addition to the days specified by the systematic sampling schedule. For the same reasons given in the discussion of estimated exceedances, under section 3.2 of this appendix, the quarterly averages would be calculated by using the following equation:</P>
          <HD SOURCE="HD2">Equation 6</HD>
          <GPH DEEP="28" SPAN="1">
            <GID>ER18JY97.185</GID>
          </GPH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">x<AC T="8"/>
            <E T="52">q</E> = the quarterly mean concentration for quarter q, q=1, 2, 3, or 4;</FP>
          <FP SOURCE="FP-1">x<E T="52">ij</E> = the ith concentration value recorded in stratum j;</FP>
          <FP SOURCE="FP-1">k<E T="52">j</E> = the number of actual samples in stratum j; and</FP>
          <FP SOURCE="FP-1">m<E T="52">q</E> = the number of strata with data in the quarter.</FP>
          
          <P>(b) If one sample value is recorded in each stratum, Equation 6 reduces to a simple arithmetic average of the observed values as described by Equation 4.</P>
          <HD SOURCE="HD2">Example 5</HD>

          <P>a. During one calendar quarter, 9 observations were recorded. These samples were distributed among 7 sampling strata, with 3 observations in one stratum. The concentrations of the 3 observations in the single stratum were 202, 242, and 180 µg/m<SU>3</SU>. The remaining 6 observed concentrations were 55, 68, 73, 92, 120, and 155 µg/m<SU>3</SU>. Applying the weighting factors specified in Equation 6, the quarterly mean is:
          </P>
          <FP>x<AC T="8"/>
            <E T="52">q</E> = (1/7) × [(1/3) × (202 = 242 = 180) = 155 = 68 = 73 = 92 = 120 = 155] = 110.1</FP>
          
          <P>b. Although 24-hour measurements are rounded to the nearest 10 µg/m<SU>3</SU> for determinations of exceedances of the 24-hour standard, note that these values are rounded to the nearest 1 µg/m<SU>3</SU> for the calculation of means.</P>
          <CITA>[62 FR 38712, July 18, 1997]</CITA>
        </APPENDIX>
        <APPENDIX>
          <EAR>Pt. 50, App. L</EAR>

          <HD SOURCE="HED">Appendix L to Part 50—Reference Method for the Determination of Fine Particulate Matter as PM<E T="52">2.5</E> in the Atmosphere</HD>
          <P>1.0 <E T="03">Applicability.</E>
          </P>

          <P>1.1 This method provides for the measurement of the mass concentration of fine particulate matter having an aerodynamic diameter less than or equal to a nominal 2.5 micrometers (PM<E T="52">2.5</E>) in ambient air over a 24-hour period for purposes of determining whether the primary and secondary national ambient air quality standards for fine particulate matter specified in § 50.7 of this part are met. The measurement process is considered to be nondestructive, and the PM<E T="52">2.5</E> sample obtained can be subjected to subsequent physical or chemical analyses. Quality assessment procedures are provided in part 58, appendix A of this chapter, and quality assurance guidance are provided in references 1, 2, and 3 in section 13.0 of this appendix.</P>
          <P>1.2 This method will be considered a reference method for purposes of part 58 of this chapter only if:</P>
          <P>(a) The associated sampler meets the requirements specified in this appendix and the applicable requirements in part 53 of this chapter, and</P>
          <P>(b) The method and associated sampler have been designated as a reference method in accordance with part 53 of this chapter.</P>
          <P>1.3 PM<E T="52">2.5</E> samplers that meet nearly all specifications set forth in this method but have minor deviations and/or modifications of the reference method sampler will be designated as “Class I” equivalent methods for PM<E T="52">2.5</E> in accordance with part 53 of this chapter.</P>
          <P>2.0 <E T="03">Principle.</E>
          </P>

          <P>2.1 An electrically powered air sampler draws ambient air at a constant volumetric flow rate into a specially shaped inlet and <PRTPAGE P="74"/>through an inertial particle size separator (impactor) where the suspended particulate matter in the PM<E T="52">2.5</E> size range is separated for collection on a polytetrafluoroethylene (PTFE) filter over the specified sampling period. The air sampler and other aspects of this reference method are specified either explicitly in this appendix or generally with reference to other applicable regulations or quality assurance guidance.</P>

          <P>2.2 Each filter is weighed (after moisture and temperature conditioning) before and after sample collection to determine the net gain due to collected PM<E T="52">2.5</E>. The total volume of air sampled is determined by the sampler from the measured flow rate at actual ambient temperature and pressure and the sampling time. The mass concentration of PM<E T="52">2.5</E> in the ambient air is computed as the total mass of collected particles in the PM<E T="52">2.5</E> size range divided by the actual volume of air sampled, and is expressed in micrograms per cubic meter of air (µg/m<SU>3</SU>).</P>
          <P>3.0 <E T="03">PM</E>
            <E T="52">2.5</E>
            <E T="03">Measurement Range.</E>
          </P>
          <P>3.1 <E T="03">Lower concentration limit.</E> The lower detection limit of the mass concentration measurement range is estimated to be approximately 2 µg/m<SU>3</SU>, based on noted mass changes in field blanks in conjunction with the 24 m<SU>3</SU> nominal total air sample volume specified for the 24-hour sample.</P>
          <P>3.2 <E T="03">Upper concentration limit.</E> The upper limit of the mass concentration range is determined by the filter mass loading beyond which the sampler can no longer maintain the operating flow rate within specified limits due to increased pressure drop across the loaded filter. This upper limit cannot be specified precisely because it is a complex function of the ambient particle size distribution and type, humidity, the individual filter used, the capacity of the sampler flow rate control system, and perhaps other factors. Nevertheless, all samplers are estimated to be capable of measuring 24-hour PM<E T="52">2.5</E> mass concentrations of at least 200 µg/m<SU>3</SU> while maintaining the operating flow rate within the specified limits.</P>
          <P>3.3 <E T="03">Sample period.</E> The required sample period for PM<E T="52">2.5</E> concentration measurements by this method shall be 1,380 to 1500 minutes (23 to 25 hours). However, when a sample period is less than 1,380 minutes, the measured concentration (as determined by the collected PM<E T="52">2.5</E> mass divided by the actual sampled air volume), multiplied by the actual number of minutes in the sample period and divided by 1,440, may be used as if it were a valid concentration measurement for the specific purpose of determining a violation of the NAAQS. This value assumes that the PM<E T="52">2.5</E> concentration is zero for the remaining portion of the sample period and therefore represents the minimum concentration that could have been measured for the full 24-hour sample period. Accordingly, if the value thus calculated is high enough to be an exceedance, such an exceedance would be a valid exceedance for the sample period. When reported to AIRS, this data value should receive a special code to identify it as not to be commingled with normal concentration measurements or used for other purposes.</P>
          <P>4.0 <E T="03">Accuracy.</E>
          </P>

          <P>4.1 Because the size and volatility of the particles making up ambient particulate matter vary over a wide range and the mass concentration of particles varies with particle size, it is difficult to define the accuracy of PM<E T="52">2.5</E> measurements in an absolute sense. The accuracy of PM<E T="52">2.5</E> measurements is therefore defined in a relative sense, referenced to measurements provided by this reference method. Accordingly, accuracy shall be defined as the degree of agreement between a subject field PM<E T="52">2.5</E> sampler and a collocated PM<E T="52">2.5</E> reference method audit sampler operating simultaneously at the monitoring site location of the subject sampler and includes both random (precision) and systematic (bias) errors. The requirements for this field sampler audit procedure are set forth in part 58, appendix A of this chapter.</P>
          <P>4.2 <E T="03">Measurement system bias.</E> Results of collocated measurements where the duplicate sampler is a reference method sampler are used to assess a portion of the measurement system bias according to the schedule and procedure specified in part 58, appendix A of this chapter.</P>
          <P>4.3 <E T="03">Audits with reference method samplers to determine system accuracy and bias.</E> According to the schedule and procedure specified in part 58, appendix A of this chapter, a reference method sampler is required to be located at each of selected PM<E T="52">2.5</E> SLAMS sites as a duplicate sampler. The results from the primary sampler and the duplicate reference method sampler are used to calculate accuracy of the primary sampler on a quarterly basis, bias of the primary sampler on an annual basis, and bias of a single reporting organization on an annual basis. Reference 2 in section 13.0 of this appendix provides additional information and guidance on these reference method audits.</P>
          <P>4.4 <E T="03">Flow rate accuracy and bias.</E> Part 58, appendix A of this chapter requires that the flow rate accuracy and bias of individual PM<E T="52">2.5</E> samplers used in SLAMS monitoring networks be assessed periodically via audits of each sampler's operational flow rate. In addition, part 58, appendix A of this chapter requires that flow rate bias for each reference and equivalent method operated by each reporting organization be assessed quarterly and annually. Reference 2 in section 13.0 of this appendix provides additional information and guidance on flow rate accuracy audits and calculations for accuracy and bias.</P>
          <P>5.0 <E T="03">Precision.</E> A data quality objective of 10 percent coefficient of variation or better has <PRTPAGE P="75"/>been established for the operational precision of PM<E T="52">2.5</E> monitoring data.</P>
          <P>5.1 Tests to establish initial operational precision for each reference method sampler are specified as a part of the requirements for designation as a reference method under § 53.58 of this chapter.</P>
          <P>5.2 <E T="03">Measurement System Precision.</E> Collocated sampler results, where the duplicate sampler is not a reference method sampler but is a sampler of the same designated method as the primary sampler, are used to assess measurement system precision according to the schedule and procedure specified in part 58, appendix A of this chapter. Part 58, appendix A of this chapter requires that these collocated sampler measurements be used to calculate quarterly and annual precision estimates for each primary sampler and for each designated method employed by each reporting organization. Reference 2 in section 13.0 of this appendix provides additional information and guidance on this requirement.</P>
          <P>6.0 <E T="03">Filter for PM</E>
            <E T="52">2.5</E>
            <E T="03">Sample Collection.</E> Any filter manufacturer or vendor who sells or offers to sell filters specifically identified for use with this PM<E T="52">2.5</E> reference method shall certify that the required number of filters from each lot of filters offered for sale as such have been tested as specified in this section 6.0 and meet all of the following design and performance specifications.</P>
          <P>6.1 <E T="03">Size.</E> Circular, 46.2 mm diameter ±0.25 mm.</P>
          <P>6.2 <E T="03">Medium.</E> Polytetrafluoroethylene (PTFE Teflon), with integral support ring.</P>
          <P>6.3 <E T="03">Support ring.</E> Polymethylpentene (PMP) or equivalent inert material, 0.38 ±0.04 mm thick, outer diameter 46.2 mm ±0.25 mm, and width of 3.68 mm ( ±0.00, -0.51 mm).</P>
          <P>6.4 <E T="03">Pore size.</E> 2 µm as measured by ASTM F 316-94.</P>
          <P>6.5 <E T="03">Filter thickness.</E> 30 to 50 µm.</P>
          <P>6.6 <E T="03">Maximum pressure drop (clean filter).</E> 30 cm H<E T="52">2</E>O column @ 16.67 L/min clean air flow.</P>
          <P>6.7 <E T="03">Maximum moisture pickup.</E> Not more than 10 µg weight increase after 24-hour exposure to air of 40 percent relative humidity, relative to weight after 24-hour exposure to air of 35 percent relative humidity.</P>
          <P>6.8 <E T="03">Collection efficiency.</E> Greater than 99.7 percent, as measured by the DOP test (ASTM D 2986-91) with 0.3 µm particles at the sampler's operating face velocity.</P>
          <P>6.9 <E T="03">Filter weight stability.</E> Filter weight loss shall be less than 20 µg, as measured in each of the following two tests specified in sections 6.9.1 and 6.9.2 of this appendix. The following conditions apply to both of these tests: Filter weight loss shall be the average difference between the initial and the final filter weights of a random sample of test filters selected from each lot prior to sale. The number of filters tested shall be not less than 0.1 percent of the filters of each manufacturing lot, or 10 filters, whichever is greater. The filters shall be weighed under laboratory conditions and shall have had no air sample passed through them, i.e., filter blanks. Each test procedure must include initial conditioning and weighing, the test, and final conditioning and weighing. Conditioning and weighing shall be in accordance with sections 8.0 through 8.2 of this appendix and general guidance provided in reference 2 of section 13.0 of this appendix.</P>
          <P>6.9.1 <E T="03">Test for loose, surface particle contamination.</E> After the initial weighing, install each test filter, in turn, in a filter cassette (Figures L-27, L-28, and L-29 of this appendix) and drop the cassette from a height of 25 cm to a flat hard surface, such as a particle-free wood bench. Repeat two times, for a total of three drop tests for each test filter. Remove the test filter from the cassette and weigh the filter. The average change in weight must be less than 20 µg.</P>
          <P>6.9.2 <E T="03">Test for temperature stability.</E> After weighing each filter, place the test filters in a drying oven set at 40 °C ±2 °C for not less than 48 hours. Remove, condition, and reweigh each test filter. The average change in weight must be less than 20 µg.</P>
          <P>6.10 <E T="03">Alkalinity.</E> Less than 25 microequivalents/gram of filter, as measured by the guidance given in reference 2 in section 13.0 of this appendix.</P>
          <P>6.11 <E T="03">Supplemental requirements.</E> Although not required for determination of PM<E T="52">2.5</E> mass concentration under this reference method, additional specifications for the filter must be developed by users who intend to subject PM<E T="52">2.5</E> filter samples to subsequent chemical analysis. These supplemental specifications include background chemical contamination of the filter and any other filter parameters that may be required by the method of chemical analysis. All such supplemental filter specifications must be compatible with and secondary to the primary filter specifications given in this section 6.0 of this appendix.</P>
          <P>7.0 <E T="03">PM</E>
            <E T="52">2.5</E>
            <E T="03">Sampler.</E>
          </P>
          <P>7.1 <E T="03">Configuration.</E> The sampler shall consist of a sample air inlet, downtube, particle size separator (impactor), filter holder assembly, air pump and flow rate control system, flow rate measurement device, ambient and filter temperature monitoring system, barometric pressure measurement system, timer, outdoor environmental enclosure, and suitable mechanical, electrical, or electronic control capability to meet or exceed the design and functional performance as specified in this section 7.0 of this appendix. The performance specifications require that the sampler:</P>
          <P>(a) Provide automatic control of sample volumetric flow rate and other operational parameters.</P>
          <P>(b) Monitor these operational parameters as well as ambient temperature and pressure.</P>

          <P>(c) Provide this information to the sampler operator at the end of each sample period in <PRTPAGE P="76"/>digital form, as specified in table L-1 of section 7.4.19 of this appendix.</P>
          <P>7.2 <E T="03">Nature of specifications.</E> The PM<E T="52">2.5</E> sampler is specified by a combination of design and performance requirements. The sample inlet, downtube, particle size discriminator, filter cassette, and the internal configuration of the filter holder assembly are specified explicitly by design figures and associated mechanical dimensions, tolerances, materials, surface finishes, assembly instructions, and other necessary specifications. All other aspects of the sampler are specified by required operational function and performance, and the design of these other aspects (including the design of the lower portion of the filter holder assembly) is optional, subject to acceptable operational performance. Test procedures to demonstrate compliance with both the design and performance requirements are set forth in subpart E of part 53 of this chapter.</P>
          <P>7.3 <E T="03">Design specifications.</E> Except as indicated in this section 7.3 of this appendix, these components must be manufactured or reproduced exactly as specified, in an ISO 9001-registered facility, with registration initially approved and subsequently maintained during the period of manufacture. See § 53.1(t) of this chapter for the definition of an ISO-registered facility. Minor modifications or variances to one or more components that clearly would not affect the aerodynamic performance of the inlet, downtube, impactor, or filter cassette will be considered for specific approval. Any such proposed modifications shall be described and submitted to the EPA for specific individual acceptability either as part of a reference or equivalent method application under part 53 of this chapter or in writing in advance of such an intended application under part 53 of this chapter.</P>
          <P>7.3.1 <E T="03">Sample inlet assembly.</E> The sample inlet assembly, consisting of the inlet, downtube, and impactor shall be configured and assembled as indicated in Figure L-1 of this appendix and shall meet all associated requirements. A portion of this assembly shall also be subject to the maximum overall sampler leak rate specification under section 7.4.6 of this appendix.</P>
          <P>7.3.2 <E T="03">Inlet.</E> The sample inlet shall be fabricated as indicated in Figures L-2 through L-18 of this appendix and shall meet all associated requirements.</P>
          <P>7.3.3 <E T="03">Downtube.</E> The downtube shall be fabricated as indicated in Figure L-19 of this appendix and shall meet all associated requirements.</P>
          <P>7.3.4 <E T="03">Impactor.</E>
          </P>
          <P>7.3.4.1 The impactor (particle size separator) shall be fabricated as indicated in Figures L-20 through L-24 of this appendix and shall meet all associated requirements. Following the manufacture and finishing of each upper impactor housing (Figure L-21 of this appendix), the dimension of the impaction jet must be verified by the manufacturer using Class ZZ go/no-go plug gauges that are traceable to NIST.</P>
          <P>7.3.4.2 Impactor filter specifications:</P>
          <P>(a) Size. Circular, 35 to 37 mm diameter.</P>
          <P>(b) Medium. Borosilicate glass fiber, without binder.</P>
          <P>(c) Pore size. 1 to 1.5 micrometer, as measured by ASTM F 316-80.</P>
          <P>(d) Thickness. 300 to 500 micrometers.</P>
          <P>7.3.4.3 Impactor oil specifications:</P>
          <P>(a) Composition. Tetramethyltetraphenyltrisiloxane, single-compound diffusion oil.</P>
          <P>(b) Vapor pressure. Maximum 2×10<E T="51">−8</E> mm Hg at 25 °C.</P>
          <P>(c) Viscosity. 36 to 40 centistokes at 25 °C.</P>
          <P>(d) Density. 1.06 to 1.07 g/cm<SU>3</SU> at 25 °C.</P>
          <P>(e) Quantity. 1 mL ±0.1 mL.</P>
          <P>7.3.5 <E T="03">Filter holder assembly.</E> The sampler shall have a sample filter holder assembly to adapt and seal to the down tube and to hold and seal the specified filter, under section 6.0 of this appendix, in the sample air stream in a horizontal position below the downtube such that the sample air passes downward through the filter at a uniform face velocity. The upper portion of this assembly shall be fabricated as indicated in Figures L-25 and L-26 of this appendix and shall accept and seal with the filter cassette, which shall be fabricated as indicated in Figures L-27 through L-29 of this appendix.</P>
          <P>(a) The lower portion of the filter holder assembly shall be of a design and construction that:</P>
          <P>(1) Mates with the upper portion of the assembly to complete the filter holder assembly,</P>
          <P>(2) Completes both the external air seal and the internal filter cassette seal such that all seals are reliable over repeated filter changings, and</P>
          <P>(3) Facilitates repeated changing of the filter cassette by the sampler operator.</P>
          <P>(b) Leak-test performance requirements for the filter holder assembly are included in section 7.4.6 of this appendix.</P>
          <P>(c) If additional or multiple filters are stored in the sampler as part of an automatic sequential sample capability, all such filters, unless they are currently and directly installed in a sampling channel or sampling configuration (either active or inactive), shall be covered or (preferably) sealed in such a way as to:</P>
          <P>(1) Preclude significant exposure of the filter to possible contamination or accumulation of dust, insects, or other material that may be present in the ambient air, sampler, or sampler ventilation air during storage periods either before or after sampling; and</P>

          <P>(2) To minimize loss of volatile or semi-volatile PM sample components during storage of the filter following the sample period.<PRTPAGE P="77"/>
          </P>
          <P>7.3.6 <E T="03">Flow rate measurement adapter.</E> A flow rate measurement adapter as specified in Figure L-30 of this appendix shall be furnished with each sampler.</P>
          <P>7.3.7 <E T="03">Surface finish.</E> All internal surfaces exposed to sample air prior to the filter shall be treated electrolytically in a sulfuric acid bath to produce a clear, uniform anodized surface finish of not less than 1000 mg/ft<SU>2</SU> (1.08 mg/cm<SU>2</SU>) in accordance with military standard specification (mil. spec.) 8625F, Type II, Class 1 in reference 4 of section 13.0 of this appendix. This anodic surface coating shall not be dyed or pigmented. Following anodization, the surfaces shall be sealed by immersion in boiling deionized water for not less than 15 minutes. Section 53.51(d)(2) of this chapter should also be consulted.</P>
          <P>7.3.8 <E T="03">Sampling height.</E> The sampler shall be equipped with legs, a stand, or other means to maintain the sampler in a stable, upright position and such that the center of the sample air entrance to the inlet, during sample collection, is maintained in a horizontal plane and is 2.0 ±0.2 meters above the floor or other horizontal supporting surface. Suitable bolt holes, brackets, tie-downs, or other means should be provided to facilitate mechanically securing the sample to the supporting surface to prevent toppling of the sampler due to wind.</P>
          <P>7.4 <E T="03">Performance specifications.</E>
          </P>
          <P>7.4.1 <E T="03">Sample flow rate.</E> Proper operation of the impactor requires that specific air velocities be maintained through the device. Therefore, the design sample air flow rate through the inlet shall be 16.67 L/min (1.000 m<SU>3</SU>/hour) measured as actual volumetric flow rate at the temperature and pressure of the sample air entering the inlet.</P>
          <P>7.4.2 <E T="03">Sample air flow rate control system.</E> The sampler shall have a sample air flow rate control system which shall be capable of providing a sample air volumetric flow rate within the specified range, under section 7.4.1 of this appendix, for the specified filter, under section 6.0 of this appendix, at any atmospheric conditions specified, under section 7.4.7 of this appendix, at a filter pressure drop equal to that of a clean filter plus up to 75 cm water column (55 mm Hg), and over the specified range of supply line voltage, under section 7.4.15.1 of this appendix. This flow control system shall allow for operator adjustment of the operational flow rate of the sampler over a range of at least ±15 percent of the flow rate specified in section 7.4.1 of this appendix.</P>
          <P>7.4.3 <E T="03">Sample flow rate regulation.</E> The sample flow rate shall be regulated such that for the specified filter, under section 6.0 of this appendix, at any atmospheric conditions specified, under section 7.4.7 of this appendix, at a filter pressure drop equal to that of a clean filter plus up to 75 cm water column (55 mm Hg), and over the specified range of supply line voltage, under section 7.4.15.1 of this appendix, the flow rate is regulated as follows:</P>
          <P>7.4.3.1 The volumetric flow rate, measured or averaged over intervals of not more than 5 minutes over a 24-hour period, shall not vary more than ±5 percent from the specified 16.67 L/min flow rate over the entire sample period.</P>
          <P>7.4.3.2 The coefficient of variation (sample standard deviation divided by the mean) of the flow rate, measured over a 24-hour period, shall not be greater than 2 percent.</P>
          <P>7.4.3.3 The amplitude of short-term flow rate pulsations, such as may originate from some types of vacuum pumps, shall be attenuated such that they do not cause significant flow measurement error or affect the collection of particles on the particle collection filter.</P>
          <P>7.4.4 <E T="03">Flow rate cut off.</E> The sampler's sample air flow rate control system shall terminate sample collection and stop all sample flow for the remainder of the sample period in the event that the sample flow rate deviates by more than 10 percent from the sampler design flow rate specified in section 7.4.1 of this appendix for more than 60 seconds. However, this sampler cut-off provision shall not apply during periods when the sampler is inoperative due to a temporary power interruption, and the elapsed time of the inoperative period shall not be included in the total sample time measured and reported by the sampler, under section 7.4.13 of this appendix.</P>
          <P>7.4.5 <E T="03">Flow rate measurement.</E>
          </P>
          <P>7.4.5.1 The sampler shall provide a means to measure and indicate the instantaneous sample air flow rate, which shall be measured as volumetric flow rate at the temperature and pressure of the sample air entering the inlet, with an accuracy of ±2 percent. The measured flow rate shall be available for display to the sampler operator at any time in either sampling or standby modes, and the measurement shall be updated at least every 30 seconds. The sampler shall also provide a simple means by which the sampler operator can manually start the sample flow temporarily during non-sampling modes of operation, for the purpose of checking the sample flow rate or the flow rate measurement system.</P>
          <P>7.4.5.2 During each sample period, the sampler's flow rate measurement system shall automatically monitor the sample volumetric flow rate, obtaining flow rate measurements at intervals of not greater than 30 seconds.</P>
          <P>(a) Using these interval flow rate measurements, the sampler shall determine or calculate the following flow-related parameters, scaled in the specified engineering units:</P>
          <P>(1) The instantaneous or interval-average flow rate, in L/min.</P>

          <P>(2) The value of the average sample flow rate for the sample period, in L/min.<PRTPAGE P="78"/>
          </P>
          <P>(3) The value of the coefficient of variation (sample standard deviation divided by the average) of the sample flow rate for the sample period, in percent.</P>
          <P>(4) The occurrence of any time interval during the sample period in which the measured sample flow rate exceeds a range of ±5 percent of the average flow rate for the sample period for more than 5 minutes, in which case a warning flag indicator shall be set.</P>
          <P>(5) The value of the integrated total sample volume for the sample period, in m<SU>3</SU>.</P>
          <P>(b) Determination or calculation of these values shall properly exclude periods when the sampler is inoperative due to temporary interruption of electrical power, under section 7.4.13 of this appendix, or flow rate cut off, under section 7.4.4 of this appendix.</P>
          <P>(c) These parameters shall be accessible to the sampler operator as specified in table L-1 of section 7.4.19 of this appendix. In addition, it is strongly encouraged that the flow rate for each 5-minute interval during the sample period be available to the operator following the end of the sample period.</P>
          <P>7.4.6 <E T="03">Leak test capability.</E>
          </P>
          <P>7.4.6.1 <E T="03">External leakage.</E> The sampler shall include an external air leak-test capability consisting of components, accessory hardware, operator interface controls, a written procedure in the associated Operation/Instruction Manual, under section 7.4.18 of this appendix, and all other necessary functional capability to permit and facilitate the sampler operator to conveniently carry out a leak test of the sampler at a field monitoring site without additional equipment. The sampler components to be subjected to this leak test include all components and their interconnections in which external air leakage would or could cause an error in the sampler's measurement of the total volume of sample air that passes through the sample filter.</P>
          <P>(a) The suggested technique for the operator to use for this leak test is as follows:</P>
          <P>(1) Remove the sampler inlet and installs the flow rate measurement adapter supplied with the sampler, under section 7.3.6 of this appendix.</P>
          <P>(2) Close the valve on the flow rate measurement adapter and use the sampler air pump to draw a partial vacuum in the sampler, including (at least) the impactor, filter holder assembly (filter in place), flow measurement device, and interconnections between these devices, of at least 55 mm Hg (75 cm water column), measured at a location downstream of the filter holder assembly.</P>
          <P>(3) Plug the flow system downstream of these components to isolate the components under vacuum from the pump, such as with a built-in valve.</P>
          <P>(4) Stop the pump.</P>
          <P>(5) Measure the trapped vacuum in the sampler with a built-in pressure measuring device.</P>
          <P>(6) (i) Measure the vacuum in the sampler with the built-in pressure measuring device again at a later time at least 10 minutes after the first pressure measurement.</P>
          <P>(ii) <E T="04">Caution:</E> Following completion of the test, the adaptor valve should be opened slowly to limit the flow rate of air into the sampler. Excessive air flow rate may blow oil out of the impactor.</P>
          <P>(7) Upon completion of the test, open the adaptor valve, remove the adaptor and plugs, and restore the sampler to the normal operating configuration.</P>
          <P>(b) The associated leak test procedure shall require that for successful passage of this test, the difference between the two pressure measurements shall not be greater than the number of mm of Hg specified for the sampler by the manufacturer, based on the actual internal volume of the sampler, that indicates a leak of less than 80 mL/min.</P>
          <P>(c) Variations of the suggested technique or an alternative external leak test technique may be required for samplers whose design or configuration would make the suggested technique impossible or impractical. The specific proposed external leak test procedure, or particularly an alternative leak test technique, proposed for a particular candidate sampler may be described and submitted to the EPA for specific individual acceptability either as part of a reference or equivalent method application under part 53 of this chapter or in writing in advance of such an intended application under part 53 of this chapter.</P>
          <P>7.4.6.2 <E T="03">Internal, filter bypass leakage.</E> The sampler shall include an internal, filter bypass leak-check capability consisting of components, accessory hardware, operator interface controls, a written procedure in the Operation/Instruction Manual, and all other necessary functional capability to permit and facilitate the sampler operator to conveniently carry out a test for internal filter bypass leakage in the sampler at a field monitoring site without additional equipment. The purpose of the test is to determine that any portion of the sample flow rate that leaks past the sample filter without passing through the filter is insignificant relative to the design flow rate for the sampler.</P>
          <P>(a) The suggested technique for the operator to use for this leak test is as follows:</P>
          <P>(1) Carry out an external leak test as provided under section 7.4.6.1 of this appendix which indicates successful passage of the prescribed external leak test.</P>
          <P>(2) Install a flow-impervious membrane material in the filter cassette, either with or without a filter, as appropriate, which effectively prevents air flow through the filter.</P>

          <P>(3) Use the sampler air pump to draw a partial vacuum in the sampler, downstream of the filter holder assembly, of at least 55 mm Hg (75 cm water column).<PRTPAGE P="79"/>
          </P>
          <P>(4) Plug the flow system downstream of the filter holder to isolate the components under vacuum from the pump, such as with a built-in valve.</P>
          <P>(5) Stop the pump.</P>
          <P>(6) Measure the trapped vacuum in the sampler with a built-in pressure measuring device.</P>
          <P>(7) Measure the vacuum in the sampler with the built-in pressure measuring device again at a later time at least 10 minutes after the first pressure measurement.</P>
          <P>(8) Remove the flow plug and membrane and restore the sampler to the normal operating configuration.</P>
          <P>(b) The associated leak test procedure shall require that for successful passage of this test, the difference between the two pressure measurements shall not be greater than the number of mm of Hg specified for the sampler by the manufacturer, based on the actual internal volume of the portion of the sampler under vacuum, that indicates a leak of less than 80 mL/min.</P>
          <P>(c) Variations of the suggested technique or an alternative internal, filter bypass leak test technique may be required for samplers whose design or configuration would make the suggested technique impossible or impractical. The specific proposed internal leak test procedure, or particularly an alternative internal leak test technique proposed for a particular candidate sampler may be described and submitted to the EPA for specific individual acceptability either as part of a reference or equivalent method application under part 53 of this chapter or in writing in advance of such intended application under part 53 of this chapter.</P>
          <P>7.4.7 <E T="03">Range of operational conditions.</E> The sampler is required to operate properly and meet all requirements specified in this appendix over the following operational ranges.</P>
          <P>7.4.7.1 <E T="03">Ambient temperature.</E> -30 to =45 °C (Note: Although for practical reasons, the temperature range over which samplers are required to be tested under part 53 of this chapter is -20 to =40 °C, the sampler shall be designed to operate properly over this wider temperature range.).</P>
          <P>7.4.7.2 <E T="03">Ambient relative humidity.</E> 0 to 100 percent.</P>
          <P>7.4.7.3 <E T="03">Barometric pressure range.</E> 600 to 800 mm Hg.</P>
          <P>7.4.8 <E T="03">Ambient temperature sensor.</E> The sampler shall have capability to measure the temperature of the ambient air surrounding the sampler over the range of -30 to =45 °C, with a resolution of 0.1 °C and accuracy of ±2.0 °C, referenced as described in reference 3 in section 13.0 of this appendix, with and without maximum solar insolation.</P>
          <P>7.4.8.1 The ambient temperature sensor shall be mounted external to the sampler enclosure and shall have a passive, naturally ventilated sun shield. The sensor shall be located such that the entire sun shield is at least 5 cm above the horizontal plane of the sampler case or enclosure (disregarding the inlet and downtube) and external to the vertical plane of the nearest side or protuberance of the sampler case or enclosure. The maximum temperature measurement error of the ambient temperature measurement system shall be less than 1.6 °C at 1 m/s wind speed and 1000 W/m2 solar radiation intensity.</P>
          <P>7.4.8.2 The ambient temperature sensor shall be of such a design and mounted in such a way as to facilitate its convenient dismounting and immersion in a liquid for calibration and comparison to the filter temperature sensor, under section 7.4.11 of this appendix.</P>
          <P>7.4.8.3 This ambient temperature measurement shall be updated at least every 30 seconds during both sampling and standby (non-sampling) modes of operation. A visual indication of the current (most recent) value of the ambient temperature measurement, updated at least every 30 seconds, shall be available to the sampler operator during both sampling and standby (non-sampling) modes of operation, as specified in table L-1 of section 7.4.19 of this appendix.</P>
          <P>7.4.8.4 This ambient temperature measurement shall be used for the purpose of monitoring filter temperature deviation from ambient temperature, as required by section 7.4.11 of this appendix, and may be used for purposes of effecting filter temperature control, under section 7.4.10 of this appendix, or computation of volumetric flow rate, under sections 7.4.1 to 7.4.5 of this appendix, if appropriate.</P>
          <P>7.4.8.5 Following the end of each sample period, the sampler shall report the maximum, minimum, and average temperature for the sample period, as specified in table L-1 of section 7.4.19 of this appendix.</P>
          <P>7.4.9 <E T="03">Ambient barometric sensor.</E> The sampler shall have capability to measure the barometric pressure of the air surrounding the sampler over a range of 600 to 800 mm Hg referenced as described in reference 3 in section 13.0 of this appendix; also see part 53, subpart E of this chapter. This barometric pressure measurement shall have a resolution of 5 mm Hg and an accuracy of ±10 mm Hg and shall be updated at least every 30 seconds. A visual indication of the value of the current (most recent) barometric pressure measurement, updated at least every 30 seconds, shall be available to the sampler operator during both sampling and standby (non-sampling) modes of operation, as specified in table L-1 of section 7.4.19 of this appendix. This barometric pressure measurement may be used for purposes of computation of volumetric flow rate, under sections 7.4.1 to 7.4.5 of this appendix, if appropriate. Following the end of a sample period, the sampler shall report the maximum, minimum, and mean barometric pressures for the sample period, <PRTPAGE P="80"/>as specified in table L-1 of section 7.4.19 of this appendix.</P>
          <P>7.4.10 <E T="03">Filter temperature control (sampling and post-sampling).</E> The sampler shall provide a means to limit the temperature rise of the sample filter (all sample filters for sequential samplers), from insolation and other sources, to no more 5 °C above the temperature of the ambient air surrounding the sampler, during both sampling and post-sampling periods of operation. The post-sampling period is the non-sampling period between the end of the active sampling period and the time of retrieval of the sample filter by the sampler operator.</P>
          <P>7.4.11 <E T="03">Filter temperature sensor(s).</E>
          </P>
          <P>7.4.11.1 The sampler shall have the capability to monitor the temperature of the sample filter (all sample filters for sequential samplers) over the range of -30 to =45 °C during both sampling and non-sampling periods. While the exact location of this temperature sensor is not explicitly specified, the filter temperature measurement system must demonstrate agreement, within 1 °C, with a test temperature sensor located within 1 cm of the center of the filter downstream of the filter during both sampling and non-sampling modes, as specified in the filter temperature measurement test described in part 53, subpart E of this chapter. This filter temperature measurement shall have a resolution of 0.1 °C and accuracy of ±1.0 °C, referenced as described in reference 3 in section 13.0 of this appendix. This temperature sensor shall be of such a design and mounted in such a way as to facilitate its reasonably convenient dismounting and immersion in a liquid for calibration and comparison to the ambient temperature sensor under section 7.4.8 of this appendix.</P>
          <P>7.4.11.2 The filter temperature measurement shall be updated at least every 30 seconds during both sampling and standby (non-sampling) modes of operation. A visual indication of the current (most recent) value of the filter temperature measurement, updated at least every 30 seconds, shall be available to the sampler operator during both sampling and standby (non-sampling) modes of operation, as specified in table L-1 of section 7.4.19 of this appendix.</P>
          <P>7.4.11.3 For sequential samplers, the temperature of each filter shall be measured individually unless it can be shown, as specified in the filter temperature measurement test described in § 53.57 of this chapter, that the temperature of each filter can be represented by fewer temperature sensors.</P>
          <P>7.4.11.4 The sampler shall also provide a warning flag indicator following any occurrence in which the filter temperature (any filter temperature for sequential samplers) exceeds the ambient temperature by more than 5 °C for more than 30 consecutive minutes during either the sampling or post-sampling periods of operation, as specified in table L-1 of section 7.4.19 of this appendix, under section 10.12 of this appendix, regarding sample validity when a warning flag occurs. It is further recommended (not required) that the sampler be capable of recording the maximum differential between the measured filter temperature and the ambient temperature and its time and date of occurrence during both sampling and post-sampling (non-sampling) modes of operation and providing for those data to be accessible to the sampler operator following the end of the sample period, as suggested in table L-1 of section 7.4.19 of this appendix.</P>
          <P>7.4.12 <E T="03">Clock/timer system.</E>
          </P>
          <P>(a) The sampler shall have a programmable real-time clock timing/control system that:</P>
          <P>(1) Is capable of maintaining local time and date, including year, month, day-of-month, hour, minute, and second to an accuracy of ±1.0 minute per month.</P>
          <P>(2) Provides a visual indication of the current system time, including year, month, day-of-month, hour, and minute, updated at least each minute, for operator verification.</P>
          <P>(3) Provides appropriate operator controls for setting the correct local time and date.</P>
          <P>(4) Is capable of starting the sample collection period and sample air flow at a specific, operator-settable time and date, and stopping the sample air flow and terminating the sampler collection period 24 hours (1440 minutes) later, or at a specific, operator-settable time and date.</P>
          <P>(b) These start and stop times shall be readily settable by the sampler operator to within ±1.0 minute. The system shall provide a visual indication of the current start and stop time settings, readable to ±1.0 minute, for verification by the operator, and the start and stop times shall also be available via the data output port, as specified in table L-1 of section 7.4.19 of this appendix. Upon execution of a programmed sample period start, the sampler shall automatically reset all sample period information and warning flag indications pertaining to a previous sample period. Refer also to section 7.4.15.4 of this appendix regarding retention of current date and time and programmed start and stop times during a temporary electrical power interruption.</P>
          <P>7.4.13 <E T="03">Sample time determination.</E> The sampler shall be capable of determining the elapsed sample collection time for each PM<E T="52">2.5</E> sample, accurate to within ±1.0 minute, measured as the time between the start of the sampling period, under section 7.4.12 of this appendix and the termination of the sample period, under section 7.4.12 of this appendix or section 7.4.4 of this appendix. This elapsed sample time shall not include periods when the sampler is inoperative due to a temporary interruption of electrical power, under section 7.4.15.4 of this appendix. In the event that the elapsed sample time determined for the sample period is not within the <PRTPAGE P="81"/>range specified for the required sample period in section 3.3 of this appendix, the sampler shall set a warning flag indicator. The date and time of the start of the sample period, the value of the elapsed sample time for the sample period, and the flag indicator status shall be available to the sampler operator following the end of the sample period, as specified in table L-1 of section 7.4.19 of this appendix.</P>
          <P>7.4.14 <E T="03">Outdoor environmental enclosure.</E> The sampler shall have an outdoor enclosure (or enclosures) suitable to protect the filter and other non-weatherproof components of the sampler from precipitation, wind, dust, extremes of temperature and humidity; to help maintain temperature control of the filter (or filters, for sequential samplers); and to provide reasonable security for sampler components and settings.</P>
          <P>7.4.15 <E T="03">Electrical power supply.</E>
          </P>
          <P>7.4.15.1 The sampler shall be operable and function as specified herein when operated on an electrical power supply voltage of 105 to 125 volts AC (RMS) at a frequency of 59 to 61 Hz. Optional operation as specified at additional power supply voltages and/or frequencies shall not be precluded by this requirement.</P>
          <P>7.4.15.2 The design and construction of the sampler shall comply with all applicable National Electrical Code and Underwriters Laboratories electrical safety requirements.</P>
          <P>7.4.15.3 The design of all electrical and electronic controls shall be such as to provide reasonable resistance to interference or malfunction from ordinary or typical levels of stray electromagnetic fields (EMF) as may be found at various monitoring sites and from typical levels of electrical transients or electronic noise as may often or occasionally be present on various electrical power lines.</P>
          <P>7.4.15.4 In the event of temporary loss of electrical supply power to the sampler, the sampler shall not be required to sample or provide other specified functions during such loss of power, except that the internal clock/timer system shall maintain its local time and date setting within ±1 minute per week, and the sampler shall retain all other time and programmable settings and all data required to be available to the sampler operator following each sample period for at least 7 days without electrical supply power. When electrical power is absent at the operator-set time for starting a sample period or is interrupted during a sample period, the sampler shall automatically start or resume sampling when electrical power is restored, if such restoration of power occurs before the operator-set stop time for the sample period.</P>
          <P>7.4.15.5 The sampler shall have the capability to record and retain a record of the year, month, day-of-month, hour, and minute of the start of each power interruption of more than 1 minute duration, up to 10 such power interruptions per sample period. (More than 10 such power interruptions shall invalidate the sample, except where an exceedance is measured, under section 3.3 of this appendix.) The sampler shall provide for these power interruption data to be available to the sampler operator following the end of the sample period, as specified in table L-1 of section 7.4.19 of this appendix.</P>
          <P>7.4.16 <E T="03">Control devices and operator interface.</E> The sampler shall have mechanical, electrical, or electronic controls, control devices, electrical or electronic circuits as necessary to provide the timing, flow rate measurement and control, temperature control, data storage and computation, operator interface, and other functions specified. Operator-accessible controls, data displays, and interface devices shall be designed to be simple, straightforward, reliable, and easy to learn, read, and operate under field conditions. The sampler shall have provision for operator input and storage of up to 64 characters of numeric (or alphanumeric) data for purposes of site, sampler, and sample identification. This information shall be available to the sampler operator for verification and change and for output via the data output port along with other data following the end of a sample period, as specified in table L-1 of section 7.4.19 of this appendix. All data required to be available to the operator following a sample collection period or obtained during standby mode in a post-sampling period shall be retained by the sampler until reset, either manually by the operator or automatically by the sampler upon initiation of a new sample collection period.</P>
          <P>7.4.17 <E T="03">Data output port requirement.</E> The sampler shall have a standard RS-232C data output connection through which digital data may be exported to an external data storage or transmission device. All information which is required to be available at the end of each sample period shall be accessible through this data output connection. The information that shall be accessible though this output port is summarized in table L-1 of section 7.4.19 of this appendix. Since no specific format for the output data is provided, the sampler manufacturer or vendor shall make available to sampler purchasers appropriate computer software capable of receiving exported sampler data and correctly translating the data into a standard spreadsheet format and optionally any other formats as may be useful to sampler users. This requirement shall not preclude the sampler from offering other types of output connections in addition to the required RS-232C port.</P>
          <P>7.4.18 <E T="03">Operation/instruction manual.</E> The sampler shall include an associated comprehensive operation or instruction manual, as required by part 53 of this chapter, which includes detailed operating instructions on <PRTPAGE P="82"/>the setup, operation, calibration, and maintenance of the sampler. This manual shall provide complete and detailed descriptions of the operational and calibration procedures prescribed for field use of the sampler and all instruments utilized as part of this reference method. The manual shall include adequate warning of potential safety hazards that may result from normal use or malfunction of the method and a description of necessary safety precautions. The manual shall also include a clear description of all procedures pertaining to installation, operation, periodic and corrective maintenance, and troubleshooting, and shall include parts identification diagrams.</P>
          <P>7.4.19 <E T="03">Data reporting requirements.</E> The various information that the sampler is required to provide and how it is to be provided is summarized in the following table L-1.</P>
          <GPOTABLE CDEF="s25,r10,10C,10C,10C,10C,r25,r25" COLS="8" OPTS="L2">
            <TTITLE>Table L-1—Summary of Information To Be Provided By the Sampler</TTITLE>
            <BOXHD>
              <CHED H="1">Information to be provided</CHED>
              <CHED H="1">Appendix L section reference</CHED>
              <CHED H="1">Availability</CHED>
              <CHED H="2">Anytime <SU>1</SU>
              </CHED>
              <CHED H="2">End of period <SU>2</SU>
              </CHED>
              <CHED H="2">Visual display <SU>3</SU>
              </CHED>
              <CHED H="2">Data output <SU>4</SU>
              </CHED>
              <CHED H="1">Format</CHED>
              <CHED H="2">Digital reading <SU>5</SU>
              </CHED>
              <CHED H="2">Units</CHED>
            </BOXHD>
            <ROW>
              <ENT I="01">Flow rate, 30-second maximum interval</ENT>
              <ENT>7.4.5.1</ENT>
              <ENT>✔</ENT>
              <ENT/>
              <ENT>✔</ENT>
              <ENT>*</ENT>
              <ENT>XX.X</ENT>
              <ENT>L/min</ENT>
            </ROW>
            <ROW>
              <ENT I="01">Flow rate, average for the sample period</ENT>
              <ENT>7.4.5.2</ENT>
              <ENT>*</ENT>
              <ENT>✔</ENT>
              <ENT>*</ENT>
              <ENT>✔</ENT>
              <ENT>XX.X</ENT>
              <ENT>L/min</ENT>
            </ROW>
            <ROW>
              <ENT I="01">Flow rate, CV, for sample period</ENT>
              <ENT>7.4.5.2</ENT>
              <ENT>*</ENT>
              <ENT>✔</ENT>
              <ENT>*</ENT>
              <ENT>✔■</ENT>
              <ENT>XX.X</ENT>
              <ENT>%</ENT>
            </ROW>
            <ROW>
              <ENT I="01">Flow rate, 5-min. average out of spec. (FLAG <SU>6</SU>)</ENT>
              <ENT>7.4.5.2</ENT>
              <ENT>✔</ENT>
              <ENT>✔</ENT>
              <ENT>✔</ENT>
              <ENT>✔■</ENT>
              <ENT>On/Off</ENT>
              <ENT/>
            </ROW>
            <ROW>
              <ENT I="01">Sample volume, total</ENT>
              <ENT>7.4.5.2</ENT>
              <ENT>*</ENT>
              <ENT>✔</ENT>
              <ENT>✔</ENT>
              <ENT>✔■</ENT>
              <ENT>XX.X</ENT>
              <ENT>m<SU>3</SU>
              </ENT>
            </ROW>
            <ROW>
              <ENT I="01">Temperature, ambient, 30-second interval</ENT>
              <ENT>7.4.8</ENT>
              <ENT>✔</ENT>
              <ENT/>
              <ENT>✔</ENT>
              <ENT/>
              <ENT>XX.X</ENT>
              <ENT>°C</ENT>
            </ROW>
            <ROW>
              <ENT I="01">Temperature, ambient, min., max., average for the sample period</ENT>
              <ENT>7.4.8</ENT>
              <ENT>*</ENT>
              <ENT>✔</ENT>
              <ENT>✔</ENT>
              <ENT>✔■</ENT>
              <ENT>XX.X</ENT>
              <ENT>°C</ENT>
            </ROW>
            <ROW>
              <ENT I="01">Baro pressure, ambient, 30-second interval</ENT>
              <ENT>7.4.9</ENT>
              <ENT>✔</ENT>
              <ENT/>
              <ENT>✔</ENT>
              <ENT/>
              <ENT>XXX</ENT>
              <ENT>mm Hg</ENT>
            </ROW>
            <ROW>
              <ENT I="01">Baro pressure, ambient, min., max., average for the sample period</ENT>
              <ENT>7.4.9</ENT>
              <ENT>*</ENT>
              <ENT>✔</ENT>
              <ENT>✔</ENT>
              <ENT>✔■</ENT>
              <ENT>XXX</ENT>
              <ENT>mm Hg</ENT>
            </ROW>
            <ROW>
              <ENT I="01">Filter temperature, 30-second interval</ENT>
              <ENT>7.4.11</ENT>
              <ENT>✔</ENT>
              <ENT/>
              <ENT>✔</ENT>
              <ENT/>
              <ENT>XX.X</ENT>
              <ENT>°C</ENT>
            </ROW>
            <ROW>
              <ENT I="01">Filter temperature differential, 30-second interval, out of spec. (FLAG <SU>6</SU>)</ENT>
              <ENT>7.4.11</ENT>
              <ENT>*</ENT>
              <ENT>✔</ENT>
              <ENT>✔</ENT>
              <ENT>✔■</ENT>
              <ENT>On/Off</ENT>
              <ENT/>
            </ROW>
            <ROW>
              <ENT I="01">Filter temperature, maximum differential from ambient, date, time of occurrence</ENT>
              <ENT>7.4.11</ENT>
              <ENT>*</ENT>
              <ENT>*</ENT>
              <ENT>*</ENT>
              <ENT>*</ENT>
              <ENT>X.X, YY/MM/DD HH:mm</ENT>
              <ENT>°C, Yr./Mon./Day Hrs. min</ENT>
            </ROW>
            <ROW>
              <ENT I="01">Date and time</ENT>
              <ENT>7.4.12</ENT>
              <ENT>✔</ENT>
              <ENT/>
              <ENT>✔</ENT>
              <ENT/>
              <ENT>YY/MM/DD HH:mm</ENT>
              <ENT>Yr./Mon./Day Hrs. min</ENT>
            </ROW>
            <ROW>
              <ENT I="01">Sample start and stop time settings</ENT>
              <ENT>7.4.12</ENT>
              <ENT>✔</ENT>
              <ENT>✔</ENT>
              <ENT>✔</ENT>
              <ENT>✔</ENT>
              <ENT>YY/MM/DD HH:mm</ENT>
              <ENT>Yr./Mon./Day Hrs. min</ENT>
            </ROW>
            <ROW>
              <ENT I="01">Sample period start time</ENT>
              <ENT>7.4.12</ENT>
              <ENT/>
              <ENT>✔</ENT>
              <ENT>✔</ENT>
              <ENT>✔■</ENT>
              <ENT>YYYY/MM/DD HH:mm</ENT>
              <ENT>Yr./Mon./Day Hrs. min</ENT>
            </ROW>
            <ROW>
              <ENT I="01">Elapsed sample time</ENT>
              <ENT>7.4.13</ENT>
              <ENT>*</ENT>
              <ENT>✔</ENT>
              <ENT>✔</ENT>
              <ENT>✔■</ENT>
              <ENT>HH:mm</ENT>
              <ENT>Hrs. min</ENT>
            </ROW>
            <ROW>
              <ENT I="01">Elapsed sample time, out of spec. (FLAG <SU>6</SU>)</ENT>
              <ENT>7.4.13</ENT>
              <ENT/>
              <ENT>✔</ENT>
              <ENT>✔</ENT>
              <ENT>✔■</ENT>
              <ENT>On/Off</ENT>
              <ENT/>
            </ROW>
            <ROW>
              <PRTPAGE P="83"/>
              <ENT I="01">Power interruptions ≤1 min., start time of first 10</ENT>
              <ENT>7.4.15.5</ENT>
              <ENT>*</ENT>
              <ENT>✔</ENT>
              <ENT>*</ENT>
              <ENT>✔</ENT>
              <ENT>1HH:mm, 2HH:mm, etc ...</ENT>
              <ENT>Hrs. min</ENT>
            </ROW>
            <ROW>
              <ENT I="01">User-entered information, such as sampler and site identification</ENT>
              <ENT>7.4.16</ENT>
              <ENT>✔</ENT>
              <ENT>✔</ENT>
              <ENT>✔</ENT>
              <ENT>✔■</ENT>
              <ENT>As entered</ENT>
              <ENT/>
            </ROW>
            <TNOTE>✔ Provision of this information is required.</TNOTE>
            <TNOTE>*Provision of this information is optional. If information related to the entire sample period is optionally provided prior to the end of the sample period, the value provided should be the value calculated for the portion of the sampler period completed up to the time the information is provided.</TNOTE>
            <TNOTE>■ Indicates that this information is also required to be provided to the AIRS data bank; see § § 58.26 and 58.35 of this chapter.</TNOTE>
            <TNOTE>
              <SU>1</SU> Information is required to be available to the operator at any time the sampler is operating, whether sampling or not.</TNOTE>
            <TNOTE>
              <SU>2</SU> Information relates to the entire sampler period and must be provided following the end of the sample period until reset manually by the operator or automatically by the sampler upon the start of a new sample period.</TNOTE>
            <TNOTE>
              <SU>3</SU> Information shall be available to the operator visually.</TNOTE>
            <TNOTE>
              <SU>4</SU> Information is to be available as digital data at the sampler's data output port specified in section 7.4.16 of this appendix following the end of the sample period until reset manually by the operator or automatically by the sampler upon the start of a new sample period.</TNOTE>
            <TNOTE>
              <SU>5</SU> Digital readings, both visual and data output, shall have not less than the number of significant digits and resolution specified.</TNOTE>
            <TNOTE>
              <SU>6</SU> Flag warnings may be displayed to the operator by a single-flag indicator or each flag may be displayed individually. Only a set (on) flag warning must be indicated; an off (unset) flag may be indicated by the absence of a flag warning. Sampler users should refer to section 10.12 of this appendix regarding the validity of samples for which the sampler provided an associated flag warning.</TNOTE>
          </GPOTABLE>
          <P>8.0 <E T="03">Filter Weighing.</E> See reference 2 in section 13.0 of this appendix, for additional, more detailed guidance.</P>
          <P>8.1 <E T="03">Analytical balance.</E> The analytical balance used to weigh filters must be suitable for weighing the type and size of filters specified, under section 6.0 of this appendix, and have a readability of ±1 µg. The balance shall be calibrated as specified by the manufacturer at installation and recalibrated immediately prior to each weighing session. See reference 2 in section 13.0 of this appendix for additional guidance.</P>
          <P>8.2 <E T="03">Filter conditioning.</E> All sample filters used shall be conditioned immediately before both the pre- and post-sampling weighings as specified below. See reference 2 in section 13.0 of this appendix for additional guidance.</P>
          <P>8.2.1 <E T="03">Mean temperature.</E> 20 - 23 °C.</P>
          <P>8.2.2 <E T="03">Temperature control.</E> ±2 °C over 24 hours.</P>
          <P>8.2.3 <E T="03">Mean humidity.</E> Generally, 30-40 percent relative humidity; however, where it can be shown that the mean ambient relative humidity during sampling is less than 30 percent, conditioning is permissible at a mean relative humidity within ±5 relative humidity percent of the mean ambient relative humidity during sampling, but not less than 20 percent.</P>
          <P>8.2.4 <E T="03">Humidity control.</E> ±5 relative humidity percent over 24 hours.</P>
          <P>8.2.5 <E T="03">Conditioning time.</E> Not less than 24 hours.</P>
          <P>8.3 <E T="03">Weighing procedure.</E>
          </P>
          <P>8.3.1 New filters should be placed in the conditioning environment immediately upon arrival and stored there until the pre-sampling weighing. See reference 2 in section 13.0 of this appendix for additional guidance.</P>
          <P>8.3.2 The analytical balance shall be located in the same controlled environment in which the filters are conditioned. The filters shall be weighed immediately following the conditioning period without intermediate or transient exposure to other conditions or environments.</P>
          <P>8.3.3 Filters must be conditioned at the same conditions (humidity within ±5 relative humidity percent) before both the pre- and post-sampling weighings.</P>
          <P>8.3.4 Both the pre- and post-sampling weighings should be carried out on the same analytical balance, using an effective technique to neutralize static charges on the filter, under reference 2 in section 13.0 of this appendix. If possible, both weighings should be carried out by the same analyst.</P>
          <P>8.3.5 The pre-sampling (tare) weighing shall be within 30 days of the sampling period.</P>
          <P>8.3.6 The post-sampling conditioning and weighing shall be completed within 240 hours (10 days) after the end of the sample period, unless the filter sample is maintained at 4 °C or less during the entire time between retrieval from the sampler and the start of the conditioning, in which case the period shall not exceed 30 days. Reference 2 in section 13.0 of this appendix has additional guidance on transport of cooled filters.</P>
          <P>8.3.7 <E T="03">Filter blanks.</E>
            <PRTPAGE P="84"/>
          </P>

          <P>8.3.7.1 New field blank filters shall be weighed along with the pre-sampling (tare) weighing of each lot of PM<E T="52">2.5</E> filters. These blank filters shall be transported to the sampling site, installed in the sampler, retrieved from the sampler without sampling, and reweighed as a quality control check.</P>

          <P>8.3.7.2 New laboratory blank filters shall be weighed along with the pre-sampling (tare) weighing of each set of PM<E T="52">2.5</E> filters. These laboratory blank filters should remain in the laboratory in protective containers during the field sampling and should be reweighed as a quality control check.</P>
          <P>8.3.8 Additional guidance for proper filter weighing and related quality assurance activities is provided in reference 2 in section 13.0 of this appendix.</P>
          <P>9.0 <E T="03">Calibration.</E> Reference 2 in section 13.0 of this appendix contains additional guidance.</P>
          <P>9.1 <E T="03">General requirements.</E>
          </P>
          <P>9.1.1 Multipoint calibration and single-point verification of the sampler's flow rate measurement device must be performed periodically to establish and maintain traceability of subsequent flow measurements to a flow rate standard.</P>
          <P>9.1.2 An authoritative flow rate standard shall be used for calibrating or verifying the sampler's flow rate measurement device with an accuracy of ±2 percent. The flow rate standard shall be a separate, stand-alone device designed to connect to the flow rate measurement adapter, Figure L-30 of this appendix. This flow rate standard must have its own certification and be traceable to a National Institute of Standards and Technology (NIST) primary standard for volume or flow rate. If adjustments to the sampler's flow rate measurement system calibration are to be made in conjunction with an audit of the sampler's flow measurement system, such adjustments shall be made following the audit. Reference 2 in section 13.0 of this appendix contains additional guidance.</P>
          <P>9.1.3 The sampler's flow rate measurement device shall be re-calibrated after electromechanical maintenance or transport of the sampler.</P>
          <P>9.2 <E T="03">Flow rate calibration/verification procedure.</E>
          </P>
          <P>9.2.1 PM<E T="52">2.5</E> samplers may employ various types of flow control and flow measurement devices. The specific procedure used for calibration or verification of the flow rate measurement device will vary depending on the type of flow rate controller and flow rate measurement employed. Calibration shall be in terms of actual ambient volumetric flow rates (Q<E T="51">a</E>), measured at the sampler's inlet downtube. The generic procedure given here serves to illustrate the general steps involved in the calibration of a PM<E T="52">2.5</E> sampler. The sampler operation/instruction manual required under section 7.4.18 of this appendix and the Quality Assurance Handbook in reference 2 in section 13.0 of this appendix provide more specific and detailed guidance for calibration.</P>

          <P>9.2.2 The flow rate standard used for flow rate calibration shall have its own certification and be traceable to a NIST primary standard for volume or flow rate. A calibration relationship for the flow rate standard, e.g., an equation, curve, or family of curves relating actual flow rate (Q<E T="52">a</E>) to the flow rate indicator reading, shall be established that is accurate to within 2 percent over the expected range of ambient temperatures and pressures at which the flow rate standard may be used. The flow rate standard must be re-calibrated or re-verified at least annually.</P>
          <P>9.2.3 The sampler flow rate measurement device shall be calibrated or verified by removing the sampler inlet and connecting the flow rate standard to the sampler's downtube in accordance with the operation/instruction manual, such that the flow rate standard accurately measures the sampler's flow rate. The sampler operator shall first carry out a sampler leak check and confirm that the sampler passes the leak test and then verify that no leaks exist between the flow rate standard and the sampler.</P>
          <P>9.2.4 The calibration relationship between the flow rate (in actual L/min) indicated by the flow rate standard and by the sampler's flow rate measurement device shall be established or verified in accordance with the sampler operation/instruction manual. Temperature and pressure corrections to the flow rate indicated by the flow rate standard may be required for certain types of flow rate standards. Calibration of the sampler's flow rate measurement device shall consist of at least three separate flow rate measurements (multipoint calibration) evenly spaced within the range of -10 percent to =10 percent of the sampler's operational flow rate, section 7.4.1 of this appendix. Verification of the sampler's flow rate shall consist of one flow rate measurement at the sampler's operational flow rate. The sampler operation/instruction manual and reference 2 in section 13.0 of this appendix provide additional guidance.</P>
          <P>9.2.5 If during a flow rate verification the reading of the sampler's flow rate indicator or measurement device differs by ±4 percent or more from the flow rate measured by the flow rate standard, a new multipoint calibration shall be performed and the flow rate verification must then be repeated.</P>

          <P>9.2.6 Following the calibration or verification, the flow rate standard shall be removed from the sampler and the sampler inlet shall be reinstalled. Then the sampler's normal operating flow rate (in L/min) shall be determined with a clean filter in place. If the flow rate indicated by the sampler differs by ±2 percent or more from the required sampler flow rate, the sampler flow rate must be adjusted to the required flow rate, under section 7.4.1 of this appendix.<PRTPAGE P="85"/>
          </P>
          <P>9.3 Periodic calibration or verification of the calibration of the sampler's ambient temperature, filter temperature, and barometric pressure measurement systems is also required. Reference 3 of section 13.0 of this appendix contains additional guidance.</P>
          <P>10.0 <E T="03">PM</E>
            <E T="52">2.5</E>
            <E T="03">Measurement Procedure.</E> The detailed procedure for obtaining valid PM<E T="52">2.5</E> measurements with each specific sampler designated as part of a reference method for PM<E T="52">2.5</E> under part 53 of this chapter shall be provided in the sampler-specific operation or instruction manual required by section 7.4.18 of this appendix. Supplemental guidance is provided in section 2.12 of the Quality Assurance Handbook listed in reference 2 in section 13.0 of this appendix. The generic procedure given here serves to illustrate the general steps involved in the PM<E T="52">2.5</E> sample collection and measurement, using a PM<E T="52">2.5</E> reference method sampler.</P>
          <P>10.1 The sampler shall be set up, calibrated, and operated in accordance with the specific, detailed guidance provided in the specific sampler's operation or instruction manual and in accordance with a specific quality assurance program developed and established by the user, based on applicable supplementary guidance provided in reference 2 in section 13.0 of this appendix.</P>
          <P>10.2 Each new sample filter shall be inspected for correct type and size and for pinholes, particles, and other imperfections. Unacceptable filters should be discarded. A unique identification number shall be assigned to each filter, and an information record shall be established for each filter. If the filter identification number is not or cannot be marked directly on the filter, alternative means, such as a number-identified storage container, must be established to maintain positive filter identification.</P>
          <P>10.3 Each filter shall be conditioned in the conditioning environment in accordance with the requirements specified in section 8.2 of this appendix.</P>
          <P>10.4 Following conditioning, each filter shall be weighed in accordance with the requirements specified in section 8.0 of this appendix and the presampling weight recorded with the filter identification number.</P>
          <P>10.5 A numbered and preweighed filter shall be installed in the sampler following the instructions provided in the sampler operation or instruction manual.</P>
          <P>10.6 The sampler shall be checked and prepared for sample collection in accordance with instructions provided in the sampler operation or instruction manual and with the specific quality assurance program established for the sampler by the user.</P>
          <P>10.7 The sampler's timer shall be set to start the sample collection at the beginning of the desired sample period and stop the sample collection 24 hours later.</P>
          <P>10.8 Information related to the sample collection (site location or identification number, sample date, filter identification number, and sampler model and serial number) shall be recorded and, if appropriate, entered into the sampler.</P>
          <P>10.9 The sampler shall be allowed to collect the PM<E T="52">2.5</E> sample during the set 24-hour time period.</P>
          <P>10.10 Within 96 hours of the end of the sample collection period, the filter, while still contained in the filter cassette, shall be carefully removed from the sampler, following the procedure provided in the sampler operation or instruction manual and the quality assurance program, and placed in a protective container. The protective container shall contain no loose material that could be transferred to the filter. The protective container shall hold the filter cassette securely such that the cover shall not come in contact with the filter's surfaces. Reference 2 in section 13.0 of this appendix contains additional information.</P>
          <P>10.11 The total sample volume in actual m<SU>3</SU> for the sampling period and the elapsed sample time shall be obtained from the sampler and recorded in accordance with the instructions provided in the sampler operation or instruction manual. All sampler warning flag indications and other information required by the local quality assurance program shall also be recorded.</P>
          <P>10.12 All factors related to the validity or representativeness of the sample, such as sampler tampering or malfunctions, unusual meteorological conditions, construction activity, fires or dust storms, etc. shall be recorded as required by the local quality assurance program. The occurrence of a flag warning during a sample period shall not necessarily indicate an invalid sample but rather shall indicate the need for specific review of the QC data by a quality assurance officer to determine sample validity.</P>

          <P>10.13 After retrieval from the sampler, the exposed filter containing the PM<E T="52">2.5</E> sample should be transported to the filter conditioning environment as soon as possible ideally to arrive at the conditioning environment within 24 hours for conditioning and subsequent weighing. During the period between filter retrieval from the sampler and the start of the conditioning, the filter shall be maintained as cool as practical and continuously protected from exposure to temperatures over 25 °C. See section 8.3.6 of this appendix regarding time limits for completing the post-sampling weighing. See reference 2 in section 13.0 of this appendix for additional guidance on transporting filter samplers to the conditioning and weighing laboratory.</P>
          <P>10.14. The exposed filter containing the PM<E T="52">2.5</E> sample shall be re-conditioned in the conditioning environment in accordance with the requirements specified in section 8.2 of this appendix.<PRTPAGE P="86"/>
          </P>
          <P>10.15. The filter shall be reweighed immediately after conditioning in accordance with the requirements specified in section 8.0 of this appendix, and the postsampling weight shall be recorded with the filter identification number.</P>
          <P>10.16 The PM<E T="52">2.5</E> concentration shall be calculated as specified in section 12.0 of this appendix.</P>
          <P>11.0 <E T="03">Sampler Maintenance.</E> The sampler shall be maintained as described by the sampler's manufacturer in the sampler-specific operation or instruction manual required under section 7.4.18 of this appendix and in accordance with the specific quality assurance program developed and established by the user based on applicable supplementary guidance provided in reference 2 in section 13.0 of this appendix.</P>
          <P>12.0 <E T="03">Calculations</E>
          </P>
          <P>12.1 (a) The PM<E T="52">2.5</E> concentration is calculated as:
          </P>
          <FP SOURCE="FP-1">PM<E T="52">2.5</E> = (W<E T="52">f</E> − W<E T="52">i</E>)/V<E T="52">a</E>
          </FP>
          
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">PM<E T="52">2.5</E> = mass concentration of PM<E T="52">2.5</E>, µg/m<SU>3</SU>;</FP>
          <FP SOURCE="FP-1">W<E T="52">f</E>, W<E T="52">i</E> = final and initial weights, respectively, of the filter used to collect the PM<E T="52">2.5</E> particle sample, µg;</FP>
          <FP SOURCE="FP-1">V<E T="52">a</E> = total air volume sampled in actual volume units, as provided by the sampler, m<SU>3</SU>.</FP>
          
          <NOTE>
            <HD SOURCE="HED">Note:</HD>

            <P>Total sample time must be between 1,380 and 1,500 minutes (23 and 25 hrs) for a fully valid PM<E T="52">2.5</E> sample; however, see also section 3.3 of this appendix.</P>
          </NOTE>
          <P>13.0 <E T="03">References.</E>
          </P>
          <P>1. Quality Assurance Handbook for Air Pollution Measurement Systems, Volume I, Principles. EPA/600/R-94/038a, April 1994. Available from CERI, ORD Publications, U.S. Environmental Protection Agency, 26 West Martin Luther King Drive, Cincinnati, Ohio 45268.</P>
          <P>2. Copies of section 2.12 of the Quality Assurance Handbook for Air Pollution Measurement Systems, Volume II, Ambient Air Specific Methods, EPA/600/R-94/038b, are available from Department E (MD-77B), U.S. EPA, Research Triangle Park, NC 27711.</P>
          <P>3. Quality Assurance Handbook for Air Pollution Measurement Systems, Volume IV: Meteorological Measurements, (Revised Edition) EPA/600/R-94/038d, March, 1995. Available from CERI, ORD Publications, U.S. Environmental Protection Agency, 26 West Martin Luther King Drive, Cincinnati, Ohio 45268.</P>
          <P>4. Military standard specification (mil. spec.) 8625F, Type II, Class 1 as listed in Department of Defense Index of Specifications and Standards (DODISS), available from DODSSP-Customer Service, Standardization Documents Order Desk, 700 Robbins Avenue, Building 4D, Philadelphia, PA 1911-5094.</P>
          <P>14.0 <E T="03">Figures L-1 through L-30 to Appendix L.</E>
          </P>
          <GPH DEEP="422" SPAN="2">
            <PRTPAGE P="87"/>
            <GID>ER18JY97.022</GID>
          </GPH>
          <GPH DEEP="470" SPAN="2">
            <PRTPAGE P="88"/>
            <GID>ER18JY97.023</GID>
          </GPH>
          <GPH DEEP="470" SPAN="2">
            <PRTPAGE P="89"/>
            <GID>ER18JY97.024</GID>
          </GPH>
          <GPH DEEP="470" SPAN="2">
            <PRTPAGE P="90"/>
            <GID>ER18JY97.025</GID>
          </GPH>
          <GPH DEEP="470" SPAN="2">
            <PRTPAGE P="91"/>
            <GID>ER17FE98.004</GID>
          </GPH>
          <GPH DEEP="468" SPAN="2">
            <PRTPAGE P="92"/>
            <GID>ER18JY97.027</GID>
          </GPH>
          <GPH DEEP="470" SPAN="2">
            <PRTPAGE P="93"/>
            <GID>ER18JY97.028</GID>
          </GPH>
          <GPH DEEP="470" SPAN="2">
            <PRTPAGE P="94"/>
            <GID>ER18JY97.029</GID>
          </GPH>
          <GPH DEEP="470" SPAN="2">
            <PRTPAGE P="95"/>
            <GID>ER18JY97.030</GID>
          </GPH>
          <GPH DEEP="470" SPAN="2">
            <PRTPAGE P="96"/>
            <GID>ER18JY97.031</GID>
          </GPH>
          <GPH DEEP="470" SPAN="2">
            <PRTPAGE P="97"/>
            <GID>ER18JY97.032</GID>
          </GPH>
          <GPH DEEP="470" SPAN="2">
            <PRTPAGE P="98"/>
            <GID>ER17FE98.005</GID>
          </GPH>
          <GPH DEEP="470" SPAN="2">
            <PRTPAGE P="99"/>
            <GID>ER18JY97.034</GID>
          </GPH>
          <GPH DEEP="460" SPAN="2">
            <PRTPAGE P="100"/>
            <GID>ER18JY97.035</GID>
          </GPH>
          <GPH DEEP="470" SPAN="2">
            <PRTPAGE P="101"/>
            <GID>ER18JY97.036</GID>
          </GPH>
          <GPH DEEP="469" SPAN="2">
            <PRTPAGE P="102"/>
            <GID>ER18JY97.037</GID>
          </GPH>
          <GPH DEEP="470" SPAN="2">
            <PRTPAGE P="103"/>
            <GID>ER18JY97.038</GID>
          </GPH>
          <GPH DEEP="470" SPAN="2">
            <PRTPAGE P="104"/>
            <GID>ER18JY97.039</GID>
          </GPH>
          <GPH DEEP="470" SPAN="2">
            <PRTPAGE P="105"/>
            <GID>ER18JY97.040</GID>
          </GPH>
          <GPH DEEP="470" SPAN="2">
            <PRTPAGE P="106"/>
            <GID>ER18JY97.041</GID>
          </GPH>
          <GPH DEEP="470" SPAN="2">
            <PRTPAGE P="107"/>
            <GID>ER18JY97.042</GID>
          </GPH>
          <GPH DEEP="463" SPAN="2">
            <PRTPAGE P="108"/>
            <GID>ER18JY97.043</GID>
          </GPH>
          <GPH DEEP="469" SPAN="2">
            <PRTPAGE P="109"/>
            <GID>ER18JY97.044</GID>
          </GPH>
          <GPH DEEP="470" SPAN="2">
            <PRTPAGE P="110"/>
            <GID>ER18JY97.045</GID>
          </GPH>
          <GPH DEEP="470" SPAN="2">
            <PRTPAGE P="111"/>
            <GID>ER18JY97.046</GID>
          </GPH>
          <GPH DEEP="470" SPAN="2">
            <PRTPAGE P="112"/>
            <GID>ER17FE98.006</GID>
          </GPH>
          <GPH DEEP="465" SPAN="2">
            <PRTPAGE P="113"/>
            <GID>ER18JY97.048</GID>
          </GPH>
          <GPH DEEP="466" SPAN="2">
            <PRTPAGE P="114"/>
            <GID>ER18JY97.049</GID>
          </GPH>
          <GPH DEEP="466" SPAN="2">
            <PRTPAGE P="115"/>
            <GID>ER18JY97.050</GID>
          </GPH>
          <GPH DEEP="470" SPAN="2">
            <PRTPAGE P="116"/>
            <GID>ER18JY97.051</GID>
          </GPH>
          <CITA>[62 FR 38714, July 18, 1997, as amended at 64 FR 19719, Apr. 22, 1999]</CITA>
        </APPENDIX>
        <APPENDIX>
          <PRTPAGE P="117"/>
          <RESERVED>Appendix M to Part 50 [Reserved]</RESERVED>
        </APPENDIX>
        <APPENDIX>
          <EAR>Pt. 50, App. N</EAR>

          <HD SOURCE="HED">Appendix N to Part 50—Interpretation of the National Ambient Air Quality Standards for PM<E T="52">2.5</E>
          </HD>
          <P>1.0 <E T="03">General.</E>
          </P>

          <P>(a) This appendix explains the data handling conventions and computations necessary for determining when the annual and 24-hour primary and secondary national ambient air quality standards for PM specified in § 50.7 of this part are met. Particulate matter is measured in the ambient air as PM<E T="52">2.5</E> (particles with an aerodynamic diameter less than or equal to a nominal 2.5 micrometers) by a reference method based on appendix L of this part, as applicable, and designated in accordance with part 53 of this chapter, or by an equivalent method designated in accordance with part 53 of this chapter. Data handling and computation procedures to be used in making comparisons between reported PM<E T="52">2.5</E> concentrations and the levels of the PM standards are specified in the following sections.</P>
          <P>(b) Data resulting from uncontrollable or natural events, for example structural fires or high winds, may require special consideration. In some cases, it may be appropriate to exclude these data because they could result in inappropriate values to compare with the levels of the PM standards. In other cases, it may be more appropriate to retain the data for comparison with the level of the PM standards and then allow the EPA to formulate the appropriate regulatory response. Whether to exclude, retain, or make adjustments to the data affected by uncontrollable or natural events is subject to the approval of the appropriate Regional Administrator.</P>
          <P>(c) The terms used in this appendix are defined as follows:</P>
          <P>Average and mean refer to an arithmetic mean.</P>

          <P>Daily value for PM refers to the 24-hour average concentration of PM<E T="52">2.5</E> calculated or measured from midnight to midnight (local time).</P>
          <P>Designated monitors are those monitoring sites designated in a State PM Monitoring Network Description for spatial averaging in areas opting for spatial averaging in accordance with part 58 of this chapter.</P>
          <P>98th percentile means the daily value out of a year of PM<E T="52">2.5</E> monitoring data below which 98 percent of all values in the group fall.</P>
          <P>Year refers to a calendar year.</P>
          <P>(d) Sections 2.1 and 2.5 of this appendix contain data handling instructions for the option of using a spatially averaged network of monitors for the annual standard. If spatial averaging is not considered for an area, then the spatial average is equivalent to the annual average of a single site and is treated accordingly in subsequent calculations. For example, paragraph (a)(3) of section 2.1 of this appendix could be eliminated since the spatial average would be equivalent to the annual average.</P>
          <P>2.0 <E T="03">Comparisons with the PM</E>
            <E T="52">2.5</E>
            <E T="03">Standards.</E>
          </P>
          <P>2.1 <E T="03">Annual PM</E>
            <E T="52">2.5</E>
            <E T="03">Standard.</E>
          </P>
          <P>(a) The annual PM<E T="52">2.5</E> standard is met when the 3-year average of the spatially averaged annual means is less than or equal to 15.0 µg/m<SU>3</SU>. The 3-year average of the spatially averaged annual means is determined by averaging quarterly means at each monitor to obtain the annual mean PM<E T="52">2.5</E> concentrations at each monitor, then averaging across all designated monitors, and finally averaging for 3 consecutive years. The steps can be summarized as follows:</P>
          <P>(1) Average 24-hour measurements to obtain quarterly means at each monitor.</P>
          <P>(2) Average quarterly means to obtain annual means at each monitor.</P>
          <P>(3) Average across designated monitoring sites to obtain an annual spatial mean for an area (this can be one site in which case the spatial mean is equal to the annual mean).</P>
          <P>(4) Average 3 years of annual spatial means to obtain a 3-year average of spatially averaged annual means.</P>

          <P>(b) In the case of spatial averaging, 3 years of spatial averages are required to demonstrate that the standard has been met. Designated sites with less than 3 years of data shall be included in spatial averages for those years that data completeness requirements are met. For the annual PM<E T="52">2.5</E> standard, a year meets data completeness requirements when at least 75 percent of the scheduled sampling days for each quarter have valid data. However, years with high concentrations and more than a minimal amount of data (at least 11 samples in each quarter) shall not be ignored just because they are comprised of quarters with less than complete data. Thus, in computing annual spatially averaged means, years containing quarters with at least 11 samples but less than 75 percent data completeness shall be included in the computation if the resulting spatially averaged annual mean concentration (rounded according to the conventions of section 2.3 of this appendix) is greater than the level of the standard.</P>
          <P>(c) Situations may arise in which there are compelling reasons to retain years containing quarters which do not meet the data completeness requirement of 75 percent or the minimum number of 11 samples. The use of less than complete data is subject to the approval of the appropriate Regional Administrator.</P>

          <P>(d) The equations for calculating the 3-year average annual mean of the PM<E T="52">2.5</E> standard are given in section 2.5 of this appendix.</P>
          <P>2.2 <E T="03">24-Hour PM</E>
            <E T="52">2.5</E>
            <E T="03">Standard.</E>
          </P>
          <P>(a) The 24-hour PM<E T="52">2.5</E> standard is met when the 3-year average of the 98<E T="51">th</E> percentile values at each monitoring site is less than or <PRTPAGE P="118"/>equal to 65 µg/m<SU>3</SU>. This comparison shall be based on 3 consecutive, complete years of air quality data. A year meets data completeness requirements when at least 75 percent of the scheduled sampling days for each quarter have valid data. However, years with high concentrations shall not be ignored just because they are comprised of quarters with less than complete data. Thus, in computing the 3-year average 98<E T="51">th</E> percentile value, years containing quarters with less than 75 percent data completeness shall be included in the computation if the annual 98<E T="51">th</E> percentile value (rounded according to the conventions of section 2.3 of this appendix) is greater than the level of the standard.</P>
          <P>(b) Situations may arise in which there are compelling reasons to retain years containing quarters which do not meet the data completeness requirement. The use of less than complete data is subject to the approval of the appropriate Regional Administrator.</P>

          <P>(c) The equations for calculating the 3-year average of the annual 98<E T="51">th</E> percentile values is given in section 2.6 of this appendix.</P>
          <P>2.3 <E T="03">Rounding Conventions.</E> For the purposes of comparing calculated values to the applicable level of the standard, it is necessary to round the final results of the calculations described in sections 2.5 and 2.6 of this appendix. For the annual PM<E T="52">2.5</E> standard, the 3-year average of the spatially averaged annual means shall be rounded to the nearest 0.1 µg/m<SU>3</SU> (decimals 0.05 and greater are rounded up to the next 0.1, and any decimal lower than 0.05 is rounded down to the nearest 0.1). For the 24-hour PM<E T="52">2.5</E> standard, the 3-year average of the annual 98<E T="51">th</E> percentile values shall be rounded to the nearest 1 µg/m<SU>3</SU> (decimals 0.5 and greater are rounded up to nearest whole number, and any decimal lower than 0.5 is rounded down to the nearest whole number).</P>
          <P>2.4 <E T="03">Monitoring Considerations.</E>
          </P>

          <P>(a) Section 58.13 of this chapter specifies the required minimum frequency of sampling for PM<E T="52">2.5</E>. Exceptions to the specified sampling frequencies, such as a reduced frequency during a season of expected low concentrations, are subject to the approval of the appropriate Regional Administrator. Section 58.14 of 40 CFR part 58 and section 2.8 of appendix D of 40 CFR part 58, specify which monitors are eligible for making comparisons with the PM standards. In determining a spatial mean using two or more monitoring sites operating in a given year, the annual mean for an individual site may be included in the spatial mean if and only if the mean for that site meets the criterion specified in § 2.8 of appendix D of 40 CFR part 58. In the event data from an otherwise eligible site is excluded from being averaged with data from other sites on the basis of this criterion, then the 3-year mean from that site shall be compared directly to the annual standard.</P>
          <P>(b) For the annual PM<E T="52">2.5</E> standard, when designated monitors are located at the same site and are reporting PM<E T="52">2.5</E> values for the same time periods, and when spatial averaging has been chosen, their concentrations shall be averaged before an area-wide spatial average is calculated. Such monitors will then be considered as one monitor.</P>
          <P>2.5 <E T="03">Equations for the Annual PM</E>
            <E T="52">2.5</E>
            <E T="03">Standard.</E>
          </P>
          <P>(a) An annual mean value for PM<E T="52">2.5</E> is determined by first averaging the daily values of a calendar quarter:</P>
          <HD SOURCE="HD2">Equation 1</HD>
          <GPH DEEP="32" SPAN="1">
            <GID>ER18JY97.000</GID>
          </GPH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">x<AC T="8"/>
            <E T="52">q,y,s</E> = the mean for quarter q of year y for site s;</FP>
          <FP SOURCE="FP-1">n<E T="52">q</E> = the number of monitored values in the quarter; and</FP>
          <FP SOURCE="FP-1">x<E T="52">i,q,y,s</E> = the i<E T="51">th</E> value in quarter q for year y for site s.</FP>
          
          <P>(b) The following equation is then to be used for calculation of the annual mean:</P>
          <HD SOURCE="HD2">Equation 2</HD>
          <GPH DEEP="31" SPAN="1">
            <GID>ER18JY97.001</GID>
          </GPH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">x<AC T="8"/>
            <E T="52">y,s</E> = the annual mean concentration for year y (y = 1, 2, or 3) and for site s; and</FP>
          <FP SOURCE="FP-1">x<AC T="8"/>
            <E T="52">q,y,s</E> = the mean for quarter q of year y for site s.</FP>
          

          <P>(c)(1) The spatially averaged annual mean for year y is computed by first calculating the annual mean for each site designated to be included in a spatial average, x<AC T="8"/>
            <E T="52">y,s</E>, and then computing the average of these values across sites:</P>
          <HD SOURCE="HD2">Equation 3</HD>
          <GPH DEEP="31" SPAN="1">
            <GID>ER18JY97.002</GID>
          </GPH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">x<AC T="8"/>
            <E T="52">y</E> = the spatially averaged mean for year y;</FP>
          <FP SOURCE="FP-1">x<AC T="8"/>
            <E T="52">y,s</E> = the annual mean for year y and site s; and</FP>
          <FP SOURCE="FP-1">n<E T="52">s</E> = the number of sites designated to be averaged.</FP>
          

          <P>(2) In the event that an area designated for spatial averaging has two or more sites at the same location producing data for the <PRTPAGE P="119"/>same time periods, the sites are averaged together before using Equation 3 by:</P>
          <HD SOURCE="HD2">Equation 4</HD>
          <GPH DEEP="30" SPAN="1">
            <GID>ER18JY97.003</GID>
          </GPH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">x<AC T="8"/>
            <E T="52">y,s*</E> = the annual mean for year y for the sites at the same location (which will now be considered one site);</FP>
          <FP SOURCE="FP-1">n<E T="52">c</E> = the number of sites at the same location designated to be included in the spatial average; and</FP>
          <FP SOURCE="FP-1">x<AC T="8"/>
            <E T="52">y,s</E> = the annual mean for year y and site s.</FP>
          
          <P>(d) The 3-year average of the spatially averaged annual means is calculated by using the following equation:</P>
          <HD SOURCE="HD2">Equation 5</HD>
          <GPH DEEP="31" SPAN="1">
            <GID>ER18JY97.004</GID>
          </GPH>
          <FP>where:</FP>
          
          <FP SOURCE="FP-1">x<AC T="8"/> = the 3-year average of the spatially averaged annual means; and</FP>
          <FP SOURCE="FP-1">x<AC T="8"/>
            <E T="52">y</E> = the spatially averaged annual mean for year y.</FP>
          

          <HD SOURCE="HD2">Example 1—Area Designated for Spatial Averaging That Meets the Primary Annual PM<E T="52">2.5</E> Standard.</HD>

          <P>a. In an area designated for spatial averaging, four designated monitors recorded data in at least 1 year of a particular 3-year period. Using Equations 1 and 2, the annual means for PM<E T="52">2.5</E> at each site are calculated for each year. The following table can be created from the results. Data completeness percentages for the quarter with the fewest number of samples are also shown.</P>
          <GPOTABLE CDEF="s25,r35,9.1,9.1,9.1,9.1,8.2" COLS="7" OPTS="L2,tp8,i1">
            <TTITLE>Table 1—Results from Equations 1 and 2</TTITLE>
            <BOXHD>
              <CHED H="1"/>
              <CHED H="1"/>
              <CHED H="1">Site ⊥1</CHED>
              <CHED H="1">Site ⊥2</CHED>
              <CHED H="1">Site ⊥3</CHED>
              <CHED H="1">Site ⊥4</CHED>
              <CHED H="1">Spatial mean</CHED>
            </BOXHD>
            <ROW>
              <ENT I="01">Year 1</ENT>
              <ENT>Annual mean (µg/m<SU>3</SU>)</ENT>
              <ENT>12.7</ENT>
              <ENT/>
              <ENT/>
              <ENT/>
              <ENT>12.7</ENT>
            </ROW>
            <ROW>
              <ENT I="22"/>
              <ENT>% data completeness</ENT>
              <ENT>80</ENT>
              <ENT>0</ENT>
              <ENT>0</ENT>
              <ENT>0</ENT>
              <ENT/>
            </ROW>
            <ROW>
              <ENT I="01">Year 2</ENT>
              <ENT>Annual mean (µg/m<SU>3</SU>)</ENT>
              <ENT>12.6</ENT>
              <ENT>17.5</ENT>
              <ENT>15.2</ENT>
              <ENT/>
              <ENT>15.05</ENT>
            </ROW>
            <ROW>
              <ENT I="22"/>
              <ENT>% data completeness</ENT>
              <ENT>90</ENT>
              <ENT>63</ENT>
              <ENT>38</ENT>
              <ENT>0</ENT>
              <ENT/>
            </ROW>
            <ROW>
              <ENT I="01">Year 3</ENT>
              <ENT>Annual mean (µg/m<SU>3</SU>)</ENT>
              <ENT>12.5</ENT>
              <ENT>18.5</ENT>
              <ENT>14.1</ENT>
              <ENT>16.9</ENT>
              <ENT>15.50</ENT>
            </ROW>
            <ROW>
              <ENT I="22"/>
              <ENT>% data completeness</ENT>
              <ENT>90</ENT>
              <ENT>80</ENT>
              <ENT>85</ENT>
              <ENT>50</ENT>
              <ENT/>
            </ROW>
            <ROW>
              <ENT I="01">3-year mean</ENT>
              <ENT/>
              <ENT/>
              <ENT/>
              <ENT/>
              <ENT/>
              <ENT>14.42</ENT>
            </ROW>
          </GPOTABLE>

          <P>b. The data from these sites are averaged in the order described in section 2.1 of this appendix. Note that the annual mean from site #3 in year 2 and the annual mean from site #4 in year 3 do not meet the 75 percent data completeness criteria. Assuming the 38 percent data completeness represents a quarter with fewer than 11 samples, site #3 in year 2 does not meet the minimum data completeness requirement of 11 samples in each quarter. The site is therefore excluded from the calculation of the spatial mean for year 2. However, since the spatial mean for year 3 is above the level of the standard and the minimum data requirement of 11 samples in each quarter has been met, the annual mean from site #4 in year 3 is included in the calculation of the spatial mean for year 3 and in the calculation of the 3-year average. The 3-year average is rounded to 14.4 µg/m<SU>3</SU>, indicating that this area meets the annual PM<E T="52">2.5</E> standard.</P>

          <HD SOURCE="HD2">Example 2—Area With Two Monitors at the Same Location That Meets the Primary Annual PM<E T="52">2.5</E> Standard.</HD>

          <P>a. In an area designated for spatial averaging, six designated monitors, with two monitors at the same location (#5 and #6), recorded data in a particular 3-year period. Using Equations 1 and 2, the annual means for PM<E T="52">2.5</E> are calculated for each year. The following table can be created from the results.</P>
          <GPOTABLE CDEF="s25,10,10,10,10,10,10,6.2,6.2" COLS="9" OPTS="L2,tp8,i1">
            <TTITLE>Table 2—Results From Equations 1 and 2</TTITLE>
            <BOXHD>
              <CHED H="1">Annual mean (µg/m<SU>3</SU>)</CHED>
              <CHED H="1">Site ⊥1</CHED>
              <CHED H="1">Site ⊥2</CHED>
              <CHED H="1">Site ⊥3</CHED>
              <CHED H="1">Site ⊥4</CHED>
              <CHED H="1">Site ⊥5</CHED>
              <CHED H="1">Site ⊥6</CHED>
              <CHED H="1">Average of ⊥5 and ⊥6</CHED>
              <CHED H="1">Spatial mean</CHED>
            </BOXHD>
            <ROW>
              <ENT I="01">Year 1</ENT>
              <ENT>12.9</ENT>
              <ENT>9.9</ENT>
              <ENT>12.6</ENT>
              <ENT>11.1</ENT>
              <ENT>14.5</ENT>
              <ENT>14.6</ENT>
              <ENT>14.55</ENT>
              <ENT>12.21</ENT>
            </ROW>
            <ROW>
              <ENT I="01">Year 2</ENT>
              <ENT>14.5</ENT>
              <ENT>13.3</ENT>
              <ENT>12.2</ENT>
              <ENT>10.9</ENT>
              <ENT>16.1</ENT>
              <ENT>16.0</ENT>
              <ENT>16.05</ENT>
              <ENT>13.39</ENT>
            </ROW>
            <ROW>
              <ENT I="01">Year 3</ENT>
              <ENT>14.4</ENT>
              <ENT>12.4</ENT>
              <ENT>11.5</ENT>
              <ENT>9.7</ENT>
              <ENT>12.3</ENT>
              <ENT>12.1</ENT>
              <ENT>12.20</ENT>
              <ENT>12.04</ENT>
            </ROW>
            <ROW>
              <ENT I="01">3-Year mean</ENT>
              <ENT/>
              <ENT/>
              <ENT/>
              <ENT/>
              <ENT/>
              <ENT/>
              <ENT/>
              <ENT>12.55</ENT>
            </ROW>
          </GPOTABLE>
          <PRTPAGE P="120"/>

          <P>b. The annual means for sites #5 and #6 are averaged together using Equation 4 before the spatial average is calculated using Equation 3 since they are in the same location. The 3-year mean is rounded to 12.6 µg/m<SU>3</SU>, indicating that this area meets the annual PM<E T="52">2.5</E> standard.</P>

          <HD SOURCE="HD2">Example 3—Area With a Single Monitor That Meets the Primary Annual PM<E T="52">2.5</E> Standard.</HD>

          <P>a. Given data from a single monitor in an area, the calculations are as follows. Using Equations 1 and 2, the annual means for PM<E T="52">2.5</E> are calculated for each year. If the annual means are 10.28, 17.38, and 12.25 µg/m<SU>3</SU>, then the 3-year mean is:</P>
          <GPH DEEP="15" SPAN="2">
            <GID>ER18JY97.005</GID>
          </GPH>

          <P>b. This value is rounded to 13.3, indicating that this area meets the annual PM<E T="52">2.5</E> standard.</P>
          <P>2.6 <E T="03">Equations for the 24-Hour PM</E>
            <E T="52">2.5</E>
            <E T="03">Standard.</E>
          </P>

          <P>(a) When the data for a particular site and year meet the data completeness requirements in section 2.2 of this appendix, calculation of the 98<E T="51">th</E> percentile is accomplished by the following steps. All the daily values from a particular site and year comprise a series of values (x<E T="52">1</E>, x<E T="52">2</E>, x<E T="52">3</E>, ..., x<E T="52">n</E>), that can be sorted into a series where each number is equal to or larger than the preceding number (x<E T="52">[1]</E>, x<E T="52">[2]</E>, x<E T="52">[3]</E>, ..., x<E T="52">[n]</E>). In this case, x<E T="52">[1]</E> is the smallest number and x<E T="52">[n]</E> is the largest value. The 98<E T="51">th</E> percentile is found from the sorted series of daily values which is ordered from the lowest to the highest number. Compute (0.98) × (n) as the number “i.d”, where “i” is the integer part of the result and “d” is the decimal part of the result. The 98<E T="51">th</E> percentile value for year y, P<E T="52">0.98, y</E>, is given by Equation 6:</P>
          <HD SOURCE="HD2">Equation 6</HD>
          <GPH DEEP="14" SPAN="1">
            <GID>ER18JY97.006</GID>
          </GPH>
          <FP SOURCE="FP-1">where:</FP>
          
          <FP SOURCE="FP-1">P<E T="52">0.98,y</E> = 98<E T="51">th</E> percentile for year y;</FP>
          <FP SOURCE="FP-1">x<E T="52">[i=1]</E> = the (i=1)<E T="51">th</E> number in the ordered series of numbers; and</FP>
          <FP SOURCE="FP-1">i = the integer part of the product of 0.98 and n.</FP>
          
          <P>(b) The 3-year average 98<E T="51">th</E> percentile is then calculated by averaging the annual 98<E T="51">th</E> percentiles:</P>
          <HD SOURCE="HD2">Equation 7</HD>
          <GPH DEEP="42" SPAN="1">
            <GID>ER18JY97.007</GID>
          </GPH>
          <P>(c) The 3-year average 98<E T="51">th</E> percentile is rounded according to the conventions in section 2.3 of this appendix before a comparison with the standard is made.</P>

          <HD SOURCE="HD2">Example 4—Ambient Monitoring Site With Every-Day Sampling That Meets the Primary 24-Hour PM<E T="52">2.5</E> Standard.</HD>

          <P>a. In each year of a particular 3 year period, varying numbers of daily PM<E T="52">2.5</E> values (e.g., 281, 304, and 296) out of a possible 365 values were recorded at a particular site with the following ranked values (in µg/m<SU>3</SU>):</P>
          <GPOTABLE CDEF="10C,10C,10C,10C,10C,10C" COLS="6" OPTS="L2,tp8,i1">
            <TTITLE>Table 3—Ordered Monitoring Data For 3 Years</TTITLE>
            <BOXHD>
              <CHED H="1">Year 1</CHED>
              <CHED H="2">j rank</CHED>
              <CHED H="2">X<E T="52">j</E> value</CHED>
              <CHED H="1">Year 2</CHED>
              <CHED H="2">j rank</CHED>
              <CHED H="2">X<E T="52">j</E> value</CHED>
              <CHED H="1">Year 3</CHED>
              <CHED H="2">j rank</CHED>
              <CHED H="2">X<E T="52">j</E> value</CHED>
            </BOXHD>
            <ROW>
              <ENT I="01">275</ENT>
              <ENT>57.9</ENT>
              <ENT>296</ENT>
              <ENT>54.3</ENT>
              <ENT>290</ENT>
              <ENT>66.0</ENT>
            </ROW>
            <ROW>
              <ENT I="01">276</ENT>
              <ENT>59.0</ENT>
              <ENT>297</ENT>
              <ENT>57.1</ENT>
              <ENT>291</ENT>
              <ENT>68.4</ENT>
            </ROW>
            <ROW>
              <ENT I="01">277</ENT>
              <ENT>62.2</ENT>
              <ENT>298</ENT>
              <ENT>63.0</ENT>
              <ENT>292</ENT>
              <ENT>69.8</ENT>
            </ROW>
          </GPOTABLE>
          <P>b. Using Equation 6, the 98<E T="51">th</E> percentile values for each year are calculated as follows:</P>
          <GPH DEEP="17" SPAN="2">
            <GID>ER18JY97.008</GID>
          </GPH>
          <GPH DEEP="17" SPAN="2">
            <PRTPAGE P="121"/>
            <GID>ER18JY97.009</GID>
          </GPH>
          <GPH DEEP="17" SPAN="2">
            <GID>ER18JY97.010</GID>
          </GPH>
          <P>c.1. Using Equation 7, the 3-year average 98<E T="51">th</E> percentile is calculated as follows:</P>
          <GPH DEEP="24" SPAN="2">
            <GID>ER18JY97.011</GID>
          </GPH>
          <P>2. Therefore, this site meets the 24-hour PM<E T="52">2.5</E> standard.</P>
          <CITA>[62 FR 38755, July 18, 1997, as amended at 69 FR 45595, July 30, 2004]</CITA>
        </APPENDIX>
      </PART>
      <PART>
        <EAR>Pt. 51</EAR>
        <HD SOURCE="HED">PART 51—REQUIREMENTS FOR PREPARATION, ADOPTION, AND SUBMITTAL OF IMPLEMENTATION PLANS</HD>
        <CONTENTS>
          <SECHD>Sec.</SECHD>
          <SUBPART>
            <HD SOURCE="HED">Subpart A—Emission Inventory Reporting Requirements</HD>
            <SUBJGRP>
              <HD SOURCE="HED">General Information for Inventory Preparers</HD>
              <SECTNO>51.1</SECTNO>
              <SUBJECT>Who is responsible for actions described in this subpart?</SUBJECT>
              <SECTNO>51.5</SECTNO>
              <SUBJECT>What tools are available to help prepare and report emissions data?</SUBJECT>
              <SECTNO>51.10</SECTNO>

              <SUBJECT>How does my State report emissions that are required by the NO<E T="52">X</E> SIP Call?</SUBJECT>
            </SUBJGRP>
            <SUBJGRP>
              <HD SOURCE="HED">Specific Reporting Requirements</HD>
              <SECTNO>51.15</SECTNO>
              <SUBJECT>What data does my State need to report to EPA?</SUBJECT>
              <SECTNO>51.20</SECTNO>
              <SUBJECT>What are the emission thresholds that separate point and area sources?</SUBJECT>
              <SECTNO>51.25</SECTNO>
              <SUBJECT>What geographic area must my State's inventory cover?</SUBJECT>
              <SECTNO>51.30</SECTNO>
              <SUBJECT>When does my State report the data to EPA?</SUBJECT>
              <SECTNO>51.35</SECTNO>
              <SUBJECT>How can my State equalize the effort for annual reporting?</SUBJECT>
              <SECTNO>51.40</SECTNO>
              <SUBJECT>In what form should my State report the data to EPA?</SUBJECT>
              <SECTNO>51.45</SECTNO>
              <SUBJECT>Where should my State report the data?</SUBJECT>
              <APP>Appendix A to Subpart A of Part 51—Tables and Glossary</APP>
              <APP>Appendix B to Subpart A of Part 51 [Reserved]</APP>
            </SUBJGRP>
          </SUBPART>
          <SUBPART>
            <RESERVED>Subparts B-E [Reserved]</RESERVED>
          </SUBPART>
          <SUBPART>
            <HD SOURCE="HED">Subpart F—Procedural Requirements</HD>
            <SECTNO>51.100</SECTNO>
            <SUBJECT>Definitions.</SUBJECT>
            <SECTNO>51.101</SECTNO>
            <SUBJECT>Stipulations.</SUBJECT>
            <SECTNO>51.102</SECTNO>
            <SUBJECT>Public hearings.</SUBJECT>
            <SECTNO>51.103</SECTNO>
            <SUBJECT>Submission of plans, preliminary review of plans.</SUBJECT>
            <SECTNO>51.104</SECTNO>
            <SUBJECT>Revisions.</SUBJECT>
            <SECTNO>51.105</SECTNO>
            <SUBJECT>Approval of plans.</SUBJECT>
          </SUBPART>
          <SUBPART>
            <HD SOURCE="HED">Subpart G—Control Strategy</HD>
            <SECTNO>51.110</SECTNO>
            <SUBJECT>Attainment and maintenance of national standards.</SUBJECT>
            <SECTNO>51.111</SECTNO>
            <SUBJECT>Description of control measures.</SUBJECT>
            <SECTNO>51.112</SECTNO>
            <SUBJECT>Demonstration of adequacy.</SUBJECT>
            <SECTNO>51.113</SECTNO>
            <SUBJECT>[Reserved]</SUBJECT>
            <SECTNO>51.114</SECTNO>
            <SUBJECT>Emissions data and projections.</SUBJECT>
            <SECTNO>51.115</SECTNO>
            <SUBJECT>Air quality data and projections.</SUBJECT>
            <SECTNO>51.116</SECTNO>
            <SUBJECT>Data availability.</SUBJECT>
            <SECTNO>51.117</SECTNO>
            <SUBJECT>Additional provisions for lead.</SUBJECT>
            <SECTNO>51.118</SECTNO>
            <SUBJECT>Stack height provisions.</SUBJECT>
            <SECTNO>51.119</SECTNO>
            <SUBJECT>Intermittent control systems.</SUBJECT>
            <SECTNO>51.120</SECTNO>
            <SUBJECT>Requirements for State Implementation Plan revisions relating to new motor vehicles.</SUBJECT>
            <SECTNO>51.121</SECTNO>
            <SUBJECT>Findings and requirements for submission of State implementation plan revisions relating to emissions of oxides of nitrogen.</SUBJECT>
            <SECTNO>51.122</SECTNO>

            <SUBJECT>Emissions reporting requirements for SIP revisions relating to budgets for NO<E T="52">X</E> emissions.</SUBJECT>
            <SECTNO>51.123</SECTNO>
            <SUBJECT>Findings and requirements for submission of State implementation plan revisions relating to emissions of oxides of nitrogen pursuant to the Clean Air Interstate Rule.</SUBJECT>
            <SECTNO>51.124</SECTNO>
            <SUBJECT>Findings and requirements for submission of State implementation plan revisions relating to emissions of sulfur dioxide pursuant to the Clean Air Interstate Rule.</SUBJECT>
            <SECTNO>51.125</SECTNO>

            <SUBJECT>Emissions reporting requirements for SIP revisions relating to budgets for SO<E T="52">2</E> and NO<E T="52">X</E> emissions.</SUBJECT>
          </SUBPART>
          <SUBPART>
            <PRTPAGE P="122"/>
            <HD SOURCE="HED">Subpart H—Prevention of Air Pollution Emergency Episodes</HD>
            <SECTNO>51.150</SECTNO>
            <SUBJECT>Classification of regions for episode plans.</SUBJECT>
            <SECTNO>51.151</SECTNO>
            <SUBJECT>Significant harm levels.</SUBJECT>
            <SECTNO>51.152</SECTNO>
            <SUBJECT>Contingency plans.</SUBJECT>
            <SECTNO>51.153</SECTNO>
            <SUBJECT>Reevaluation of episode plans.</SUBJECT>
          </SUBPART>
          <SUBPART>
            <HD SOURCE="HED">Subpart I—Review of New Sources and Modifications</HD>
            <SECTNO>51.160</SECTNO>
            <SUBJECT>Legally enforceable procedures.</SUBJECT>
            <SECTNO>51.161</SECTNO>
            <SUBJECT>Public availability of information.</SUBJECT>
            <SECTNO>51.162</SECTNO>
            <SUBJECT>Identification of responsible agency.</SUBJECT>
            <SECTNO>51.163</SECTNO>
            <SUBJECT>Administrative procedures.</SUBJECT>
            <SECTNO>51.164</SECTNO>
            <SUBJECT>Stack height procedures.</SUBJECT>
            <SECTNO>51.165</SECTNO>
            <SUBJECT>Permit requirements.</SUBJECT>
            <SECTNO>51.166</SECTNO>
            <SUBJECT>Prevention of significant deterioration of air quality.</SUBJECT>
          </SUBPART>
          <SUBPART>
            <HD SOURCE="HED">Subpart J—Ambient Air Quality Surveillance</HD>
            <SECTNO>51.190</SECTNO>
            <SUBJECT>Ambient air quality monitoring requirements.</SUBJECT>
          </SUBPART>
          <SUBPART>
            <HD SOURCE="HED">Subpart K—Source Survelliance</HD>
            <SECTNO>51.210</SECTNO>
            <SUBJECT>General.</SUBJECT>
            <SECTNO>51.211</SECTNO>
            <SUBJECT>Emission reports and recordkeeping.</SUBJECT>
            <SECTNO>51.212</SECTNO>
            <SUBJECT>Testing, inspection, enforcement, and complaints.</SUBJECT>
            <SECTNO>51.213</SECTNO>
            <SUBJECT>Transportation control measures.</SUBJECT>
            <SECTNO>51.214</SECTNO>
            <SUBJECT>Continuous emission monitoring.</SUBJECT>
          </SUBPART>
          <SUBPART>
            <HD SOURCE="HED">Subpart L—Legal Authority</HD>
            <SECTNO>51.230</SECTNO>
            <SUBJECT>Requirements for all plans.</SUBJECT>
            <SECTNO>51.231</SECTNO>
            <SUBJECT>Identification of legal authority.</SUBJECT>
            <SECTNO>51.232</SECTNO>
            <SUBJECT>Assignment of legal authority to local agencies.</SUBJECT>
          </SUBPART>
          <SUBPART>
            <HD SOURCE="HED">Subpart M—Intergovernmental Consultation</HD>
            <SUBJGRP>
              <HD SOURCE="HED">Agency Designation</HD>
              <SECTNO>51.240</SECTNO>
              <SUBJECT>General plan requirements.</SUBJECT>
              <SECTNO>51.241</SECTNO>
              <SUBJECT>Nonattainment areas for carbon monoxide and ozone.</SUBJECT>
              <SECTNO>51.242</SECTNO>
              <SUBJECT>[Reserved]</SUBJECT>
            </SUBJGRP>
          </SUBPART>
          <SUBPART>
            <HD SOURCE="HED">Subpart N—Compliance Schedules</HD>
            <SECTNO>51.260</SECTNO>
            <SUBJECT>Legally enforceable compliance schedules.</SUBJECT>
            <SECTNO>51.261</SECTNO>
            <SUBJECT>Final compliance schedules.</SUBJECT>
            <SECTNO>51.262</SECTNO>
            <SUBJECT>Extension beyond one year.</SUBJECT>
          </SUBPART>
          <SUBPART>
            <HD SOURCE="HED">Subpart O—Miscellaneous Plan Content Requirements</HD>
            <SECTNO>51.280</SECTNO>
            <SUBJECT>Resources.</SUBJECT>
            <SECTNO>51.281</SECTNO>
            <SUBJECT>Copies of rules and regulations.</SUBJECT>
            <SECTNO>51.285</SECTNO>
            <SUBJECT>Public notification.</SUBJECT>
            <SECTNO>51.286</SECTNO>
            <SUBJECT>Electronic reporting.</SUBJECT>
          </SUBPART>
          <SUBPART>
            <HD SOURCE="HED">Subpart P—Protection of Visibility</HD>
            <SECTNO>51.300</SECTNO>
            <SUBJECT>Purpose and applicability.</SUBJECT>
            <SECTNO>51.301</SECTNO>
            <SUBJECT>Definitions.</SUBJECT>
            <SECTNO>51.302</SECTNO>
            <SUBJECT>Implementation control strategies for reasonably attributable visibility impairment.</SUBJECT>
            <SECTNO>51.303</SECTNO>
            <SUBJECT>Exemptions from control.</SUBJECT>
            <SECTNO>51.304</SECTNO>
            <SUBJECT>Identification of integral vistas.</SUBJECT>
            <SECTNO>51.305</SECTNO>
            <SUBJECT>Monitoring for reasonably attributable visibility impairment.</SUBJECT>
            <SECTNO>51.306</SECTNO>
            <SUBJECT>Long-term strategy requirements for reasonably attributable visibility impairment.</SUBJECT>
            <SECTNO>51.307</SECTNO>
            <SUBJECT>New source review.</SUBJECT>
            <SECTNO>51.308</SECTNO>
            <SUBJECT>Regional haze program requirements.</SUBJECT>
            <SECTNO>51.309</SECTNO>
            <SUBJECT>Requirements related to the Grand Canyon Visibility Transport Commission.</SUBJECT>
          </SUBPART>
          <SUBPART>
            <HD SOURCE="HED">Subpart Q—Reports</HD>
            <SUBJGRP>
              <HD SOURCE="HED">Air Quality Data Reporting</HD>
              <SECTNO>51.320</SECTNO>
              <SUBJECT>Annual air quality data report.</SUBJECT>
            </SUBJGRP>
            <SUBJGRP>
              <HD SOURCE="HED">Source Emissions and State Action Reporting</HD>
              <SECTNO>51.321</SECTNO>
              <SUBJECT>Annual source emissions and State action report.</SUBJECT>
              <SECTNO>51.322</SECTNO>
              <SUBJECT>Sources subject to emissions reporting.</SUBJECT>
              <SECTNO>51.323</SECTNO>
              <SUBJECT>Reportable emissions data and information.</SUBJECT>
              <SECTNO>51.324</SECTNO>
              <SUBJECT>Progress in plan enforcement.</SUBJECT>
              <SECTNO>51.326</SECTNO>
              <SUBJECT>Reportable revisions.</SUBJECT>
              <SECTNO>51.327</SECTNO>
              <SUBJECT>Enforcement orders and other State actions.</SUBJECT>
              <SECTNO>51.328</SECTNO>
              <SUBJECT>[Reserved]</SUBJECT>
            </SUBJGRP>
          </SUBPART>
          <SUBPART>
            <HD SOURCE="HED">Subpart R—Extensions</HD>
            <SECTNO>51.341</SECTNO>
            <SUBJECT>Request for 18-month extension.</SUBJECT>
          </SUBPART>
          <SUBPART>
            <HD SOURCE="HED">Subpart S—Inspection/Maintenance Program Requirements</HD>
            <SECTNO>51.350</SECTNO>
            <SUBJECT>Applicability.</SUBJECT>
            <SECTNO>51.351</SECTNO>
            <SUBJECT>Enhanced I/M performance standard.</SUBJECT>
            <SECTNO>51.352</SECTNO>
            <SUBJECT>Basic I/M performance standard.</SUBJECT>
            <SECTNO>51.353</SECTNO>
            <SUBJECT>Network type and program evaluation.</SUBJECT>
            <SECTNO>51.354</SECTNO>
            <SUBJECT>Adequate tools and resources.</SUBJECT>
            <SECTNO>51.355</SECTNO>
            <SUBJECT>Test frequency and convenience.</SUBJECT>
            <SECTNO>51.356</SECTNO>
            <SUBJECT>Vehicle coverage.</SUBJECT>
            <SECTNO>51.357</SECTNO>
            <SUBJECT>Test procedures and standards.</SUBJECT>
            <SECTNO>51.358</SECTNO>
            <SUBJECT>Test equipment.</SUBJECT>
            <SECTNO>51.359</SECTNO>
            <SUBJECT>Quality control.</SUBJECT>
            <SECTNO>51.360</SECTNO>
            <SUBJECT>Waivers and compliance via diagnostic inspection.</SUBJECT>
            <SECTNO>51.361</SECTNO>
            <SUBJECT>Motorist compliance enforcement.</SUBJECT>
            <SECTNO>51.362</SECTNO>
            <SUBJECT>Motorist compliance enforcement program oversight.</SUBJECT>
            <SECTNO>51.363</SECTNO>
            <SUBJECT>Quality assurance.</SUBJECT>
            <SECTNO>51.364</SECTNO>
            <SUBJECT>Enforcement against contractors, stations and inspectors.</SUBJECT>
            <SECTNO>51.365</SECTNO>
            <SUBJECT>Data collection.</SUBJECT>
            <SECTNO>51.366</SECTNO>
            <SUBJECT>Data analysis and reporting.<PRTPAGE P="123"/>
            </SUBJECT>
            <SECTNO>51.367</SECTNO>
            <SUBJECT>Inspector training and licensing or certification.</SUBJECT>
            <SECTNO>51.368</SECTNO>
            <SUBJECT>Public information and consumer protection.</SUBJECT>
            <SECTNO>51.369</SECTNO>
            <SUBJECT>Improving repair effectiveness.</SUBJECT>
            <SECTNO>51.370</SECTNO>
            <SUBJECT>Compliance with recall notices.</SUBJECT>
            <SECTNO>51.371</SECTNO>
            <SUBJECT>On-road testing.</SUBJECT>
            <SECTNO>51.372</SECTNO>
            <SUBJECT>State Implementation Plan submissions.</SUBJECT>
            <SECTNO>51.373</SECTNO>
            <SUBJECT>Implementation deadlines.</SUBJECT>
            <APP>Appendix A to Subpart S—Calibrations, Adjustments and Quality Control</APP>
            <APP>Appendix B to Subpart S—Test Procedures</APP>
            <APP>Appendix C to Subpart S—Steady-State Short Test Standards</APP>
            <APP>Appendix D to Subpart S—Steady-State Short Test Equipment</APP>
            <APP>Appendix E to Subpart S—Transient Test Driving Cycle</APP>
          </SUBPART>
          <SUBPART>
            <HD SOURCE="HED">Subpart T—Conformity to State or Federal Implementation Plans of Transportation Plans, Programs, and Projects Developed, Funded or Approved Under Title 23 U.S.C. or the Federal Transit Laws</HD>
            <SECTNO>51.390</SECTNO>
            <SUBJECT>Implementation plan revision.</SUBJECT>
          </SUBPART>
          <SUBPART>
            <HD SOURCE="HED">Subpart U—Economic Incentive Programs</HD>
            <SECTNO>51.490</SECTNO>
            <SUBJECT>Applicability.</SUBJECT>
            <SECTNO>51.491</SECTNO>
            <SUBJECT>Definitions.</SUBJECT>
            <SECTNO>51.492</SECTNO>
            <SUBJECT>State program election and submittal.</SUBJECT>
            <SECTNO>51.493</SECTNO>
            <SUBJECT>State program requirements.</SUBJECT>
            <SECTNO>51.494</SECTNO>
            <SUBJECT>Use of program revenues.</SUBJECT>
          </SUBPART>
          <SUBPART>
            <HD SOURCE="HED">Subpart W—Determining Conformity of General Federal Actions to State or Federal Implementation Plans</HD>
            <SECTNO>51.850</SECTNO>
            <SUBJECT>Prohibition.</SUBJECT>
            <SECTNO>51.851</SECTNO>
            <SUBJECT>State Implementation Plan (SIP) revision.</SUBJECT>
            <SECTNO>51.852</SECTNO>
            <SUBJECT>Definitions.</SUBJECT>
            <SECTNO>51.853</SECTNO>
            <SUBJECT>Applicability.</SUBJECT>
            <SECTNO>51.854</SECTNO>
            <SUBJECT>Conformity analysis.</SUBJECT>
            <SECTNO>51.855</SECTNO>
            <SUBJECT>Reporting requirements.</SUBJECT>
            <SECTNO>51.856</SECTNO>
            <SUBJECT>Public participation.</SUBJECT>
            <SECTNO>51.857</SECTNO>
            <SUBJECT>Frequency of conformity determinations.</SUBJECT>
            <SECTNO>51.858</SECTNO>
            <SUBJECT>Criteria for determining conformity of general Federal actions.</SUBJECT>
            <SECTNO>51.859</SECTNO>
            <SUBJECT>Procedures for conformity determinations of general Federal actions.</SUBJECT>
            <SECTNO>51.860</SECTNO>
            <SUBJECT>Mitigation of air quality impacts.</SUBJECT>
          </SUBPART>
          <SUBPART>
            <HD SOURCE="HED">Subpart X—Provisions for Implementation of 8-hour Ozone National Ambient Air Quality Standard</HD>
            <SECTNO>51.900</SECTNO>
            <SUBJECT>Definitions.</SUBJECT>
            <SECTNO>51.901</SECTNO>
            <SUBJECT>Applicability of part 51.</SUBJECT>
            <SECTNO>51.902</SECTNO>
            <SUBJECT>Which classification and area planning provisions of the CAA shall apply to areas designated nonattainment for the 8-hour NAAQS?</SUBJECT>
            <SECTNO>51.903</SECTNO>
            <SUBJECT>How do the classification and attainment date provisions in section 181 of subpart 2 of the CAA apply to areas subject to § 51.902(a)?</SUBJECT>
            <SECTNO>51.904</SECTNO>
            <SUBJECT>How do the classification and attainment date provisions in section 172(a) of subpart 1 of the CAA apply to areas subject to § 51.902(b)?</SUBJECT>
            <SECTNO>51.905</SECTNO>
            <SUBJECT>How do areas transition from the 1-hour NAAQS to the 8-hour NAAQS and what are the anti-backsliding provisions?</SUBJECT>
            <SECTNO>51.906</SECTNO>
            <SUBJECT>Redesignation to nonattainment following initial designations for the 8-hour NAAQS.</SUBJECT>
            <SECTNO>51.907</SECTNO>
            <SUBJECT>For an area that fails to attain the 8-hour NAAQS by its attainment date, how does EPA interpret sections 172(a)(2)(C)(ii) and 181(a)(5)(B) of the CAA?</SUBJECT>
            <SECTNO>51.908</SECTNO>
            <SUBJECT>What modeling and attainment demonstration requirements apply for purposes of the 8-hour ozone NAAQS?</SUBJECT>
            <SECTNO>51.909</SECTNO>
            <SUBJECT>[Reserved]</SUBJECT>
            <SECTNO>51.910</SECTNO>
            <SUBJECT>What requirements for reasonable further progress (RFP) under sections 172(c)(2) and 182 apply for areas designated nonattainment for the 8-hour ozone NAAQS?</SUBJECT>
            <SECTNO>51.911</SECTNO>
            <SUBJECT>[Reserved]</SUBJECT>
            <SECTNO>51.912</SECTNO>
            <SUBJECT>What requirements apply for reasonably available control technology (RACT) and reasonably available control measures (RACM) under the 8-hour NAAQS?</SUBJECT>
            <SECTNO>51.913</SECTNO>
            <SUBJECT>How do the section 182(f) NO<E T="52">X</E> exemption provisions apply for the 8-hour NAAQS?</SUBJECT>
            <SECTNO>51.914</SECTNO>
            <SUBJECT>What new source review requirements apply for 8-hour ozone nonattainment areas?</SUBJECT>
            <SECTNO>51.915</SECTNO>
            <SUBJECT>What emissions inventory requirements apply under the 8-hour NAAQS?</SUBJECT>
            <SECTNO>51.916</SECTNO>
            <SUBJECT>What are the requirements for an Ozone Transport Region under the 8-hour NAAQS?</SUBJECT>
            <SECTNO>51.917</SECTNO>
            <SUBJECT>What is the effective date of designation for the Las Vegas, NV, 8-hour ozone nonattainment area?</SUBJECT>
            <SECTNO>51.918</SECTNO>
            <SUBJECT>Can any SIP planning requirements be suspended in 8-hour ozone nonattainment areas that have air quality data that meets the NAAQS?</SUBJECT>
            <APP>Appendixes A-K to Part 51 [Reserved]</APP>
            <APP>Appendix L to Part 51—Example Regulations for Prevention of Air Pollution Emergency Episodes</APP>
            <APP>Appendix M to Part 51—Recommended Test Methods for State Implementation Plans</APP>
            <APP>Appendixes N-O to Part 51 [Reserved]</APP>
            <APP>Appendix P to Part 51—Minimum Emission Monitoring Requirements</APP>
            <APP>Appendixes Q-R to Part 51 [Reserved]</APP>

            <APP>Appendix S to Part 51—Emission Offset Interpretative Ruling<PRTPAGE P="124"/>
            </APP>
            <APP>Appendixes T-U to Part 51 [Reserved]</APP>
            <APP>Appendix V to Part 51—Criteria for Determining the Completeness of Plan Submissions</APP>
            <APP>Appendix W to Part 51—Guideline on Air Quality Models</APP>
            <APP>Appendix X to Part 51—Examples of Economic Incentive Programs</APP>
            <APP>Appendix Y to Part 51—Guidelines for BART Determinations Under the Regional Haze Rule</APP>
          </SUBPART>
        </CONTENTS>
        <AUTH>
          <HD SOURCE="HED">Authority:</HD>
          <P>23 U.S.C. 101; 42 U.S.C. 7401-7671q.</P>
        </AUTH>
        <SOURCE>
          <HD SOURCE="HED">Source:</HD>
          <P>36 FR 22398, Nov. 25, 1971, unless otherwise noted.</P>
        </SOURCE>
        <SUBPART>
          <HD SOURCE="HED">Subpart A—Emission Inventory Reporting Requirements</HD>
          <SOURCE>
            <HD SOURCE="HED">Source:</HD>
            <P>67 FR 39611, June 10, 2002, unless otherwise noted.</P>
          </SOURCE>
          <SUBJGRP>
            <HD SOURCE="HED">General Information for Inventory Preparers</HD>
            <SECTION>
              <SECTNO>§ 51.1</SECTNO>
              <SUBJECT>Who is responsible for actions described in this subpart?</SUBJECT>
              <P>State agencies whose geographic coverage include any point, area, mobile, or biogenic sources must inventory these sources and report this information to EPA.</P>
            </SECTION>
            <SECTION>
              <SECTNO>§ 51.5</SECTNO>
              <SUBJECT>What tools are available to help prepare and report emissions data?</SUBJECT>
              <P>We urge your State to use estimation procedures described in documents from the Emission Inventory Improvement Program (EIIP). These procedures are standardized and ranked according to relative uncertainty for each emission estimating technique. Using this guidance will enable others to use your State's data and evaluate its quality and consistency with other data.</P>
            </SECTION>
            <SECTION>
              <SECTNO>§ 51.10</SECTNO>

              <SUBJECT>How does my State report emissions that are required by the NO<E T="52">X</E> SIP Call?</SUBJECT>

              <P>The States and the District of Columbia that are subject to the NO<E T="52">X</E> SIP Call (§ 51.121) should report their emissions under the provisions of § 51.122. To avoid confusion, these requirements are not repeated here.</P>
            </SECTION>
          </SUBJGRP>
          <SUBJGRP>
            <HD SOURCE="HED">Specific Reporting Requirements</HD>
            <SECTION>
              <SECTNO>§ 51.15</SECTNO>
              <SUBJECT>What data does my State need to report to EPA?</SUBJECT>
              <P>(a) <E T="03">Pollutants.</E> Report actual emissions of the following (see Glossary to Appendix A to this subpart for precise definitions as required):</P>
              <P>(1) Required Pollutants:</P>
              <P>(i) Sulfur oxides.</P>
              <P>(ii) VOC.</P>
              <P>(iii) Nitrogen oxides.</P>
              <P>(iv) Carbon monoxide.</P>
              <P>(v) Lead and lead compounds.</P>
              <P>(vi) Primary PM<E T="52">2.5</E>.</P>
              <P>(vii) Primary PM<E T="52">10</E>.</P>
              <P>(viii) NH<E T="52">3</E>.</P>
              <P>(2) Optional Pollutant:</P>
              <P>(i) Primary PM.</P>
              <P>(ii) [Reserved]</P>
              <P>(b) <E T="03">Sources.</E> Emissions should be reported from the following sources:</P>
              <P>(1) Point.</P>
              <P>(2) Area.</P>
              <P>(3) Onroad mobile.</P>
              <P>(4) Nonroad mobile.</P>
              <P>(5) Biogenic.</P>
              <P>(c) <E T="03">Supporting information.</E> Report the data elements in Tables 2a through 2d of Appendix A to this subpart. Depending on the format you choose to report your State data, additional information not listed in Tables 2a through 2d will be required. We may ask you for other data on a voluntary basis to meet special purposes.</P>
              <P>(d) <E T="03">Confidential data.</E> We don't consider the data in Tables 2a through 2d of Appendix A to this subpart confidential, but some States limit release of this type of data. Any data that you submit to EPA under this rule will be considered in the public domain and cannot be treated as confidential. If Federal and State requirements are inconsistent, consult your EPA Regional Office for a final reconciliation.</P>
            </SECTION>
            <SECTION>
              <SECTNO>§ 51.20</SECTNO>
              <SUBJECT>What are the emission thresholds that separate point and area sources?</SUBJECT>
              <P>(a) All anthropogenic stationary sources must be included in your inventory as either point or area sources.</P>
              <P>(b) See Table 1 of Appendix A to this subpart for minimum reporting thresholds on point sources.</P>

              <P>(c) Your State has two alternatives to the point source reporting thresholds in paragraph (b) of this section:<PRTPAGE P="125"/>
              </P>
              <P>(1) You may choose to define point sources by the definition of a major source used under CAA Title V, see 40 CFR 70.2.</P>
              <P>(2) If your State has lower emission reporting thresholds for point sources than paragraph (b) of this section, then you may use these in reporting your emissions to EPA.</P>
              <P>(d) All stationary sources that have actual emissions lower than the thresholds specified in paragraphs (b) and (c) of this section, should be reported as area sources.</P>
            </SECTION>
            <SECTION>
              <SECTNO>§ 51.25</SECTNO>
              <SUBJECT>What geographic area must my State's inventory cover?</SUBJECT>
              <P>Because of the regional nature of these pollutants, your State's inventory must be statewide, regardless of an area's attainment status.</P>
            </SECTION>
            <SECTION>
              <SECTNO>§ 51.30</SECTNO>
              <SUBJECT>When does my State report the data to EPA?</SUBJECT>
              <P>Your State is required to report two basic types of emission inventories to us: Annual Cycle Inventory; and Three-year Cycle Inventory.</P>
              <P>(a) <E T="03">Annual cycle.</E> You are required to report annually data from Type A (large) point sources. Except as provided in paragraph (e) of this section, the first annual cycle inventory will be for the year 2001 and must be submitted to us within 17 months, i.e., by June 1, 2003. Subsequent annual cycle inventories will be due 17 months following the end of the reporting year. See Table 2a of Appendix A to this subpart for the specific data elements to report annually.</P>
              <P>(b) <E T="03">Three-year cycle.</E> You are required to report triennially, data for Type B (all) point sources, area sources and mobile sources. Except as provided in paragraph (e) of this section, the first three-year cycle inventory will be for the year 2002 and must be submitted to us within 17 months, i.e., by June 1, 2004. Subsequent three-year cycle inventories will be due 17 months following the end of the reporting year. See Tables 2a, 2b and 2c of Appendix A to this subpart for the specific data elements that must be reported triennially.</P>
              <P>(c) NO<E T="52">X</E> SIP call. There are specific annual and three-year reporting requirements for States subject to the NO<E T="52">X</E> SIP call. See § 51.122 for these requirements.</P>
              <P>(d) <E T="03">Biogenic emissions.</E> Biogenic emissions are part of your 3-year cycle inventory. Your State must establish an initial baseline for biogenic emissions that is due as specified under paragraph (b) of this section. Your State need not submit more biogenic data unless land use characteristics or the methods for estimating emissions change substantially. If either of these changes, your State must report the biogenic emission data elements shown in Table 2d of Appendix A to this subpart. Report these data elements 17 months after the end of the reporting year.</P>
              <P>(e) <E T="03">Point Sources.</E> States must commence reporting point source emissions of PM<E T="52">2.5</E> and NH<E T="52">3</E> on June 1, 2004 unless that date is less than 60 days after EPA publishes an approved Information Collection Request (ICR) addressing this section of the rule. If EPA fails to publish an approved ICR 60 days in advance of June 1, 2004, States must commence reporting point source emissions of PM<E T="52">2.5</E> and NH<E T="52">3</E> on the next annual or triennial reporting date (as appropriate) that is at least 60 days after EPA publishes an approved ICR addressing this section.</P>
            </SECTION>
            <SECTION>
              <SECTNO>§ 51.35</SECTNO>
              <SUBJECT>How can my State equalize the effort for annual reporting?</SUBJECT>
              <P>(a) Compiling a 3-year cycle inventory means much more effort every three years. As an option, your State may ease this workload spike by using the following approach:</P>
              <P>(1) Annually collect and report data for all Type A (large) point sources (This is required for all Type A point sources).</P>

              <P>(2) Annually collect data for one-third of your smaller point sources (Type B point sources minus Type A (large) point sources). Collect data for a different third of these sources each year so that data has been collected for all of the smaller point sources by the end of each three-year cycle. You may report these data to EPA annually, or as an option you may save three years of data and then report all of the smaller point sources on the three-year cycle due date.<PRTPAGE P="126"/>
              </P>
              <P>(3) Annually collect data for one-third of the area, nonroad mobile, onroad mobile and, if required, biogenic sources. You may report these data to EPA annually, or as an option you may save three years of data and then report all of these data on the three-year cycle due date.</P>
              <P>(b) For the sources described in paragraph (a) of this section, your State will therefore have data from three successive years at any given time, rather than from the single year in which it is compiled.</P>
              <P>(c) If your State chooses the method of inventorying one-third of your smaller point sources and 3-year cycle area, nonroad mobile, onroad mobile sources each year, your State must compile each year of the three-year period identically. For example, if a process hasn't changed for a source category or individual plant, your State must use the same emission factors to calculate emissions for each year of the three-year period. If your State has revised emission factors during the three years for a process that hasn't changed, resubmit previous year's data using the revised factor. If your State uses models to estimate emissions, you must make sure that the model is the same for all three years.</P>
              <P>(d) If your State chooses the method of inventorying one-third of your smaller point sources and 3-year cycle area, nonroad mobile, onroad mobile sources each year and reporting them on the 3-year cycle due date, the first required date for you to report on all such sources will be June 1, 2004 as specified in § 51.25. You can satisfy the 2004 reporting requirement by either: Starting to inventory one third of your sources in 2000; or doing a one-time complete 3-year cycle inventory for 2002, then changing to the option of inventorying one third of your sources for subsequent years.</P>
              <P>(e) If your State needs a new reference year emission inventory for a selected pollutant, your State can't use these optional reporting frequencies for the new reference year.</P>
              <P>(f) If your State is a NO<E T="52">X</E> SIP call State, you can't use these optional reporting frequencies for NO<E T="52">X</E> SIP call reporting.</P>
            </SECTION>
            <SECTION>
              <SECTNO>§ 51.40</SECTNO>
              <SUBJECT>In what form should my State report the data to EPA?</SUBJECT>

              <P>You must report your emission inventory data to us in electronic form. We support specific electronic data reporting formats and you are required to report your data in a format consistent with these. Because electronic reporting technology continually changes, contact the Emission Factor and Inventory Group (EFIG) for the latest specific formats. You can find information on the current formats at the following Internet address: <E T="03">http://www.epa.gov/ttn/chief.</E> You may also call our Info CHIEF help desk at (919) 541-1000 or email to <E T="03">info.chief@epa.gov.</E>
              </P>
            </SECTION>
            <SECTION>
              <SECTNO>§ 51.45</SECTNO>
              <SUBJECT>Where should my State report the data?</SUBJECT>
              <P>(a) Your State submits or reports data by providing it directly to EPA.</P>

              <P>(b) The latest information on data reporting procedures is available at the following Internet address: <E T="03">http://www.epa.gov/ttn/chief.</E>
              </P>

              <P>You may also call our Info CHIEF help desk at (919)541-1000 or email to <E T="03">info.chief@epa.gov.</E>
              </P>
            </SECTION>
          </SUBJGRP>
          <APPENDIX>
            <EAR>Pt. 51, Subpt. A, App. A</EAR>
            <HD SOURCE="HED">Appendix A to Subpart A of Part 51—Tables and Glossary</HD>
            <GPOTABLE CDEF="s25,16,16,xs84" COLS="4" OPTS="L2">

              <TTITLE>Table 1—Minimum Point Source Reporting Thresholds by Pollutant(<E T="01">tpy</E>
                <SU>1</SU>)</TTITLE>
              <BOXHD>
                <CHED H="1">Pollutant</CHED>
                <CHED H="1">Annual cycle<LI>(type A sources)</LI>
                </CHED>
                <CHED H="1">Three-year cycle</CHED>
                <CHED H="2">Type B sources <SU>2</SU>
                </CHED>
                <CHED H="2">NAA <SU>3</SU>
                </CHED>
              </BOXHD>
              <ROW>
                <ENT I="01">1. SO<E T="52">X</E>
                </ENT>
                <ENT>≥2500</ENT>
                <ENT>≥100</ENT>
                <ENT>≥100</ENT>
              </ROW>
              <ROW>
                <ENT I="01">2. VOC</ENT>
                <ENT>≥250</ENT>
                <ENT>≥100</ENT>
                <ENT>0<E T="52">3</E> (moderate)≥100</ENT>
              </ROW>
              <ROW>
                <ENT I="01">3. VOC</ENT>
                <ENT/>
                <ENT/>
                <ENT>O<E T="52">3</E> (serious)≥50</ENT>
              </ROW>
              <ROW>
                <ENT I="01">4. VOC</ENT>
                <ENT/>
                <ENT/>
                <ENT>O<E T="52">3</E> (severe)≥25</ENT>
              </ROW>
              <ROW>
                <ENT I="01">5. VOC</ENT>
                <ENT/>
                <ENT/>
                <ENT>O<E T="52">3</E> (extreme)≥10</ENT>
              </ROW>
              <ROW>
                <ENT I="01">6. NO<E T="52">X</E>
                </ENT>
                <ENT>≥2500</ENT>
                <ENT>≥100</ENT>
                <ENT>≥100</ENT>
              </ROW>
              <ROW>
                <ENT I="01">7. CO</ENT>
                <ENT>≥2500</ENT>
                <ENT>≥1000</ENT>
                <ENT>O<E T="52">3</E> (all areas)≥100</ENT>
              </ROW>
              <ROW>
                <ENT I="01">8. CO</ENT>
                <ENT/>
                <ENT/>
                <ENT>CO (all areas)≥100</ENT>
              </ROW>
              <ROW>
                <PRTPAGE P="127"/>
                <ENT I="01">9. Pb</ENT>
                <ENT/>
                <ENT>≥5</ENT>
                <ENT>≥5</ENT>
              </ROW>
              <ROW>
                <ENT I="01">10. PM<E T="52">10</E>
                </ENT>
                <ENT>≥250</ENT>
                <ENT>≥100</ENT>
                <ENT>PM10<E T="52">10</E> (moderate)≥100</ENT>
              </ROW>
              <ROW>
                <ENT I="01">11. PM<E T="52">10</E>
                </ENT>
                <ENT/>
                <ENT/>
                <ENT>PM<E T="52">10</E> (serious)≥70</ENT>
              </ROW>
              <ROW>
                <ENT I="01">12. PM<E T="52">2.5</E>
                </ENT>
                <ENT>≥250</ENT>
                <ENT>≥100</ENT>
                <ENT>≥100</ENT>
              </ROW>
              <ROW>
                <ENT I="01">13. NH<E T="52">3</E>
                </ENT>
                <ENT>≥250</ENT>
                <ENT>≥100</ENT>
                <ENT>≥100</ENT>
              </ROW>
              <TNOTE>
                <SU>1</SU> tpy = tons per year of actual emissions.</TNOTE>
              <TNOTE>
                <SU>2</SU> Type A sources are a subset of the Type B sources and are the larger emitting sources by pollutant.</TNOTE>
              <TNOTE>

                <SU>3</SU> NAA = Nonattainment Area. Special point source reporting thresholds apply for certain pollutants by type of nonattainment area. The pollutants by nonattainment area are: Ozone: VOC, NO<E T="52">X</E>, CO; CO: CO; PM<E T="52">10</E>: PM<E T="52">10</E>.</TNOTE>
            </GPOTABLE>
            <GPOTABLE CDEF="s75,15C,15C" COLS="3" OPTS="L2">
              <TTITLE>Table 2a—Data Elements That States Must Report for Point Sources</TTITLE>
              <BOXHD>
                <CHED H="1">Data elements</CHED>
                <CHED H="1">Annual (Type A sources)</CHED>
                <CHED H="1">Every 3 years (Type B sources and NAAs)</CHED>
              </BOXHD>
              <ROW>
                <ENT I="01">1. Inventory year</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">2. Inventory start date</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">3. Inventory end date</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">4. Inventory type</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">5. State FIPS code</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">6. County FIPS code</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">7. Facility ID code</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">8. Point ID code</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">9. Process ID code</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">10. Stack ID code</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">11. Site name</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">12. Physical address</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">13. SCC or PCC</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">14. Heat content (fuel) (annual average)</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">15. Ash content (fuel) (annual average)</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">16. Sulfur content (fuel) (annual average)</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">17. Pollutant code</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">18. Activity/throughput (annual)</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">19. Activity/throughput (daily)</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">20. Work weekday emissions</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">21. Annual emissions</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">22. Emission factor</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">23. Winter throughput (%)</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">24. Spring throughput (%)</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">25. Summer throughput (%)</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">26. Fall throughput (%)</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">27. Hr/day in operation</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">28. Start time (hour)</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">29. Day/wk in operation</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">30. Wk/yr in operation</ENT>
                <ENT>✔</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">31. X stack coordinate (latitude)</ENT>
                <ENT/>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">32. Y stack coordinate (longitude)</ENT>
                <ENT/>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">33. Stack Height</ENT>
                <ENT/>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">34. Stack diameter</ENT>
                <ENT/>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">35. Exit gas temperature</ENT>
                <ENT/>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">36. Exit gas velocity</ENT>
                <ENT/>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">37. Exit gas flow rate</ENT>
                <ENT/>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">38. SIC/NAICS</ENT>
                <ENT/>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">39. Design capacity</ENT>
                <ENT/>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">40. Maximum namemplate capacity</ENT>
                <ENT/>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">41. Primary control eff (%)</ENT>
                <ENT/>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">42. Secondary control eff (%)</ENT>
                <ENT/>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">43. Control device type</ENT>
                <ENT/>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">44. Rule effectiveness (%)</ENT>
                <ENT/>
                <ENT>✔</ENT>
              </ROW>
            </GPOTABLE>
            <PRTPAGE P="128"/>
            <GPOTABLE CDEF="s50,10C" COLS="2" OPTS="L2">
              <TTITLE>Table 2b—Data Elements that States Must Report for Area and Nonroad Mobile Sources</TTITLE>
              <BOXHD>
                <CHED H="1">Data elements</CHED>
                <CHED H="1">Every 3 years</CHED>
              </BOXHD>
              <ROW>
                <ENT I="01">1. Inventory year</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">2. Inventory start date</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">3. Inventory end date</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">4. Inventory type</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">5. State FIPS code</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">6. County FIPS code</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">7. SCC or PCC</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">8. Emission factor</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">9. Activity/throughput level (annual)</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">10. Total capture/control efficiency (%)</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">11. Rule effectiveness (%)</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">12. Rule penetration (%)</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">13. Pollutant code</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">14. Summer/winter work weekday emissions</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">15. Annual emissions</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">16. Winter throughput (%)</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">17. Spring throughput (%)</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">18. Summer throughput (%)</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">19. Fall throughput (%)</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">20. Hrs/day in operation</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">21. Days/wk in operation</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">22. Wks/yr in operation</ENT>
                <ENT>✔</ENT>
              </ROW>
            </GPOTABLE>
            <GPOTABLE CDEF="s50,10C" COLS="2" OPTS="L2">
              <TTITLE>Table 2c—Data Elements that States Must Report for Onroad Mobile Sources</TTITLE>
              <BOXHD>
                <CHED H="1">Data elements</CHED>
                <CHED H="1">Every 3 years</CHED>
              </BOXHD>
              <ROW>
                <ENT I="01">1. Inventory year</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">2. Inventory start date</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">3. Inventory end date</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">4. Inventory type</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">5. State FIPS code</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">6. County FIPS code</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">7. SCC or PCC</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">8. Emission factor</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">9. Activity (VMT by Roadway Class)</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">10. Pollutant code</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">11. Summer/winter work weekday emissions</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">12. Annual emissions</ENT>
                <ENT>✔</ENT>
              </ROW>
            </GPOTABLE>
            <GPOTABLE CDEF="s50,10C" COLS="2" OPTS="L2">
              <TTITLE>Table 2d—Data Elements that States Must Report for Biogenic Sources</TTITLE>
              <BOXHD>
                <CHED H="1">Data elements</CHED>
                <CHED H="1">Every 3 years</CHED>
              </BOXHD>
              <ROW>
                <ENT I="01">1. Inventory year</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">2. Inventory start date</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">3. Inventory end date</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">4. Inventory type</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">5. State FIPS code</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">6. County FIPS code</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">7. SCC or PCC</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">8. Pollutant code</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">9. Summer/winter work weekday emissions</ENT>
                <ENT>✔</ENT>
              </ROW>
              <ROW>
                <ENT I="01">10. Annual emissions</ENT>
                <ENT>✔</ENT>
              </ROW>
            </GPOTABLE>
            <HD SOURCE="HD1">Glossary</HD>
            <P>Activity rate/throughput (annual)—A measurable factor or parameter that relates directly or indirectly to the emissions of an air pollution source. Depending on the type of source category, activity information may refer to the amount of fuel combusted, raw material processed, product manufactured, or material handled or processed. It may also refer to population, employment, number of units, or miles traveled. Activity information is typically the value that is multiplied against an emission factor to generate an emissions estimate.</P>
            <P>Activity rate/throughput (daily)—The beginning and ending dates and times that define the emissions period used to estimate the daily activity rate/throughput.</P>
            <P>Annual emissions—Actual emissions for a plant, point, or process—measured or calculated that represent a calendar year.</P>
            <P>Area sources—Area sources collectively represent individual sources that have not been inventoried as specific point, mobile, or biogenic sources. These individual sources treated collectively as area sources are typically too small, numerous, or difficult to inventory using the methods for the other classes of sources.</P>
            <P>Ash content—Inert residual portion of a fuel.</P>
            <P>Biogenic sources—Biogenic emissions are all pollutants emitted from non-anthropogenic sources. Example sources include trees and vegetation, oil and gas seeps, and microbial activity.</P>
            <P>Control device type—The name of the type of control device (e.g., wet scrubber, flaring, or process change).</P>
            <P>County FIPS Code—Federal Information Placement System (FIPS) is the system of unique numeric codes the government developed to identify States, counties and parishes for the entire United States, Puerto Rico, and Guam.</P>
            <P>Day/wk in operations—Days per week that the emitting process operates—average over the inventory period.</P>
            <P>Design capacity—A measure of the size of a point source, based on the reported maximum continuous capacity of the unit.</P>
            <P>Emission factor—Ratio relating emissions of a specific pollutant to an activity or material throughput level.</P>
            <P>Exit gas flow rate—Numeric value of stack gas's flow rate.</P>
            <P>Exit gas temperature—Numeric value of an exit gas stream's temperature.</P>
            <P>Exit gas velocity—Numeric value of an exit gas stream's velocity.</P>
            <P>Facility ID code—Unique code for a plant or facility, containing one or more pollutant-emitting sources. This is the data element in Appendix A, Table 2a, that is defined elsewhere in this glossary as a “point source”.</P>

            <P>Fall throughput(%)—Part of the throughput for the three Fall months (September, October, November). This expresses part of the annual activity information based on four seasons—typically spring, summer, fall, and winter. It can be a percentage of the annual activity (<E T="03">e.g.,</E> production in summer is <PRTPAGE P="129"/>40% of the year's production) or units of the activity (<E T="03">e.g.,</E> out of 600 units produced, spring = 150 units, summer = 250 units, fall = 150 units, and winter = 50 units).</P>
            <P>Heat content—The amount of thermal heat energy in a solid, liquid, or gaseous fuel. Fuel heat content is typically expressed in units of Btu/lb of fuel, Btu/gal of fuel, joules/kg of fuel, etc.</P>
            <P>Hr/day in operations—Hours per day that the emitting process operates—average over the inventory period.</P>
            <P>Inventory end date—Last day of the inventory period.</P>
            <P>Inventory start date—First day of the inventory period.</P>
            <P>Inventory type—Type of inventory represented by data (<E T="03">i.e.,</E> point, 3-year cycle, daily).</P>
            <P>Inventory year—The calendar year for which you calculated emissions estimates.</P>
            <P>Lead (Pb)—As defined in 40 CFR 50.12, lead should be reported as elemental lead and its compounds.</P>
            <P>Maximum nameplate capacity—A measure of a unit's size that the manufacturer puts on the unit's nameplate.</P>
            <P>Mobile source—A motor vehicle, nonroad engine or nonroad vehicle.</P>
            <P>• A “motor vehicle” is any self-propelled vehicle used to carry people or property on a street or highway.</P>
            <P>• A “nonroad engine” is an internal combustion engine (including fuel system) that is not used in a motor vehicle or vehicle only used for competition, or that is not affected by sections 111 or 202 of the CAA.</P>
            <P>• A “nonroad vehicle” is a vehicle that is run by a nonroad engine and that is not a motor vehicle or a vehicle only used for competition.</P>
            <P>PM (Particulate Matter)—Particulate matter is a criteria air pollutant. For the purpose of this subpart, the following definitions apply:</P>
            <P>(1) <E T="03">Primary PM:</E> Particles that enter the atmosphere as a direct emission from a stack or an open source. It is comprised of two components: Filterable PM and Condensible PM. (As specified in § 51.15 (a)(2), these two PM components are the components measured by a stack sampling train such as EPA Method 5 and have no upper particle size limit.)</P>
            <P>(2) <E T="03">Filterable PM:</E> Particles that are directly emitted by a source as a solid or liquid at stack or release conditions and captured on the filter of a stack test train.</P>
            <P>(3) <E T="03">Condensible PM:</E> Material that is vapor phase at stack conditions, but which condenses and/or reacts upon cooling and dilution in the ambient air to form solid or liquid PM immediately after discharge from the stack.</P>
            <P>(4) <E T="03">Secondary PM:</E> Particles that form through chemical reactions in the ambient air well after dilution and condensation have occurred. Secondary PM is usually formed at some distance downwind from the source. Secondary PM should NOT be reported in the emission inventory and is NOT covered by this subpart.</P>
            <P>(5) <E T="03">Primary PM</E>
              <E T="52">2.5</E>: Also PM<E T="52">2.5</E> (or Filterable PM<E T="52">2.5</E> and Condensible PM individually. Note that all Condensible PM is assumed to be in the PM<E T="52">2.5</E> size fraction)—Particulate matter with an aerodynamic diameter equal to or less than 2.5 micrometers.</P>
            <P>(6) <E T="03">Primary PM</E>
              <E T="52">10</E>: Also PM<E T="52">10</E> (or Filterable PM<E T="52">10</E> and Condensible PM individually)—Particulate matter with an aerodynamic diameter equal to or less than 10 micrometers.</P>
            <P>PCC—Process classification code. A process-level code that describes the equipment or operation which is emitting pollutants. This code is being considered as a replacement for the SCC.</P>
            <P>Physical address—Street address of a facility. This is the address of the location where the emissions occur; not, for example, the corporate headquarters.</P>
            <P>Point ID code—Unique code for the point of generation of emissions, typically a physical piece of equipment.</P>
            <P>Point source—Point sources are large, stationary (non-mobile), identifiable sources of emissions that release pollutants into the atmosphere. As used in this rule, a point source is defined as a facility that annually emits more than a “threshold” value as defined under § 51.20.</P>
            <P>Pollutant code—A unique code for each reported pollutant assigned in the Emission Inventory Improvement Program (EIIP) Data Model. The EIIP model was developed to promote consistency in organizations sharing emissions data. The model uses character names for criteria pollutants and Chemical Abstracts Service (CAS) numbers for all other pollutants. You may be using SAROAD codes for pollutants, but you should be able to map them to the pollutant codes in the EIIP Data Model.</P>
            <P>Process ID code—Unique code for the process generating the emissions, typically a description of a process.</P>
            <P>Roadway class—A classification system developed by the Federal Highway Administration that defines all public roadways as to type. Currently there are four roadway types: (1) Freeway, (2) freeway ramp, (3) arterial/collector and (4) local.</P>
            <P>Rule effectiveness (RE)—How well a regulatory program achieves all possible emission reductions. This rating reflects the assumption that controls typically aren't 100 percent effective because of equipment downtime, upsets, decreases in control efficiencies, and other deficiencies in emission estimates. RE adjusts the control efficiency.</P>

            <P>Rule penetration—The percentage of an area source category covered by an applicable regulation.<PRTPAGE P="130"/>
            </P>
            <P>SCC—Source classification code. A process-level code that describes the equipment and/or operation which is emitting pollutants.</P>
            <P>Seasonal activity rate/throughput—A measurable factor or parameter that relates directly or indirectly to the pollutant season emissions of an air pollution source. Depending on the type of source category, activity information may refer to the amount of fuel combusted, raw material processed, product manufactured, or material handled or processed. It may also refer to population, employment, number of units, or miles traveled. Activity information is typically the value that is multiplied against an emission factor to generate an emissions estimate.</P>
            <P>Seasonal fuel heat content—The amount of thermal heat energy in a solid, liquid, or gaseous fuel used during the pollutant season. Fuel heat content is typically expressed in units of Btu/lb of fuel, Btu/gal of fuel, joules/kg of fuel, etc.</P>
            <P>Secondary control eff (%)—The emission reduction efficiency of a secondary control device. Control efficiency is usually expressed as a percentage or in tenths.</P>
            <P>SIC/NAICS—Standard Industrial Classification code. NAICS (North American Industry Classification System) codes will replace SIC codes. U.S. Department of Commerce's code for businesses by products or services.</P>
            <P>Site name—The name of the facility.</P>
            <P>Spring throughput (%)—Part of throughput or activity for the three spring months (March, April, May). See the definition of Fall Throughput.</P>
            <P>Stack diameter—A stack's inner physical diameter.</P>
            <P>Stack height—A stack's physical height above the surrounding terrain.</P>
            <P>Stack ID code—Unique code for the point where emissions from one or more processes release into the atmosphere.</P>
            <P>Start time (hour)—Start time (if available) that you used to calculate the emissions estimates.</P>
            <P>State FIPS Code—Federal Information Placement System (FIPS) is the system of unique numeric codes the government developed to identify States, counties and parishes for the entire United States, Puerto Rico, and Guam.</P>
            <P>Sulfur content—Sulfur content of a fuel, usually expressed as percent by weight.</P>
            <P>Summer throughput(%)—Part of throughput or activity for the three summer months (June, July, August). See the definition of Fall Throughput.</P>
            <P>Summer/winter work weekday emissions—Average day's emissions for a typical day. Ozone daily emissions = summer work weekday; CO and PM daily emissions = winter work weekday.</P>
            <P>Total capture/control efficiency—The emission reduction efficiency of a primary control device, which shows the amount controls or material changes reduce a particular pollutant from a process' emissions. Control efficiency is usually expressed as a percentage or in tenths.</P>
            <P>Type A source—Large point sources with actual annual emissions greater than or equal to any of the emission thresholds listed in Table 1 for Type A sources.</P>
            <P>Type B source—Point sources with actual annual emissions during any year of the three year cycle greater than or equal to any of the emission thresholds listed in Table 1 for Type B sources. Type B sources include all Type A sources.</P>
            <P>VMT by Roadway Class—Vehicle miles traveled (VMT) expresses vehicle activity and is used with emission factors. The emission factors are usually expressed in terms of grams per mile of travel. Because VMT doesn't correlate directly to emissions that occur while the vehicle isn't moving, these nonmoving emissions are incorporated into the emission factors in EPA's MOBILE Model.</P>
            <P>VOC—Volatile Organic Compounds. The EPA's regulatory definition of VOC is in 40 CFR 51.100.</P>
            <P>Winter throughput (%)—Part of throughput or activity for the three winter months (December, January, February, all from the same year, e.g., Winter 2000 = January 2000 + February, 2000 + December 2000). See the definition of Fall Throughput.</P>
            <P>Wk/yr in operation—Weeks per year that the emitting process operates.</P>
            <P>Work Weekday—Any day of the week except Saturday or Sunday.</P>
            <P>X stack coordinate (latitude)—An object's north-south geographical coordinate. Y stack coordinate (longitude)—An object's east-west geographical coordinate.</P>
          </APPENDIX>
          <APPENDIX>
            <RESERVED>Appendix B to Subpart A of Part 51 [Reserved]</RESERVED>
          </APPENDIX>
        </SUBPART>
        <SUBPART>
          <RESERVED>Subparts B-E [Reserved]</RESERVED>
        </SUBPART>
        <SUBPART>
          <HD SOURCE="HED">Subpart F—Procedural Requirements</HD>
          <AUTH>
            <HD SOURCE="HED">Authority:</HD>
            <P>42 U.S.C. 7401, 7411, 7412, 7413, 7414, 7470-7479, 7501-7508, 7601, and 7602.</P>
          </AUTH>
          <SECTION>
            <SECTNO>§ 51.100</SECTNO>
            <SUBJECT>Definitions.</SUBJECT>
            <P>As used in this part, all terms not defined herein will have the meaning given them in the Act:</P>
            <P>(a) <E T="03">Act</E> means the Clean Air Act (42 U.S.C. 7401 <E T="03">et seq.,</E> as amended by Pub. L. 91-604, 84 Stat. 1676 Pub. L. 95-95, 91 Stat., 685 and Pub. L. 95-190, 91 Stat., 1399.)<PRTPAGE P="131"/>
            </P>
            <P>(b) <E T="03">Administrator</E> means the Administrator of the Environmental Protection Agency (EPA) or an authorized representative.</P>
            <P>(c) <E T="03">Primary standard</E> means a national primary ambient air quality standard promulgated pursuant to section 109 of the Act.</P>
            <P>(d) <E T="03">Secondary standard</E> means a national secondary ambient air quality standard promulgated pursuant to section 109 of the Act.</P>
            <P>(e) <E T="03">National standard</E> means either a primary or secondary standard.</P>
            <P>(f) <E T="03">Owner or operator</E> means any person who owns, leases, operates, controls, or supervises a facility, building, structure, or installation which directly or indirectly result or may result in emissions of any air pollutant for which a national standard is in effect.</P>
            <P>(g) <E T="03">Local agency</E> means any local government agency other than the State agency, which is charged with responsibility for carrying out a portion of the plan.</P>
            <P>(h) <E T="03">Regional Office</E> means one of the ten (10) EPA Regional Offices.</P>
            <P>(i) <E T="03">State agency</E> means the air pollution control agency primarily responsible for development and implementation of a plan under the Act.</P>
            <P>(j) <E T="03">Plan</E> means an implementation plan approved or promulgated under section 110 of 172 of the Act.</P>
            <P>(k) <E T="03">Point source</E> means the following:</P>
            <P>(1) For particulate matter, sulfur oxides, carbon monoxide, volatile organic compounds (VOC) and nitrogen dioxide—</P>

            <P>(i) Any stationary source the actual emissions of which are in excess of 90.7 metric tons (100 tons) per year of the pollutant in a region containing an area whose 1980 <E T="03">urban place</E> population, as defined by the U.S. Bureau of the Census, was equal to or greater than 1 million.</P>

            <P>(ii) Any stationary source the actual emissions of which are in excess of 22.7 metric tons (25 tons) per year of the pollutant in a region containing an area whose 1980 <E T="03">urban place</E> population, as defined by the U.S. Bureau of the Census, was less than 1 million; or</P>
            <P>(2) For lead or lead compounds measured as elemental lead, any stationary source that actually emits a total of 4.5 metric tons (5 tons) per year or more.</P>
            <P>(l) <E T="03">Area source</E> means any small residential, governmental, institutional, commercial, or industrial fuel combustion operations; onsite solid waste disposal facility; motor vehicles, aircraft vessels, or other transportation facilities or other miscellaneous sources identified through inventory techniques similar to those described in the “AEROS Manual series, Vol. II AEROS User's Manual,” EPA-450/2-76-029 December 1976.</P>
            <P>(m) <E T="03">Region</E> means an area designated as an air quality control region (AQCR) under section 107(c) of the Act.</P>
            <P>(n) <E T="03">Control strategy</E> means a combination of measures designated to achieve the aggregate reduction of emissions necessary for attainment and maintenance of national standards including, but not limited to, measures such as:</P>
            <P>(1) Emission limitations.</P>
            <P>(2) Federal or State emission charges or taxes or other economic incentives or disincentives.</P>
            <P>(3) Closing or relocation of residential, commercial, or industrial facilities.</P>
            <P>(4) Changes in schedules or methods of operation of commercial or industrial facilities or transportation systems, including, but not limited to, short-term changes made in accordance with standby plans.</P>
            <P>(5) Periodic inspection and testing of motor vehicle emission control systems, at such time as the Administrator determines that such programs are feasible and practicable.</P>
            <P>(6) Emission control measures applicable to in-use motor vehicles, including, but not limited to, measures such as mandatory maintenance, installation of emission control devices, and conversion to gaseous fuels.</P>
            <P>(7) Any transportation control measure including those transportation measures listed in section 108(f) of the Clean Air Act as amended.</P>
            <P>(8) Any variation of, or alternative to any measure delineated herein.</P>

            <P>(9) Control or prohibition of a fuel or fuel additive used in motor vehicles, if such control or prohibition is necessary to achieve a national primary or secondary air quality standard and is <PRTPAGE P="132"/>approved by the Administrator under section 211(c)(4)(C) of the Act.</P>
            <P>(o) <E T="03">Reasonably available control technology (RACT)</E> means devices, systems, process modifications, or other apparatus or techniques that are reasonably available taking into account:</P>
            <P>(1) The necessity of imposing such controls in order to attain and maintain a national ambient air quality standard;</P>
            <P>(2) The social, environmental, and economic impact of such controls; and</P>
            <P>(3) Alternative means of providing for attainment and maintenance of such standard. (This provision defines RACT for the purposes of § 51.341(b) only.)</P>
            <P>(p) <E T="03">Compliance schedule</E> means the date or dates by which a source or category of sources is required to comply with specific emission limitations contained in an implementation plan and with any increments of progress toward such compliance.</P>
            <P>(q) <E T="03">Increments of progress</E> means steps toward compliance which will be taken by a specific source, including:</P>
            <P>(1) Date of submittal of the source's final control plan to the appropriate air pollution control agency;</P>
            <P>(2) Date by which contracts for emission control systems or process modifications will be awarded; or date by which orders will be issued for the purchase of component parts to accomplish emission control or process modification;</P>
            <P>(3) Date of initiation of on-site construction or installation of emission control equipment or process change;</P>
            <P>(4) Date by which on-site construction or installation of emission control equipment or process modification is to be completed; and</P>
            <P>(5) Date by which final compliance is to be achieved.</P>
            <P>(r) <E T="03">Transportation control measure</E> means any measure that is directed toward reducing emissions of air pollutants from transportation sources. Such measures include, but are not limited to, those listed in section 108(f) of the Clean Air Act.</P>
            <P>(s) <E T="03">Volatile organic compounds (VOC)</E> means any compound of carbon, excluding carbon monoxide, carbon dioxide, carbonic acid, metallic carbides or carbonates, and ammonium carbonate, which participates in atmospheric photochemical reactions.</P>

            <P>(1) This includes any such organic compound other than the following, which have been determined to have negligible photochemical reactivity: methane; ethane; methylene chloride (dichloromethane); 1,1,1-trichloroethane (methyl chloroform); 1,1,2-trichloro-1,2,2-trifluoroethane (CFC-113); trichlorofluoromethane (CFC-11); dichlorodifluoromethane (CFC-12); chlorodifluoromethane (HCFC-22); trifluoromethane (HFC-23); 1,2-dichloro 1,1,2,2-tetrafluoroethane (CFC-114); chloropentafluoroethane (CFC-115); 1,1,1-trifluoro 2,2-dichloroethane (HCFC-123); 1,1,1,2-tetrafluoroethane (HFC-134a); 1,1-dichloro 1-fluoroethane (HCFC-141b); 1-chloro 1,1-difluoroethane (HCFC-142b); 2-chloro-1,1,1,2-tetrafluoroethane (HCFC-124); pentafluoroethane (HFC-125); 1,1,2,2-tetrafluoroethane (HFC-134); 1,1,1-trifluoroethane (HFC-143a); 1,1-difluoroethane (HFC-152a); parachlorobenzotrifluoride (PCBTF); cyclic, branched, or linear completely methylated siloxanes; acetone; perchloroethylene (tetrachloroethylene); 3,3-dichloro-1,1,1,2,2-pentafluoropropane (HCFC-225ca); 1,3-dichloro-1,1,2,2,3-pentafluoropropane (HCFC-225cb); 1,1,1,2,3,4,4,5,5,5-decafluoropentane (HFC 43-10mee); difluoromethane (HFC-32); ethylfluoride (HFC-161); 1,1,1,3,3,3-hexafluoropropane (HFC-236fa); 1,1,2,2,3-pentafluoropropane (HFC-245ca); 1,1,2,3,3-pentafluoropropane (HFC-245ea); 1,1,1,2,3-pentafluoropropane (HFC-245eb); 1,1,1,3,3-pentafluoropropane (HFC-245fa); 1,1,1,2,3,3-hexafluoropropane (HFC-236ea); 1,1,1,3,3-pentafluorobutane (HFC-365mfc); chlorofluoromethane (HCFC-31); 1 chloro-1-fluoroethane (HCFC-151a); 1,2-dichloro-1,1,2-trifluoroethane (HCFC-123a); 1,1,1,2,2,3,3,4,4-nonafluoro-4-methoxy-butane (C<E T="52">4</E>F<E T="52">9</E>OCH<E T="52">3</E> or HFE-7100); 2-(difluoromethoxymethyl)-1,1,1,2,3,3,3-heptafluoropropane ((CF<E T="52">3</E>)<E T="52">2</E>CFCF<E T="52">2</E>OCH<E T="52">3</E>); 1-ethoxy-1,1,2,2,3,3,4,4,4-nonafluorobutane (C<E T="52">4</E>F<E T="52">9</E>OC<E T="52">2</E>H<E T="52">5</E> or HFE-7200); 2-(ethoxydifluoromethyl)-1,1,1,2,3,3,3-heptafluoropropane ((CF<E T="52">3</E>)<E T="52">2</E>CFCF<E T="52">2</E>OC<E T="52">2</E>H<E T="52">5</E>); methyl acetate, <PRTPAGE P="133"/>1,1,1,2,2,3,3-heptafluoro-3-methoxy-propane (n-C<E T="52">3</E>F<E T="52">7</E>OCH<E T="52">3</E>, HFE-7000), 3-ethoxy-1,1,1,2,3,4,4,5,5,6,6,6-dodecafluoro-2-(trifluoromethyl) hexane (HFE-7500), 1,1,1,2,3,3,3-heptafluoropropane (HFC 227ea), and methyl formate (HCOOCH3), and perfluorocarbon compounds which fall into these classes:</P>
            <P>(i) Cyclic, branched, or linear, completely fluorinated alkanes;</P>
            <P>(ii) Cyclic, branched, or linear, completely fluorinated ethers with no unsaturations;</P>
            <P>(iii) Cyclic, branched, or linear, completely fluorinated tertiary amines with no unsaturations; and</P>
            <P>(iv) Sulfur containing perfluorocarbons with no unsaturations and with sulfur bonds only to carbon and fluorine.</P>
            <P>(2) For purposes of determining compliance with emissions limits, VOC will be measured by the test methods in the approved State implementation plan (SIP) or 40 CFR part 60, appendix A, as applicable. Where such a method also measures compounds with negligible photochemical reactivity, these negligibility-reactive compounds may be excluded as VOC if the amount of such compounds is accurately quantified, and such exclusion is approved by the enforcement authority.</P>
            <P>(3) As a precondition to excluding these compounds as VOC or at any time thereafter, the enforcement authority may require an owner or operator to provide monitoring or testing methods and results demonstrating, to the satisfaction of the enforcement authority, the amount of negligibly-reactive compounds in the source's emissions.</P>
            <P>(4) For purposes of Federal enforcement for a specific source, the EPA shall use the test methods specified in the applicable EPA-approved SIP, in a permit issued pursuant to a program approved or promulgated under title V of the Act, or under 40 CFR part 51, subpart I or appendix S, or under 40 CFR parts 52 or 60. The EPA shall not be bound by any State determination as to appropriate methods for testing or monitoring negligibly-reactive compounds if such determination is not reflected in any of the above provisions.</P>
            <P>(5) The following compound(s) are VOC for purposes of all recordkeeping, emissions reporting, photochemical dispersion modeling and inventory requirements which apply to VOC and shall be uniquely identified in emission reports, but are not VOC for purposes of VOC emissions limitations or VOC content requirements: t-butyl acetate.</P>
            <P>(6) For the purposes of determining compliance with California's aerosol coatings reactivity-based regulation, (as described in the California Code of Regulations, Title 17, Division 3, Chapter 1, Subchapter 8.5, Article 3), any organic compound in the volatile portion of an aerosol coating is counted towards that product's reactivity-based limit. Therefore, the compounds identified in paragraph (s) of this section as negligibly reactive and excluded from EPA's definition of VOCs are to be counted towards a product's reactivity limit for the purposes of determining compliance with California's aerosol coatings reactivity-based regulation.</P>
            <P>(t)-(w) [Reserved]</P>
            <P>(x) <E T="03">Time period</E> means any period of time designated by hour, month, season, calendar year, averaging time, or other suitable characteristics, for which ambient air quality is estimated.</P>
            <P>(y) <E T="03">Variance</E> means the temporary deferral of a final compliance date for an individual source subject to an approved regulation, or a temporary change to an approved regulation as it applies to an individual source.</P>
            <P>(z) <E T="03">Emission limitation</E> and <E T="03">emission standard</E> mean a requirement established by a State, local government, or the Administrator which limits the quantity, rate, or concentration of emissions of air pollutants on a continuous basis, including any requirements which limit the level of opacity, prescribe equipment, set fuel specifications, or prescribe operation or maintenance procedures for a source to assure continuous emission reduction.</P>
            <P>(aa) <E T="03">Capacity factor</E> means the ratio of the average load on a machine or equipment for the period of time considered to the capacity rating of the machine or equipment.</P>
            <P>(bb) <E T="03">Excess emissions</E> means emissions of an air pollutant in excess of an emission standard.<PRTPAGE P="134"/>
            </P>
            <P>(cc) <E T="03">Nitric acid plant</E> means any facility producing nitric acid 30 to 70 percent in strength by either the pressure or atmospheric pressure process.</P>
            <P>(dd) <E T="03">Sulfuric acid plant</E> means any facility producing sulfuric acid by the contact process by burning elemental sulfur, alkylation acid, hydrogen sulfide, or acid sludge, but does not include facilities where conversion to sulfuric acid is utilized primarily as a means of preventing emissions to the atmosphere of sulfur dioxide or other sulfur compounds.</P>
            <P>(ee) <E T="03">Fossil fuel-fired steam generator</E> means a furnance or bioler used in the process of burning fossil fuel for the primary purpose of producing steam by heat transfer.</P>
            <P>(ff) <E T="03">Stack</E> means any point in a source designed to emit solids, liquids, or gases into the air, including a pipe or duct but not including flares.</P>
            <P>(gg) <E T="03">A stack in existence</E> means that the owner or operator had (1) begun, or caused to begin, a continuous program of physical on-site construction of the stack or (2) entered into binding agreements or contractual obligations, which could not be cancelled or modified without substantial loss to the owner or operator, to undertake a program of construction of the stack to be completed within a reasonable time.</P>
            <P>(hh)(1) <E T="03">Dispersion technique</E> means any technique which attempts to affect the concentration of a pollutant in the ambient air by:</P>
            <P>(i) Using that portion of a stack which exceeds good engineering practice stack height:</P>
            <P>(ii) Varying the rate of emission of a pollutant according to atmospheric conditions or ambient concentrations of that pollutant; or</P>
            <P>(iii) Increasing final exhaust gas plume rise by manipulating source process parameters, exhaust gas parameters, stack parameters, or combining exhaust gases from several existing stacks into one stack; or other selective handling of exhaust gas streams so as to increase the exhaust gas plume rise.</P>
            <P>(2) The preceding sentence does not include:</P>
            <P>(i) The reheating of a gas stream, following use of a pollution control system, for the purpose of returning the gas to the temperature at which it was originally discharged from the facility generating the gas stream;</P>
            <P>(ii) The merging of exhaust gas streams where:</P>
            <P>(A) The source owner or operator demonstrates that the facility was originally designed and constructed with such merged gas streams;</P>

            <P>(B) After July 8, 1985 such merging is part of a change in operation at the facility that includes the installation of pollution controls and is accompanied by a net reduction in the allowable emissions of a pollutant. This exclusion from the definition of <E T="03">dispersion techniques</E> shall apply only to the emission limitation for the pollutant affected by such change in operation; or</P>
            <P>(C) Before July 8, 1985, such merging was part of a change in operation at the facility that included the installation of emissions control equipment or was carried out for sound economic or engineering reasons. Where there was an increase in the emission limitation or, in the event that no emission limitation was in existence prior to the merging, an increase in the quantity of pollutants actually emitted prior to the merging, the reviewing agency shall presume that merging was significantly motivated by an intent to gain emissions credit for greater dispersion. Absent a demonstration by the source owner or operator that merging was not significantly motivated by such intent, the reviewing agency shall deny credit for the effects of such merging in calculating the allowable emissions for the source;</P>
            <P>(iii) Smoke management in agricultural or silvicultural prescribed burning programs;</P>
            <P>(iv) Episodic restrictions on residential woodburning and open burning; or</P>
            <P>(v) Techniques under § 51.100(hh)(1)(iii) which increase final exhaust gas plume rise where the resulting allowable emissions of sulfur dioxide from the facility do not exceed 5,000 tons per year.</P>
            <P>(ii) <E T="03">Good engineering practice</E> (GEP) stack height means the greater of:</P>
            <P>(1) 65 meters, measured from the ground-level elevation at the base of the stack:</P>

            <P>(2)(i) For stacks in existence on January 12, 1979, and for which the owner <PRTPAGE P="135"/>or operator had obtained all applicable permits or approvals required under 40 CFR parts 51 and 52.
            </P>
            <FP SOURCE="FP-1">H<E T="52">g</E> = 2.5H,</FP>
            
            <FP>provided the owner or operator produces evidence that this equation was actually relied on in establishing an emission limitation:</FP>
            <P>(ii) For all other stacks,
            </P>
            <FP SOURCE="FP-1">H<E T="52">g</E> = H + 1.5L</FP>
            
            <EXTRACT>
              <FP>where:</FP>
              
              <FP SOURCE="FP-1">H<E T="52">g</E> = good engineering practice stack height, measured from the ground-level elevation at the base of the stack,</FP>
              <FP SOURCE="FP-1">H = height of nearby structure(s) measured from the ground-level elevation at the base of the stack.</FP>
              <FP SOURCE="FP-1">L = lesser dimension, height or projected width, of nearby structure(s)</FP>
            </EXTRACT>
            
            <FP>provided that the EPA, State or local control agency may require the use of a field study or fluid model to verify GEP stack height for the source; or</FP>
            <P>(3) The height demonstrated by a fluid model or a field study approved by the EPA State or local control agency, which ensures that the emissions from a stack do not result in excessive concentrations of any air pollutant as a result of atmospheric downwash, wakes, or eddy effects created by the source itself, nearby structures or nearby terrain features.</P>
            <P>(jj) <E T="03">Nearby</E> as used in § 51.100(ii) of this part is defined for a specific structure or terrain feature and</P>
            <P>(1) For purposes of applying the formulae provided in § 51.100(ii)(2) means that distance up to five times the lesser of the height or the width dimension of a structure, but not greater than 0.8 km (<FR>1/2</FR> mile), and</P>

            <P>(2) For conducting demonstrations under § 51.100(ii)(3) means not greater than 0.8 km (<FR>1/2</FR> mile), except that the portion of a terrain feature may be considered to be nearby which falls within a distance of up to 10 times the maximum height (H<E T="52">t</E>) of the feature, not to exceed 2 miles if such feature achieves a height (H<E T="52">t</E>) 0.8 km from the stack that is at least 40 percent of the GEP stack height determined by the formulae provided in § 51.100(ii)(2)(ii) of this part or 26 meters, whichever is greater, as measured from the ground-level elevation at the base of the stack. The height of the structure or terrain feature is measured from the ground-level elevation at the base of the stack.</P>
            <P>(kk) <E T="03">Excessive concentration</E> is defined for the purpose of determining good engineering practice stack height under § 51.100(ii)(3) and means:</P>
            <P>(1) For sources seeking credit for stack height exceeding that established under § 51.100(ii)(2) a maximum ground-level concentration due to emissions from a stack due in whole or part to downwash, wakes, and eddy effects produced by nearby structures or nearby terrain features which individually is at least 40 percent in excess of the maximum concentration experienced in the absence of such downwash, wakes, or eddy effects and which contributes to a total concentration due to emissions from all sources that is greater than an ambient air quality standard. For sources subject to the prevention of significant deterioration program (40 CFR 51.166 and 52.21), an excessive concentration alternatively means a maximum ground-level concentration due to emissions from a stack due in whole or part to downwash, wakes, or eddy effects produced by nearby structures or nearby terrain features which individually is at least 40 percent in excess of the maximum concentration experienced in the absence of such downwash, wakes, or eddy effects and greater than a prevention of significant deterioration increment. The allowable emission rate to be used in making demonstrations under this part shall be prescribed by the new source performance standard that is applicable to the source category unless the owner or operator demonstrates that this emission rate is infeasible. Where such demonstrations are approved by the authority administering the State implementation plan, an alternative emission rate shall be established in consultation with the source owner or operator.</P>

            <P>(2) For sources seeking credit after October 11, 1983, for increases in existing stack heights up to the heights established under § 51.100(ii)(2), either (i) a maximum ground-level concentration due in whole or part to downwash, wakes or eddy effects as provided in <PRTPAGE P="136"/>paragraph (kk)(1) of this section, except that the emission rate specified by any applicable State implementation plan (or, in the absence of such a limit, the actual emission rate) shall be used, or (ii) the actual presence of a local nuisance caused by the existing stack, as determined by the authority administering the State implementation plan; and</P>
            <P>(3) For sources seeking credit after January 12, 1979 for a stack height determined under § 51.100(ii)(2) where the authority administering the State implementation plan requires the use of a field study or fluid model to verify GEP stack height, for sources seeking stack height credit after November 9, 1984 based on the aerodynamic influence of cooling towers, and for sources seeking stack height credit after December 31, 1970 based on the aerodynamic influence of structures not adequately represented by the equations in § 51.100(ii)(2), a maximum ground-level concentration due in whole or part to downwash, wakes or eddy effects that is at least 40 percent in excess of the maximum concentration experienced in the absence of such downwash, wakes, or eddy effects.</P>
            <P>(ll)-(mm) [Reserved]</P>
            <P>(nn) Intermittent control system (ICS) means a dispersion technique which varies the rate at which pollutants are emitted to the atmosphere according to meteorological conditions and/or ambient concentrations of the pollutant, in order to prevent ground-level concentrations in excess of applicable ambient air quality standards. Such a dispersion technique is an ICS whether used alone, used with other dispersion techniques, or used as a supplement to continuous emission controls (i.e., used as a supplemental control system).</P>
            <P>(oo) <E T="03">Particulate matter</E> means any airborne finely divided solid or liquid material with an aerodynamic diameter smaller than 100 micrometers.</P>
            <P>(pp) <E T="03">Particulate matter emissions</E> means all finely divided solid or liquid material, other than uncombined water, emitted to the ambient air as measured by applicable reference methods, or an equivalent or alternative method, specified in this chapter, or by a test method specified in an approved State implementation plan.</P>
            <P>(qq) <E T="03">PM</E>
              <E T="52">10</E> means particulate matter with an aerodynamic diameter less than or equal to a nominal 10 micrometers as measured by a reference method based on appendix J of part 50 of this chapter and designated in accordance with part 53 of this chapter or by an equivalent method designated in accordance with part 53 of this chapter.</P>
            <P>(rr) <E T="03">PM</E>
              <E T="52">10</E>
              <E T="03">emissions</E> means finely divided solid or liquid material, with an aerodynamic diameter less than or equal to a nominal 10 micrometers emitted to the ambient air as measured by an applicable reference method, or an equivalent or alternative method, specified in this chapter or by a test method specified in an approved State implementation plan.</P>
            <P>(ss) <E T="03">Total suspended particulate</E> means particulate matter as measured by the method described in appendix B of part 50 of this chapter.</P>
            <CITA>[51 FR 40661, Nov. 7, 1986, as amended at 52 FR 24712, July 1, 1987; 57 FR 3945, Feb. 3, 1992; 61 FR 4590, Feb. 7, 1996; 61 FR 16060, Apr. 11, 1996; 61 FR 30162, June 14, 1996; 61 FR 52850, Oct. 8, 1996; 62 FR 44903, Aug. 25, 1997; 63 FR 9151, Feb. 24, 1998; 63 FR 17333, Apr. 9, 1998; 69 FR 69298, 69304, Nov. 29, 2004; 70 FR 53935, Sept. 13, 2005]</CITA>
          </SECTION>
          <SECTION>
            <SECTNO>§ 51.101</SECTNO>
            <SUBJECT>Stipulations.</SUBJECT>
            <P>Nothing in this part will be construed in any manner:</P>
            <P>(a) To encourage a State to prepare, adopt, or submit a plan which does not provide for the protection and enhancement of air quality so as to promote the public health and welfare and productive capacity.</P>
            <P>(b) To encourage a State to adopt any particular control strategy without taking into consideration the cost-effectiveness of such control strategy in relation to that of alternative control strategies.</P>
            <P>(c) To preclude a State from employing techniques other than those specified in this part for purposes of estimating air quality or demonstrating the adequacy of a control strategy, provided that such other techniques are shown to be adequate and appropriate for such purposes.</P>

            <P>(d) To encourage a State to prepare, adopt, or submit a plan without taking <PRTPAGE P="137"/>into consideration the social and economic impact of the control strategy set forth in such plan, including, but not limited to, impact on availability of fuels, energy, transportation, and employment.</P>
            <P>(e) To preclude a State from preparing, adopting, or submitting a plan which provides for attainment and maintenance of a national standard through the application of a control strategy not specifically identified or described in this part.</P>
            <P>(f) To preclude a State or political subdivision thereof from adopting or enforcing any emission limitations or other measures or combinations thereof to attain and maintain air quality better than that required by a national standard.</P>
            <P>(g) To encourage a State to adopt a control strategy uniformly applicable throughout a region unless there is no satisfactory alternative way of providing for attainment and maintenance of a national standard throughout such region.</P>
            <CITA>[61 FR 30163, June 14, 1996]</CITA>
          </SECTION>
          <SECTION>
            <SECTNO>§ 51.102</SECTNO>
            <SUBJECT>Public hearings.</SUBJECT>
            <P>(a) Except as otherwise provided in paragraph (c) of this section, States must conduct one or more public hearings on the following prior to adoption and submission to EPA of:</P>
            <P>(1) Any plan or revision of it required by § 51.104(a).</P>
            <P>(2) Any individual compliance schedule under (§ 51.260).</P>
            <P>(3) Any revision under § 51.104(d).</P>
            <P>(b) Separate hearings may be held for plans to implement primary and secondary standards.</P>
            <P>(c) No hearing will be required for any change to an increment of progress in an approved individual compliance schedule unless such change is likely to cause the source to be unable to comply with the final compliance date in the schedule. The requirements of §§ 51.104 and 51.105 will be applicable to such schedules, however.</P>
            <P>(d) Any hearing required by paragraph (a) of this section will be held only after reasonable notice, which will be considered to include, at least 30 days prior to the date of such hearing(s):</P>
            <P>(1) Notice given to the public by prominent advertisement in the area affected announcing the date(s), time(s), and place(s) of such hearing(s);</P>
            <P>(2) Availability of each proposed plan or revision for public inspection in at least one location in each region to which it will apply, and the availability of each compliance schedule for public inspection in at least one location in the region in which the affected source is located;</P>
            <P>(3) Notification to the Administrator (through the appropriate Regional Office);</P>
            <P>(4) Notification to each local air pollution control agency which will be significantly impacted by such plan, schedule or revision;</P>
            <P>(5) In the case of an interstate region, notification to any other States included, in whole or in part, in the regions which are significantly impacted by such plan or schedule or revision.</P>
            <P>(e) The State must prepare and retain, for inspection by the Administrator upon request, a record of each hearing. The record must contain, as a minimum, a list of witnesses together with the text of each presentation.</P>
            <P>(f) The State must submit with the plan, revision, or schedule a certification that the hearing required by paragraph (a) of this section was held in accordance with the notice required by paragraph (d) of this section.</P>
            <P>(g) Upon written application by a State agency (through the appropriate Regional Office), the Administrator may approve State procedures for public hearings. The following criteria apply:</P>
            <P>(1) Procedures approved under this section shall be deemed to satisfy the requirement of this part regarding public hearings.</P>
            <P>(2) Procedures different from this part may be approved if they—</P>
            <P>(i) Ensure public participation in matters for which hearings are required; and</P>
            <P>(ii) Provide adequate public notification of the opportunity to participate.</P>
            <P>(3) The Administrator may impose any conditions on approval he or she deems necessary.</P>
            <CITA>[36 FR 22938, Nov. 25, 1971, as amended at 65 FR 8657, Feb. 22, 2000]</CITA>
          </SECTION>
          <SECTION>
            <PRTPAGE P="138"/>
            <SECTNO>§ 51.103</SECTNO>
            <SUBJECT>Submission of plans, preliminary review of plans.</SUBJECT>
            <P>(a) The State makes an official plan submission to EPA only when the submission conforms to the requirements of appendix V to this part, and the State delivers five copies of the plan to the appropriate Regional Office, with a letter giving notice of such action.</P>
            <P>(b) Upon request of a State, the Administrator will provide preliminary review of a plan or portion thereof submitted in advance of the date such plan is due. Such requests must be made in writing to the appropriate Regional Office and must be accompanied by five copies of the materials to be reviewed. Requests for preliminary review do not relieve a State of the responsibility of adopting and submitting plans in accordance with prescribed due dates.</P>
            <CITA>[51 FR 40661, Nov. 7, 1986, as amended at 55 FR 5830, Feb. 16, 1990; 63 FR 9151, Feb. 24, 1998]</CITA>
          </SECTION>
          <SECTION>
            <SECTNO>§ 51.104</SECTNO>
            <SUBJECT>Revisions.</SUBJECT>
            <P>(a) States may revise the plan from time to time consistent with the requirements applicable to implementation plans under this part.</P>
            <P>(b) The States must submit any revision of any regulation or any compliance schedule under paragraph (c) of this section to the Administrator no later than 60 days after its adoption.</P>
            <P>(c) EPA will approve revisions only after applicable hearing requirements of § 51.102 have been satisfied.</P>
            <P>(d) In order for a variance to be considered for approval as a revision to the State implementation plan, the State must submit it in accordance with the requirements of this section.</P>
            <CITA>[51 FR 40661, Nov. 7, 1986, as amended at 61 FR 16060, Apr. 11, 1996]</CITA>
          </SECTION>
          <SECTION>
            <SECTNO>§ 51.105</SECTNO>
            <SUBJECT>Approval of plans.</SUBJECT>
            <P>Revisions of a plan, or any portion thereof, will not be considered part of an applicable plan until such revisions have been approved by the Administrator in accordance with this part.</P>
            <CITA>[51 FR 40661, Nov. 7, 1986, as amended at 60 FR 33922, June 29, 1995]</CITA>
          </SECTION>
        </SUBPART>
        <SUBPART>
          <HD SOURCE="HED">Subpart G—Control Strategy</HD>
          <SOURCE>
            <HD SOURCE="HED">Source:</HD>
            <P>51 FR 40665, Nov. 7, 1986, unless otherwise noted.</P>
          </SOURCE>
          <SECTION>
            <SECTNO>§ 51.110</SECTNO>
            <SUBJECT>Attainment and maintenance of national standards.</SUBJECT>
            <P>(a) Each plan providing for the attainment of a primary or secondary standard must specify the projected attainment date.</P>
            <P>(b)-(f) [Reserved]</P>
            <P>(g) During developing of the plan, EPA encourages States to identify alternative control strategies, as well as the costs and benefits of each such alternative for attainment or maintenance of the national standard.</P>
            <CITA>[51 FR 40661 Nov. 7, 1986 as amended at 61 FR 16060, Apr. 11, 1996; 61 FR 30163, June 14, 1996]</CITA>
          </SECTION>
          <SECTION>
            <SECTNO>§ 51.111</SECTNO>
            <SUBJECT>Description of control measures.</SUBJECT>
            <P>Each plan must set forth a control strategy which includes the following:</P>
            <P>(a) A description of enforcement methods including, but not limited to:</P>
            <P>(1) Procedures for monitoring compliance with each of the selected control measures,</P>
            <P>(2) Procedures for handling violations, and</P>
            <P>(3) A designation of agency responsibility for enforcement of implementation.</P>
            <P>(b) [Reserved]</P>
            <CITA>[51 FR 40665, Nov. 7, 1986, as amended at 60 FR 33922, June 29, 1995]</CITA>
          </SECTION>
          <SECTION>
            <SECTNO>§ 51.112</SECTNO>
            <SUBJECT>Demonstration of adequacy.</SUBJECT>
            <P>(a) Each plan must demonstrate that the measures, rules, and regulations contained in it are adequate to provide for the timely attainment and maintenance of the national standard that it implements.</P>
            <P>(1) The adequacy of a control strategy shall be demonstrated by means of applicable air quality models, data bases, and other requirements specified in appendix W of this part (Guideline on Air Quality Models).</P>

            <P>(2) Where an air quality model specified in appendix W of this part (Guideline on Air Quality Models) is inappropriate, the model may be modified or another model substituted. Such a modification or substitution of a model <PRTPAGE P="139"/>may be made on a case-by-case basis or, where appropriate, on a generic basis for a specific State program. Written approval of the Administrator must be obtained for any modification or substitution. In addition, use of a modified or substituted model must be subject to notice and opportunity for public comment under procedures set forth in § 51.102.</P>
            <P>(b) The demonstration must include the following:</P>
            <P>(1) A summary of the computations, assumptions, and judgments used to determine the degree of reduction of emissions (or reductions in the growth of emissions) that will result from the implementation of the control strategy.</P>
            <P>(2) A presentation of emission levels expected to result from implementation of each measure of the control strategy.</P>
            <P>(3) A presentation of the air quality levels expected to result from implementation of the overall control strategy presented either in tabular form or as an isopleth map showing expected maximum pollutant concentrations.</P>
            <P>(4) A description of the dispersion models used to project air quality and to evaluate control strategies.</P>
            <P>(5) For interstate regions, the analysis from each constituent State must, where practicable, be based upon the same regional emission inventory and air quality baseline.</P>
            <CITA>[51 FR 40665, Nov. 7, 1986, as amended at 58 FR 38821, July 20, 1993; 60 FR 40468, Aug. 9, 1995; 61 FR 41840, Aug. 12, 1996]</CITA>
          </SECTION>
          <SECTION>
            <SECTNO>§ 51.113</SECTNO>
            <RESERVED>[Reserved]</RESERVED>
          </SECTION>
          <SECTION>
            <SECTNO>§ 51.114</SECTNO>
            <SUBJECT>Emissions data and projections.</SUBJECT>
            <P>(a) Except for lead, each plan must contain a detailed inventory of emissions from point and area sources. Lead requirements are specified in § 51.117. The inventory must be based upon measured emissions or, where measured emissions are not available, documented emission factors.</P>
            <P>(b) Each plan must contain a summary of emission levels projected to result from application of the new control strategy.</P>
            <P>(c) Each plan must identify the sources of the data used in the projection of emissions.</P>
          </SECTION>
          <SECTION>
            <SECTNO>§ 51.115</SECTNO>
            <SUBJECT>Air quality data and projections.</SUBJECT>
            <P>(a) Each plan must contain a summary of data showing existing air quality.</P>
            <P>(b) Each plan must:</P>
            <P>(1) Contain a summary of air quality concentrations expected to result from application of the control strategy, and</P>
            <P>(2) Identify and describe the dispersion model, other air quality model, or receptor model used.</P>
            <P>(c) Actual measurements of air quality must be used where available if made by methods specified in appendix C to part 58 of this chapter. Estimated air quality using appropriate modeling techniques may be used to supplement measurements.</P>
            <P>(d) For purposes of developing a control strategy, background concentration shall be taken into consideration with respect to particulate matter. As used in this subpart, background concentration is that portion of the measured ambient levels that cannot be reduced by controlling emissions from man-made sources.</P>
            <P>(e) In developing an ozone control strategy for a particular area, background ozone concentrations and ozone transported into an area must be considered. States may assume that the ozone standard will be attained in upwind areas.</P>
          </SECTION>
          <SECTION>
            <SECTNO>§ 51.116</SECTNO>
            <SUBJECT>Data availability.</SUBJECT>
            <P>(a) The State must retain all detailed data and calculations used in the preparation of each plan or each plan revision, and make them available for public inspection and submit them to the Administrator at his request.</P>
            <P>(b) The detailed data and calculations used in the preparation of plan revisions are not considered a part of the plan.</P>

            <P>(c) Each plan must provide for public availability of emission data reported by source owners or operators or otherwise obtained by a State or local agency. Such emission data must be correlated with applicable emission limitations or other measures. As used in <PRTPAGE P="140"/>this paragraph, <E T="03">correlated</E> means presented in such a manner as to show the relationship between measured or estimated amounts of emissions and the amounts of such emissions allowable under the applicable emission limitations or other measures.</P>
          </SECTION>
          <SECTION>
            <SECTNO>§ 51.117</SECTNO>
            <SUBJECT>Additional provisions for lead.</SUBJECT>
            <P>In addition to other requirements in §§ 51.100 through 51.116 the following requirements apply to lead. To the extent they conflict, there requirements are controlling over those of the proceeding sections.</P>
            <P>(a) <E T="03">Control strategy demonstration.</E> Each plan must contain a demonstration showing that the plan will attain and maintain the standard in the following areas:</P>
            <P>(1) Areas in the vicinity of the following point sources of lead: Primary lead smelters, Secondary lead smelters, Primary copper smelters, Lead gasoline additive plants, Lead-acid storage battery manufacturing plants that produce 2,000 or more batteries per day. Any other stationary source that actually emits 25 or more tons per year of lead or lead compounds measured as elemental lead.</P>
            <P>(2) Any other area that has lead air concentrations in excess of the national ambient air quality standard concentration for lead, measured since January 1, 1974.</P>
            <P>(b) <E T="03">Time period for demonstration of adequacy.</E> The demonstration of adequacy of the control strategy required under § 51.112 may cover a longer period if allowed by the appropriate EPA Regional Administrator.</P>
            <P>(c) <E T="03">Special modeling provisions.</E> (1) For urbanized areas with measured lead concentrations in excess of 4.0 µg/m<SU>3</SU>, quarterly mean measured since January 1, 1974, the plan must employ the modified rollback model for the demonstration of attainment as a minimum, but may use an atmospheric dispersion model if desired, consistent with requirements contained in § 51.112(a). If a proportional model is used, the air quality data should be the same year as the emissions inventory required under the paragraph e.</P>
            <P>(2) For each point source listed in § 51.117(a), that plan must employ an atmospheric dispersion model for demonstration of attainment, consistent with requirements contained in § 51.112(a).</P>
            <P>(3) For each area in the vicinity of an air quality monitor that has recorded lead concentrations in excess of the lead national standard concentration, the plan must employ the modified rollback model as a minimum, but may use an atmospheric dispersion model if desired for the demonstration of attainment, consistent with requirements contained in § 51.112(a).</P>
            <P>(d) <E T="03">Air quality data and projections.</E> (1) Each State must submit to the appropriate EPA Regional Office with the plan, but not part of the plan, all lead air quality data measured since January 1, 1974. This requirement does not apply if the data has already been submitted.</P>
            <P>(2) The data must be submitted in accordance with the procedures and data forms specified in Chapter 3.4.0 of the “AEROS User's Manual” concerning storage and retrieval of aerometric data (SAROAD) except where the Regional Administrator waives this requirement.</P>
            <P>(3) If additional lead air quality data are desired to determine lead air concentrations in areas suspected of exceeding the lead national ambient air quality standard, the plan may include data from any previously collected filters from particulate matter high volume samplers. In determining the lead content of the filters for control strategy demonstration purposes, a State may use, in addition to the reference method, X-ray fluorescence or any other method approved by the Regional Administrator.</P>
            <P>(e) <E T="03">Emissions data.</E> (1) The point source inventory on which the summary of the baseline lead emissions inventory is based must contain all sources that emit five or more tons of lead per year.</P>

            <P>(2) Each State must submit lead emissions data to the appropriate EPA Regional Office with the original plan. The submission must be made with the plan, but not as part of the plan, and must include emissions data and information related to point and area source emissions. The emission data and information should include the information identified in the Hazardous <PRTPAGE P="141"/>and Trace Emissions System (HATREMS) point source coding forms for all point sources and the area source coding forms for all sources that are not point sources, but need not necessarily be in the format of those forms.</P>
            <CITA>[41 FR 18388, May 3, 1976, as amended at 58 FR 38822, July 20, 1993]</CITA>
          </SECTION>
          <SECTION>
            <SECTNO>§ 51.118</SECTNO>
            <SUBJECT>Stack height provisions.</SUBJECT>
            <P>(a) The plan must provide that the degree of emission limitation required of any source for control of any air pollutant must not be affected by so much of any source's stack height that exceeds good engineering practice or by any other dispersion technique, except as provided in § 51.118(b). The plan must provide that before a State submits to EPA a new or revised emission limitation that is based on a good engineering practice stack height that exceeds the height allowed by § 51.100(ii) (1) or (2), the State must notify the public of the availabilty of the demonstration study and must provide opportunity for a public hearing on it. This section does not require the plan to restrict, in any manner, the actual stack height of any source.</P>
            <P>(b) The provisions of § 51.118(a) shall not apply to (1) stack heights in existence, or dispersion techniques implemented on or before December 31, 1970, except where pollutants are being emitted from such stacks or using such dispersion techniques by sources, as defined in section 111(a)(3) of the Clean Air Act, which were constructed, or reconstructed, or for which major modifications, as defined in §§ 51.165(a)(1)(v)(A), 51.166(b)(2)(i) and 52.21(b)(2)(i), were carried out after December 31, 1970; or (2) coal-fired steam electric generating units subject to the provisions of section 118 of the Clean Air Act, which commenced operation before July 1, 1957, and whose stacks were construced under a construction contract awarded before February 8, 1974.</P>
          </SECTION>
          <SECTION>
            <SECTNO>§ 51.119</SECTNO>
            <SUBJECT>Intermittent control systems.</SUBJECT>
            <P>(a) The use of an intermittent control system (ICS) may be taken into account in establishing an emission limitation for a pollutant under a State implementation plan, provided:</P>
            <P>(1) The ICS was implemented before December 31, 1970, according to the criteria specified in § 51.119(b).</P>
            <P>(2) The extent to which the ICS is taken into account is limited to reflect emission levels and associated ambient pollutant concentrations that would result if the ICS was the same as it was before December 31, 1970, and was operated as specified by the operating system of the ICS before December 31, 1970.</P>
            <P>(3) The plan allows the ICS to compensate only for emissions from a source for which the ICS was implemented before December 31, 1970, and, in the event the source has been modified, only to the extent the emissions correspond to the maximum capacity of the source before December 31, 1970. For purposes of this paragraph, a source for which the ICS was implemented is any particular structure or equipment the emissions from which were subject to the ICS operating procedures.</P>
            <P>(4) The plan requires the continued operation of any constant pollution control system which was in use before December 31, 1970, or the equivalent of that system.</P>
            <P>(5) The plan clearly defines the emission limits affected by the ICS and the manner in which the ICS is taken into account in establishing those limits.</P>
            <P>(6) The plan contains requirements for the operation and maintenance of the qualifying ICS which, together with the emission limitations and any other necessary requirements, will assure that the national ambient air quality standards and any applicable prevention of significant deterioration increments will be attained and maintained. These requirements shall include, but not necessarily be limited to, the following:</P>

            <P>(i) Requirements that a source owner or operator continuously operate and maintain the components of the ICS specified at § 51.119(b)(3) (ii)-(iv) in a manner which assures that the ICS is at least as effective as it was before December 31, 1970. The air quality monitors and meteorological instrumentation specified at § 51.119(b) may be operated by a local authority or other entity provided the source has ready access <PRTPAGE P="142"/>to the data from the monitors and instrumentation.</P>
            <P>(ii) Requirements which specify the circumstances under which, the extent to which, and the procedures through which, emissions shall be curtailed through the activation of ICS.</P>
            <P>(iii) Requirements for recordkeeping which require the owner or operator of the source to keep, for periods of at least 3 years, records of measured ambient air quality data, meteorological information acquired, and production data relating to those processes affected by the ICS.</P>
            <P>(iv) Requirements for reporting which require the owner or operator of the source to notify the State and EPA within 30 days of a NAAQS violation pertaining to the pollutant affected by the ICS.</P>
            <P>(7) Nothing in this paragraph affects the applicability of any new source review requirements or new source performance standards contained in the Clean Air Act or 40 CFR subchapter C. Nothing in this paragraph precludes a State from taking an ICS into account in establishing emission limitations to any extent less than permitted by this paragraph.</P>
            <P>(b) An intermittent control system (ICS) may be considered implemented for a pollutant before December 31, 1970, if the following criteria are met:</P>
            <P>(1) The ICS must have been established and operational with respect to that pollutant prior to December 31, 1970, and reductions in emissions of that pollutant must have occurred when warranted by meteorological and ambient monitoring data.</P>
            <P>(2) The ICS must have been designed and operated to meet an air quality objective for that pollutant such as an air quality level or standard.</P>
            <P>(3) The ICS must, at a minimum, have included the following components prior to December 31, 1970:</P>
            <P>(i) <E T="03">Air quality monitors.</E> An array of sampling stations whose location and type were consistent with the air quality objective and operation of the system.</P>
            <P>(ii) <E T="03">Meteorological instrumentation.</E> A meteorological data acquisition network (may be limited to a single station) which provided meteorological prediction capabilities sufficient to determine the need for, and degree of, emission curtailments necessary to achieve the air quality design objective.</P>
            <P>(iii) <E T="03">Operating system.</E> A system of established procedures for determining the need for curtailments and for accomplishing such curtailments. Documentation of this system, as required by paragraph (n)(4), may consist of a compendium of memoranda or comparable material which define the criteria and procedures for curtailments and which identify the type and number of personnel authorized to initiate curtailments.</P>
            <P>(iv) <E T="03">Meteorologist.</E> A person, schooled in meteorology, capable of interpreting data obtained from the meteorological network and qualified to forecast meteorological incidents and their effect on ambient air quality. Sources may have obtained meteorological services through a consultant. Services of such a consultant could include sufficient training of source personnel for certain operational procedures, but not for design, of the ICS.</P>
            <P>(4) Documentation sufficient to support the claim that the ICS met the criteria listed in this paragraph must be provided. Such documentation may include affidavits or other documentation.</P>
          </SECTION>
          <SECTION>
            <SECTNO>§ 51.120</SECTNO>
            <SUBJECT>Requirements for State Implementation Plan revisions relating to new motor vehicles.</SUBJECT>

            <P>(a) The EPA Administrator finds that the State Implementation Plans (SIPs) for the States of Connecticut, Delaware, Maine, Maryland, Massachusetts, New Hampshire, New Jersey, New York, Pennsylvania, Rhode Island, and Vermont, the portion of Virginia included (as of November 15, 1990) within the Consolidated Metropolitan Statistical Area that includes the District of Columbia, are substantially inadequate to comply with the requirements of section 110(a)(2)(D) of the Clean Air Act, 42 U.S.C. 7410(a)(2)(D), and to mitigate adequately the interstate pollutant transport described in section 184 of the Clean Air Act, 42 U.S.C. 7511C, to the extent that they do not provide for emission reductions from new motor vehicles in the amount that would be <PRTPAGE P="143"/>achieved by the Ozone Transport Commission low emission vehicle (OTC LEV) program described in paragraph (c) of this section. This inadequacy will be deemed cured for each of the aforementioned States (including the District of Columbia) in the event that EPA determines through rulemaking that a national LEV-equivalent new motor vehicle emission control program is an acceptable alternative for OTC LEV and finds that such program is in effect. In the event no such finding is made, each of those States must adopt and submit to EPA by February 15, 1996 a SIP revision meeting the requirements of paragraph (b) of this section in order to cure the SIP inadequacy.</P>
            <P>(b) If a SIP revision is required under paragraph (a) of this section, it must contain the OTC LEV program described in paragraph (c) of this section unless the State adopts and submits to EPA, as a SIP revision, other emission-reduction measures sufficient to meet the requirements of paragraph (d) of this section. If a State adopts and submits to EPA, as a SIP revision, other emission-reduction measures pursuant to paragraph (d) of this section, then for purposes of determining whether such a SIP revision is complete within the meaning of section 110(k)(1) (and hence is eligible at least for consideration to be approved as satisfying paragraph (d) of this section), such a SIP revision must contain other adopted emission-reduction measures that, together with the identified potentially broadly practicable measures, achieve at least the minimum level of emission reductions that could potentially satisfy the requirements of paragraph (d) of this section. All such measures must be fully adopted and enforceable.</P>
            <P>(c) The OTC LEV program is a program adopted pursuant to section 177 of the Clean Air Act.</P>
            <P>(1) The OTC LEV program shall contain the following elements:</P>
            <P>(i) It shall apply to all new 1999 and later model year passenger cars and light-duty trucks (0-5750 pounds loaded vehicle weight), as defined in Title 13, California Code of Regulations, section 1900(b)(11) and (b)(8), respectively, that are sold, imported, delivered, purchased, leased, rented, acquired, received, or registered in any area of the State that is in the Northeast Ozone Transport Region as of December 19, 1994.</P>
            <P>(ii) All vehicles to which the OTC LEV program is applicable shall be required to have a certificate from the California Air Resources Board (CARB) affirming compliance with California standards.</P>

            <P>(iii) All vehicles to which this LEV program is applicable shall be required to meet the mass emission standards for Non-Methane Organic Gases (NMOG), Carbon Monoxide (CO), Oxides of Nitrogen (NO<E T="52">X</E>), Formaldehyde (HCHO), and particulate matter (PM) as specified in Title 13, California Code of Regulations, section 1960.1(f)(2) (and formaldehyde standards under section 1960.1(e)(2), as applicable) or as specified by California for certification as a TLEV (Transitional Low-Emission Vehicle), LEV (Low-Emission Vehicle), ULEV (Ultra-Low-Emission Vehicle), or ZEV (Zero-Emission Vehicle) under section 1960.1(g)(1) (and section 1960.1(e)(3), for formaldehyde standards, as applicable).</P>
            <P>(iv) All manufacturers of vehicles subject to the OTC LEV program shall be required to meet the fleet average NMOG exhaust emission values for production and delivery for sale of their passenger cars, light-duty trucks 0-3750 pounds loaded vehicle weight, and light-duty trucks 3751-5750 pounds loaded vehicle weight specified in Title 13, California Code of Regulations, section 1960.1(g)(2) for each model year beginning in 1999. A State may determine not to implement the NMOG fleet average in the first model year of the program if the State begins implementation of the program late in a calendar year. However, all States must implement the NMOG fleet average in any full model years of the LEV program.</P>

            <P>(v) All manufacturers shall be allowed to average, bank and trade credits in the same manner as allowed under the program specified in Title 13, California Code of Regulations, section 1960.1(g)(2) footnote 7 for each model year beginning in 1999. States may account for credits banked by manufacturers in California or New York in years immediately preceding model year 1999, in a manner consistent with <PRTPAGE P="144"/>California banking and discounting procedures.</P>
            <P>(vi) The provisions for small volume manufacturers and intermediate volume manufacturers, as applied by Title 13, California Code of Regulations to California's LEV program, shall apply. Those manufacturers defined as small volume manufacturers and intermediate volume manufacturers in California under California's regulations shall be considered small volume manufacturers and intermediate volume manufacturers under this program.</P>
            <P>(vii) The provisions for hybrid electric vehicles (HEVs), as defined in Title 13 California Code of Regulations, section 1960.1, shall apply for purposes of calculating fleet average NMOG values.</P>
            <P>(viii) The provisions for fuel-flexible vehicles and dual-fuel vehicles specified in Title 13, California Code of Regulations, section 1960.1(g)(1) footnote 4 shall apply.</P>
            <P>(ix) The provisions for reactivity adjustment factors, as defined by Title 13, California Code of Regulations, shall apply.</P>
            <P>(x) The aforementioned State OTC LEV standards shall be identical to the aforementioned California standards as such standards exist on December 19, 1994.</P>
            <P>(xi) All States' OTC LEV programs must contain any other provisions of California's LEV program specified in Title 13, California Code of Regulations necessary to comply with section 177 of the Clean Air Act.</P>
            <P>(2) States are not required to include the mandate for production of ZEVs specified in Title 13, California Code of Regulations, section 1960.1(g)(2) footnote 9.</P>
            <P>(3) Except as specified elsewhere in this section, States may implement the OTC LEV program in any manner consistent with the Act that does not decrease the emissions reductions or jeopardize the effectiveness of the program.</P>
            <P>(d) The SIP revision that paragraph (b) of this section describes as an alternative to the OTC LEV program described in paragraph (c) of this section must contain a set of State-adopted measures that provides at least the following amount of emission reductions in time to bring serious ozone nonattainment areas into attainment by their 1999 attainment date:</P>
            <P>(1) Reductions at least equal to the difference between:</P>
            <P>(i) The nitrogen oxides (NO<E T="52">X</E>) emission reductions from the 1990 statewide emissions inventory achievable through implementation of all of the Clean Air Act-mandated and potentially broadly practicable control measures throughout all portions of the State that are within the Northeast Ozone Transport Region created under section 184(a) of the Clean Air Act as of December 19, 1994; and</P>
            <P>(ii) A reduction in NO<E T="52">X</E> emissions from the 1990 statewide inventory in such portions of the State of 50% or whatever greater reduction is necessary to prevent significant contribution to nonattainment in, or interference with maintenance by, any downwind State.</P>
            <P>(2) Reductions at least equal to the difference between:</P>
            <P>(i) The VOC emission reductions from the 1990 statewide emissions inventory achievable through implementation of all of the Clean Air Act-mandated and potentially broadly practicable control measures in all portions of the State in, or near and upwind of, any of the serious or severe ozone nonattainment areas lying in the series of such areas running northeast from the Washington, DC, ozone nonattainment area to and including the Portsmouth, New Hampshire ozone nonattainment area; and</P>
            <P>(ii) A reduction in VOC emissions from the 1990 emissions inventory in all such areas of 50% or whatever greater reduction is necessary to prevent significant contribution to nonattainment in, or interference with maintenance by, any downwind State.</P>
            <CITA>[60 FR 4736, Jan. 24, 1995]</CITA>
          </SECTION>
          <SECTION>
            <SECTNO>§ 51.121</SECTNO>
            <SUBJECT>Findings and requirements for submission of State implementation plan revisions relating to emissions of oxides of nitrogen.</SUBJECT>

            <P>(a)(1) The Administrator finds that the State implementation plan (SIP) for each jurisdiction listed in paragraph (c) of this section is substantially inadequate to comply with the requirements of section 110(a)(2)(D)(i)(I) of the Clean Air Act <PRTPAGE P="145"/>(CAA), 42 U.S.C. 7410(a)(2)(D)(i)(I), because the SIP does not include adequate provisions to prohibit sources and other activities from emitting nitrogen oxides (“NO<E T="52">X</E>”) in amounts that will contribute significantly to nonattainment in one or more other States with respect to the 1-hour ozone national ambient air quality standards (NAAQS). Each of the jurisdictions listed in paragraph (c) of this section must submit to EPA a SIP revision that cures the inadequacy.</P>

            <P>(2) Under section 110(a)(1) of the CAA, 42 U.S.C. 7410(a)(1), the Administrator determines that each jurisdiction listed in paragraph (c) of this section must submit a SIP revision to comply with the requirements of section 110(a)(2)(D)(i)(I), 42 U.S.C. 7410(a)(2)(D)(i)(I), through the adoption of adequate provisions prohibiting sources and other activities from emitting NO<E T="52">X</E> in amounts that will contribute significantly to nonattainment in, or interfere with maintenance by, one or more other States with respect to the 8-hour ozone NAAQS.</P>

            <P>(3)(i) For purposes of this section, the term “Phase I SIP Submission” means those SIP revisions submitted by States on or before October 30, 2000 in compliance with paragraph (b)(1)(ii) of this section. A State's Phase I SIP submission may include portions of the NO<E T="52">X</E> budget, under paragraph (e)(3) of this section, that a State is required to include in a Phase II SIP submission.</P>

            <P>(ii) For purposes of this section, the term “Phase II SIP Submission” means those SIP revisions that must be submitted by a State in compliance with paragraph (b)(1)(ii) of this section and which includes portions of the NO<E T="52">X</E> budget under paragraph (e)(3) of this section.</P>
            <P>(b)(1) For each jurisdiction listed in paragraph (c) of this section, the SIP revision required under paragraph (a) of this section will contain adequate provisions, for purposes of complying with section 110(a)(2)(D)(i)(I) of the CAA, 42 U.S.C. 7410(a)(2)(D)(i)(I), only if the SIP revision:</P>

            <P>(i) Contains control measures adequate to prohibit emissions of NO<E T="52">X</E> that would otherwise be projected, in accordance with paragraph (g) of this section, to cause the jurisdiction's overall NO<E T="52">X</E> emissions to be in excess of the budget for that jurisdiction described in paragraph (e) of this section (except as provided in paragraph (b)(2) of this section),</P>
            <P>(ii) Requires full implementation of all such control measures by no later than May 31, 2004 for the sources covered by a Phase I SIP submission and May 1, 2007 for the sources covered by a Phase II SIP submission.</P>
            <P>(iii) Meets the other requirements of this section. The SIP revision's compliance with the requirement of paragraph (b)(1)(i) of this section shall be considered compliance with the jurisdiction's budget for purposes of this section.</P>
            <P>(2) The requirements of paragraph (b)(1)(i) of this section shall be deemed satisfied, for the portion of the budget covered by an interstate trading program, if the SIP revision:</P>

            <P>(i) Contains provisions for an interstate trading program that EPA determines will, in conjunction with interstate trading programs for one or more other jurisdictions, prohibit NO<E T="52">X</E> emissions in excess of the sum of the portion of the budgets covered by the trading programs for those jurisdictions; and</P>
            <P>(ii) Conforms to the following criteria:</P>
            <P>(A) Emissions reductions used to demonstrate compliance with the revision must occur during the ozone season.</P>
            <P>(B) Emissions reductions occurring prior to the first year in which any sources covered by Phase I or Phase II SIP submission are subject to control measures under paragraph (b)(1)(i) of this section may be used by a source to demonstrate compliance with the SIP revision for the first and second ozone seasons in which any sources covered by a Phase I or Phase II SIP submission are subject to such control measures, provided the SIPs provisions regarding such use comply with the requirements of paragraph (e)(4) of this section.</P>

            <P>(C) Emissions reductions credits or emissions allowances held by a source or other person following the first <PRTPAGE P="146"/>ozone season in which any sources covered by a Phase I or Phase II SIP submission are subject to control measures under paragraph (b)(1)(i) of this section or any ozone season thereafter that are not required to demonstrate compliance with the SIP for the relevant ozone season may be banked and used to demonstrate compliance with the SIP in a subsequent ozone season.</P>
            <P>(D) Early reductions created according to the provisions in paragraph (b)(2)(ii)(B) of this section and used in the first ozone season in which any sources covered by Phase I or Phase II submissions are subject to the control measures under paragraph (b)(1)(i) of this section are not subject to the flow control provisions set forth in paragraph (b)(2)(ii)(E) of this section.</P>
            <P>(E) Starting with the second ozone season in which any sources covered by a Phase I or Phase II SIP submission are subject to control measures under paragraph (b)(1)(i) of this section, the SIP shall include provisions to limit the use of banked emissions reductions credits or emissions allowances beyond a predetermined amount as calculated by one of the following approaches:</P>
            <P>(<E T="03">1</E>) Following the determination of compliance after each ozone season, if the total number of emissions reduction credits or banked allowances held by sources or other persons subject to the trading program exceeds 10 percent of the sum of the allowable ozone season NO<E T="52">X</E> emissions for all sources subject to the trading program, then all banked allowances used for compliance for the following ozone season shall be subject to the following:</P>
            <P>(<E T="03">i</E>) A ratio will be established according to the following formula: (0.10) × (the sum of the allowable ozone season NO<E T="52">X</E> emissions for all sources subject to the trading program) ÷ (the total number of banked emissions reduction credits or emissions allowances held by all sources or other persons subject to the trading program).</P>
            <P>(<E T="03">ii</E>) The ratio, determined using the formula specified in paragraph (b)(2)(ii)(E)(1)(i) of this section, will be multiplied by the number of banked emissions reduction credits or emissions allowances held in each account at the time of compliance determination. The resulting product is the number of banked emissions reduction credits or emissions allowances in the account which can be used in the current year's ozone season at a rate of 1 credit or allowance for every 1 ton of emissions. The SIP shall specify that banked emissions reduction credits or emissions allowances in excess of the resulting product either may not be used for compliance, or may only be used for compliance at a rate no less than 2 credits or allowances for every 1 ton of emissions.</P>
            <P>(<E T="03">2</E>) At the time of compliance determination for each ozone season, if the total number of banked emissions reduction credits or emissions allowances held by a source subject to the trading program exceeds 10 percent of the source's allowable ozone season NO<E T="52">X</E> emissions, all banked emissions reduction credits or emissions allowances used for compliance in such ozone season by the source shall be subject to the following:</P>
            <P>(<E T="03">i</E>) The source may use an amount of banked emissions reduction credits or emissions allowances not greater than 10 percent of the source's allowable ozone season NO<E T="52">X</E> emissions for compliance at a rate of 1 credit or allowance for every 1 ton of emissions.</P>
            <P>(<E T="03">ii</E>) The SIP shall specify that banked emissions reduction credits or emissions allowances in excess of 10 percent of the source's allowable ozone season NO<E T="52">X</E> emissions may not be used for compliance, or may only be used for compliance at a rate no less than 2 credits or allowances for every 1 ton of emissions.</P>
            <P>(c) The following jurisdictions (hereinafter referred to as “States”) are subject to the requirement of this section:</P>
            <P>(1) With respect to the 1-hour ozone NAAQS: Connecticut, Delaware, Illinois, Indiana, Kentucky, Maryland, Massachusetts, New Jersey, New York, North Carolina, Ohio, Pennsylvania, Rhode Island, South Carolina, Tennessee, Virginia, West Virginia, and the District of Columbia.</P>

            <P>(2) With respect to the 1-hour ozone NAAQS, the portions of Missouri, Michigan, Alabama, and Georgia within the fine grid of the OTAG modeling domain. The fine grid is the area encompassed by a box with the following <PRTPAGE P="147"/>geographic coordinates: Southwest Corner, 92 degrees West longitude and 32 degrees North latitude; and Northeast Corner, 69.5 degrees West longitude and 44 degrees North latitude.</P>
            <P>(d)(1) The SIP submissions required under paragraph (a) of this section must be submitted to EPA by no later than October 30, 2000 for Phase I SIP submissions and no later than April 1, 2005 for Phase II SIP submissions.</P>
            <P>(2) The State makes an official submission of its SIP revision to EPA only when:</P>
            <P>(i) The submission conforms to the requirements of appendix V to this part; and</P>
            <P>(ii) The State delivers five copies of the plan to the appropriate Regional Office, with a letter giving notice of such action.</P>

            <P>(e)(1) Except as provided in paragraph (e)(2)(ii) of this section, the NO<E T="52">X</E> budget for a State listed in paragraph (c) of this section is defined as the total amount of NO<E T="52">X</E> emissions from all sources in that State, as indicated in paragraph (e)(2)(i) of this section with respect to that State, which the State must demonstrate that it will not exceed in the 2007 ozone season pursuant to paragraph (g)(1) of this section.</P>
            <P>(2)(i) The State-by-State amounts of the NO<E T="52">X</E> budget, expressed in tons, are as follows:</P>
            <GPOTABLE CDEF="s25,13" COLS="2" OPTS="L2">
              <BOXHD>
                <CHED H="1">State</CHED>
                <CHED H="1">Final budget</CHED>
                <CHED H="1">Budget</CHED>
              </BOXHD>
              <ROW>
                <ENT I="01">Alabama</ENT>
                <ENT>119,827</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Connecticut</ENT>
                <ENT>42,850</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Delaware</ENT>
                <ENT>22,862</ENT>
              </ROW>
              <ROW>
                <ENT I="01">District of Columbia</ENT>
                <ENT>6,657</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Georgia</ENT>
                <ENT>150,656</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Illinois</ENT>
                <ENT>271,091</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Indiana</ENT>
                <ENT>230,381</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Kentucky</ENT>
                <ENT>162,519</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Maryland</ENT>
                <ENT>81,947</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Massachusetts</ENT>
                <ENT>84,848</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Michigan</ENT>
                <ENT>190,908</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Missouri</ENT>
                <ENT>61,406</ENT>
              </ROW>
              <ROW>
                <ENT I="01">New Jersey</ENT>
                <ENT>96,876</ENT>
              </ROW>
              <ROW>
                <ENT I="01">New York</ENT>
                <ENT>240,322</ENT>
              </ROW>
              <ROW>
                <ENT I="01">North Carolina</ENT>
                <ENT>165,306</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Ohio</ENT>
                <ENT>249,541</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Pennsylvania</ENT>
                <ENT>257,928</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Rhode Island</ENT>
                <ENT>9,378</ENT>
              </ROW>
              <ROW>
                <ENT I="01">South Carolina</ENT>
                <ENT>123,496</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Tennessee</ENT>
                <ENT>198,286</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Virginia</ENT>
                <ENT>180,521</ENT>
              </ROW>
              <ROW RUL="n,s">
                <ENT I="01">West Virginia</ENT>
                <ENT>83,921</ENT>
              </ROW>
              <ROW>
                <ENT I="02">Total</ENT>
                <ENT>$3,031,527</ENT>
              </ROW>
            </GPOTABLE>

            <P>(ii) (A) For purposes of paragraph (e)(2)(i) of this section, in the case of each State listed in paragraphs (e)(2)(ii)(B) through (E) of this section, the NO<E T="52">X</E> budget is defined as the total amount of NO<E T="52">X</E> emissions from all sources in the specified counties in that State, as indicated in paragraph (e)(2)(i) of this section with respect to the State, which the State must demonstrate that it will not exceed in the 2007 ozone season pursuant to paragraph (g)(1) of this section.</P>
            <P>(B) In the case of Alabama, the counties are: Autauga, Bibb, Blount, Calhoun, Chambers, Cherokee, Chilton, Clay, Cleburne, Colbert, Coosa, Cullman, Dallas, De Kalb, Elmore, Etowah, Fayette, Franklin, Greene, Hale, Jackson, Jefferson, Lamar, Lauderdale, Lawrence, Lee, Limestone, Macon, Madison, Marion, Marshall, Morgan, Perry, Pickens, Randolph, Russell, St. Clair, Shelby, Sumter, Talladega, Tallapoosa, Tuscaloosa, Walker, and Winston.</P>
            <P>(C) In the case of Georgia, the counties are: Baldwin, Banks, Barrow, Bartow, Bibb, Bleckley, Bulloch, Burke, Butts, Candler, Carroll, Catoosa, Chattahoochee, Chattooga, Cherokee, Clarke, Clayton, Cobb, Columbia, Coweta, Crawford, Dade, Dawson, De Kalb, Dooly, Douglas, Effingham, Elbert, Emanuel, Evans, Fannin, Fayette, Floyd, Forsyth, Franklin, Fulton, Gilmer, Glascock, Gordon, Greene, Gwinnett, Habersham, Hall, Hancock, Haralson, Harris, Hart, Heard, Henry, Houston, Jackson, Jasper, Jefferson, Jenkins, Johnson, Jones, Lamar, Laurens, Lincoln, Lumpkin, McDuffie, Macon, Madison, Marion, Meriwether, Monroe, Morgan, Murray, Muscogee, Newton, Oconee, Oglethorpe, Paulding, Peach, Pickens, Pike, Polk, Pulaski, Putnam, Rabun, Richmond, Rockdale, Schley, Screven, Spalding, Stephens, Talbot, Taliaferro, Taylor, Towns, Treutlen, Troup, Twiggs, Union, Upson, Walker, Walton, Warren, Washington, White, Whitfield, Wilkes, and Wilkinson.</P>

            <P>(D) In the case of Michigan, the counties are: Allegan, Barry, Bay, Berrien, Branch, Calhoun, Cass, Clinton, Eaton, Genesee, Gratiot, Hillsdale, Ingham, Ionia, Isabella, Jackson, Kalamazoo, Kent, Lapeer, Lenawee, Livingston, Macomb, Mecosta, Midland, Monroe, Montcalm, Muskegon, Newaygo, Oakland, Oceana, Ottawa, Saginaw, St. <PRTPAGE P="148"/>Clair, St. Joseph, Sanilac, Shiawassee, Tuscola, Van Buren, Washtenaw, and Wayne.</P>
            <P>(E) In the case of Missouri, the counties are: Bollinger, Butler, Cape Girardeau, Carter, Clark, Crawford, Dent, Dunklin, Franklin, Gasconade, Iron, Jefferson, Lewis, Lincoln, Madison, Marion, Mississippi, Montgomery, New Madrid, Oregon, Pemiscot, Perry, Pike, Ralls, Reynolds, Ripley, St. Charles, St. Genevieve, St. Francois, St. Louis, St. Louis City, Scott, Shannon, Stoddard, Warren, Washington, and Wayne.</P>
            <P>(3) The State-by-State amounts of the portion of the NO<E T="52">X</E> budget provided in paragraph (e)(1) of this section, expressed in tons, that the States may include in a Phase II SIP submission are as follows:</P>
            <GPOTABLE CDEF="s25,13" COLS="2" OPTS="L2">
              <BOXHD>
                <CHED H="1">State</CHED>
                <CHED H="1">Phase II incremental budget</CHED>
              </BOXHD>
              <ROW>
                <ENT I="01">Alabama</ENT>
                <ENT>4,968</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Connecticut</ENT>
                <ENT>41</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Delaware</ENT>
                <ENT>660</ENT>
              </ROW>
              <ROW>
                <ENT I="01">District of Columbia</ENT>
                <ENT>1</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Illinois</ENT>
                <ENT>7,055</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Indiana</ENT>
                <ENT>4,244</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Kentucky</ENT>
                <ENT>2,556</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Maryland</ENT>
                <ENT>780</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Massachusetts</ENT>
                <ENT>1,023</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Michigan</ENT>
                <ENT>1,033</ENT>
              </ROW>
              <ROW>
                <ENT I="01">New Jersey</ENT>
                <ENT>−994</ENT>
              </ROW>
              <ROW>
                <ENT I="01">New York</ENT>
                <ENT>1,659</ENT>
              </ROW>
              <ROW>
                <ENT I="01">North Carolina</ENT>
                <ENT>6,026</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Ohio</ENT>
                <ENT>2,741</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Pennsylvania</ENT>
                <ENT>10,230</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Rhode Island</ENT>
                <ENT>192</ENT>
              </ROW>
              <ROW>
                <ENT I="01">South Carolina</ENT>
                <ENT>4,260</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Tennessee</ENT>
                <ENT>2,877</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Virginia</ENT>
                <ENT>6,168</ENT>
              </ROW>
              <ROW RUL="n,s">
                <ENT I="01">West Virginia</ENT>
                <ENT>1,124</ENT>
              </ROW>
              <ROW>
                <ENT I="03">Total</ENT>
                <ENT>56,644</ENT>
              </ROW>
            </GPOTABLE>

            <P>(4)(i) Notwithstanding the State's obligation to comply with the budgets set forth in paragraph (e)(2) of this section, a SIP revision may allow sources required by the revision to implement NO<E T="52">X</E> emission control measures to demonstrate compliance in the first and second ozone seasons in which any sources covered by a Phase I or Phase II SIP submission are subject to control measures under paragraph (b)(1)(i) of this section using credit issued from the State's compliance supplement pool, as set forth in paragraph (e)(4)(iii) of this section.</P>
            <P>(ii) A source may not use credit from the compliance supplement pool to demonstrate compliance after the second ozone season in which any sources are covered by a Phase I or Phase II SIP submission.</P>
            <P>(iii) The State-by-State amounts of the compliance supplement pool are as follows:</P>
            <GPOTABLE CDEF="s25,13" COLS="2" OPTS="L2">
              <BOXHD>
                <CHED H="1">State</CHED>
                <CHED H="1">Compliance<LI>supplement pool</LI>
                  <LI>(tons of NO<E T="52">X</E>)</LI>
                </CHED>
              </BOXHD>
              <ROW>
                <ENT I="01">Alabama</ENT>
                <ENT>8,962</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Connecticut</ENT>
                <ENT>569</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Delaware</ENT>
                <ENT>168</ENT>
              </ROW>
              <ROW>
                <ENT I="01">District of Columbia</ENT>
                <ENT>0</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Georgia</ENT>
                <ENT>10,728</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Illinois</ENT>
                <ENT>17,688</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Indiana</ENT>
                <ENT>19,915</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Kentucky</ENT>
                <ENT>13,520</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Maryland</ENT>
                <ENT>3,882</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Massachusetts</ENT>
                <ENT>404</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Michigan</ENT>
                <ENT>9,907</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Missouri</ENT>
                <ENT>5,630</ENT>
              </ROW>
              <ROW>
                <ENT I="01">New Jersey</ENT>
                <ENT>1,550</ENT>
              </ROW>
              <ROW>
                <ENT I="01">New York</ENT>
                <ENT>2,764</ENT>
              </ROW>
              <ROW>
                <ENT I="01">North Carolina</ENT>
                <ENT>10,737</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Ohio</ENT>
                <ENT>22,301</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Pennsylvania</ENT>
                <ENT>15,763</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Rhode Island</ENT>
                <ENT>15</ENT>
              </ROW>
              <ROW>
                <ENT I="01">South Carolina</ENT>
                <ENT>5,344</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Tennessee</ENT>
                <ENT>10,565</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Virginia</ENT>
                <ENT>5,504</ENT>
              </ROW>
              <ROW RUL="n,s">
                <ENT I="01">West Virginia</ENT>
                <ENT>16,709</ENT>
              </ROW>
              <ROW>
                <ENT I="02">Total</ENT>
                <ENT>182,625</ENT>
              </ROW>
            </GPOTABLE>
            <P>(iv) The SIP revision may provide for the distribution of the compliance supplement pool to sources that are required to implement control measures using one or both of the following two mechanisms:</P>
            <P>(A) The State may issue some or all of the compliance supplement pool to sources that implement emissions reductions during the ozone season beyond all applicable requirements in the first ozone season in which any sources covered by a Phase I or Phase II SIP submission are subject to control measures under paragraph (b)(1)(i) of this section.</P>
            <P>(<E T="03">1</E>) The State shall complete the issuance process by no later than the commencement of the first ozone season in which any sources covered by a Phase I or Phase II SIP submission are subject to control measures under paragraph (b)(1)(i) of this section.</P>
            <P>(<E T="03">2</E>) The emissions reduction may not be required by the State's SIP or be otherwise required by the CAA.<PRTPAGE P="149"/>
            </P>
            <P>(<E T="03">3</E>) The emissions reductions must be verified by the source as actually having occurred during an ozone season between September 30, 1999 and the commencement of the first ozone season in which any sources covered by a Phase I or Phase II SIP submission are subject to control measures under paragraph (b)(1)(i) of this section.</P>
            <P>(<E T="03">4</E>) The emissions reduction must be quantified according to procedures set forth in the SIP revision and approved by EPA. Emissions reductions implemented by sources serving electric generators with a nameplate capacity greater than 25 MWe, or boilers, combustion turbines or combined cycle units with a maximum design heat input greater than 250 mmBtu/hr, must be quantified according to the requirements in paragraph (i)(4) of this section.</P>
            <P>(<E T="03">5</E>) If the SIP revision contains approved provisions for an emissions trading program, sources that receive credit according to the requirements of this paragraph may trade the credit to other sources or persons according to the provisions in the trading program.</P>
            <P>(B) The State may issue some or all of the compliance supplement pool to sources that demonstrate a need for an extension of the earliest date on which any sources covered by a Phase I or Phase II SIP submission are subject to control measures under paragraph (b)(1)(i) of this section according to the following provisions:</P>
            <P>(<E T="03">1</E>) The State shall initiate the issuance process by the later date of September 30 before the first ozone season in which any sources covered by a Phase I or Phase II SIP submission are subject to control measures under paragraph (b)(1)(i) of this section or after the State issues credit according to the procedures in paragraph (e)(4)(iv)(A) of this section.</P>
            <P>(<E T="03">2</E>) The State shall complete the issuance process by no later than the commencement of the first ozone season in which any sources covered by a Phase I or Phase II SIP submission are subject to control measures under paragraph (b)(1)(i) of this section.</P>
            <P>(<E T="03">3</E>) The State shall issue credit to a source only if the source demonstrates the following:</P>
            <P>(<E T="03">i</E>) For a source used to generate electricity, compliance with the SIP revision's applicable control measures by the commencement of the first ozone season in which any sources covered by a Phase I or Phase II SIP submission are subject to control measures under paragraph (b)(1)(i) of this section, would create undue risk for the reliability of the electricity supply. This demonstration must include a showing that it would not be feasible to import electricity from other electricity generation systems during the installation of control technologies necessary to comply with the SIP revision.</P>
            <P>(<E T="03">ii</E>) For a source not used to generate electricity, compliance with the SIP revision's applicable control measures by the commencement of the first ozone season in which any sources covered by a Phase I or Phase II SIP submission are subject to control measures under paragraph (b)(1)(i) of this section would create undue risk for the source or its associated industry to a degree that is comparable to the risk described in paragraph (e)(4)(iv)(B)(<E T="03">3</E>)(<E T="03">i</E>) of this section.</P>
            <P>(<E T="03">iii</E>) For a source subject to an approved SIP revision that allows for early reduction credits in accordance with paragraph (e)(4)(iv)(A) of this section, it was not possible for the source to comply with applicable control measures by generating early reduction credits or acquiring early reduction credits from other sources.</P>
            <P>(<E T="03">iv</E>) For a source subject to an approved emissions trading program, it was not possible to comply with applicable control measures by acquiring sufficient credit from other sources or persons subject to the emissions trading program.</P>
            <P>(<E T="03">4</E>) The State shall ensure the public an opportunity, through a public hearing process, to comment on the appropriateness of allocating compliance supplement pool credits to a source under paragraph (e)(3)(iv)(B) of this section.</P>

            <P>(5) If, no later than February 22, 1999, any member of the public requests revisions to the source-specific data and vehicle miles traveled (VMT) and nonroad mobile growth rates, VMT distribution by vehicle class, average speed by roadway type, inspection and <PRTPAGE P="150"/>maintenance program parameters, and other input parameters used to establish the State budgets set forth in paragraph (e)(2) of this section or the 2007 baseline sub-inventory information set forth in paragraph (g)(2)(ii) of this section, then EPA will act on that request no later than April 23, 1999 provided:</P>
            <P>(i) The request is submitted in electronic format;</P>
            <P>(ii) Information is provided to corroborate and justify the need for the requested modification;</P>
            <P>(iii) The request includes the following data information regarding any electricity-generating source at issue:</P>
            <P>(A) Federal Information Placement System (FIPS) State Code;</P>
            <P>(B) FIPS County Code;</P>
            <P>(C) Plant name;</P>
            <P>(D) Plant ID numbers (ORIS code preferred, State agency tracking number also or otherwise);</P>
            <P>(E) Unit ID numbers (a unit is a boiler or other combustion device);</P>
            <P>(F) Unit type;</P>
            <P>(G) Primary fuel on a heat input basis;</P>
            <P>(H) Maximum rated heat input capacity of unit;</P>
            <P>(I) Nameplate capacity of the largest generator the unit serves;</P>
            <P>(J) Ozone season heat inputs for the years 1995 and 1996;</P>
            <P>(K) 1996 (or most recent) average NO<E T="52">X</E> rate for the ozone season;</P>
            <P>(L) Latitude and longitude coordinates;</P>
            <P>(M) Stack parameter information ;</P>
            <P>(N) Operating parameter information;</P>
            <P>(O) Identification of specific change to the inventory; and</P>
            <P>(P) Reason for the change;</P>
            <P>(iv) The request includes the following data information regarding any non-electricity generating point source at issue:</P>
            <P>(A) FIPS State Code;</P>
            <P>(B) FIPS County Code;</P>
            <P>(C) Plant name;</P>
            <P>(D) Facility primary standard industrial classification code (SIC);</P>
            <P>(E) Plant ID numbers (NEDS, AIRS/AFS, and State agency tracking number also or otherwise);</P>
            <P>(F) Unit ID numbers (a unit is a boiler or other combustion device);</P>
            <P>(G) Primary source classification code (SCC);</P>
            <P>(H) Maximum rated heat input capacity of unit;</P>
            <P>(I) 1995 ozone season or typical ozone season daily NO<E T="52">X</E> emissions;</P>
            <P>(J) 1995 existing NO<E T="52">X</E> control efficiency;</P>
            <P>(K) Latitude and longitude coordinates;</P>
            <P>(L) Stack parameter information;</P>
            <P>(M) Operating parameter information;</P>
            <P>(N) Identification of specific change to the inventory; and</P>
            <P>(O) Reason for the change;</P>
            <P>(v) The request includes the following data information regarding any stationary area source or nonroad mobile source at issue:</P>
            <P>(A) FIPS State Code;</P>
            <P>(B) FIPS County Code;</P>
            <P>(C) Primary source classification code (SCC);</P>
            <P>(D) 1995 ozone season or typical ozone season daily NO<E T="52">X</E> emissions;</P>
            <P>(E) 1995 existing NO<E T="52">X</E> control efficiency;</P>
            <P>(F) Identification of specific change to the inventory; and</P>
            <P>(G) Reason for the change;</P>
            <P>(vi) The request includes the following data information regarding any highway mobile source at issue:</P>
            <P>(A) FIPS State Code;</P>
            <P>(B) FIPS County Code;</P>
            <P>(C) Primary source classification code (SCC) or vehicle type;</P>
            <P>(D) 1995 ozone season or typical ozone season daily vehicle miles traveled (VMT);</P>
            <P>(E) 1995 existing NO<E T="52">X</E> control programs;</P>
            <P>(F) identification of specific change to the inventory; and</P>
            <P>(G) reason for the change.</P>

            <P>(f) Each SIP revision must set forth control measures to meet the NO<E T="52">X</E> budget in accordance with paragraph (b)(1)(i) of this section, which include the following:</P>
            <P>(1) A description of enforcement methods including, but not limited to:</P>
            <P>(i) Procedures for monitoring compliance with each of the selected control measures;</P>
            <P>(ii) Procedures for handling violations; and<PRTPAGE P="151"/>
            </P>
            <P>(iii) A designation of agency responsibility for enforcement of implementation.</P>

            <P>(2) Should a State elect to impose control measures on fossil fuel-fired NO<E T="52">X</E> sources serving electric generators with a nameplate capacity greater than 25 MWe or boilers, combustion turbines or combined cycle units with a maximum design heat input greater than 250 mmBtu/hr as a means of meeting its NO<E T="52">X</E> budget, then those measures must:</P>
            <P>(i)(A) Impose a NO<E T="52">X</E> mass emissions cap on each source;</P>
            <P>(B) Impose a NO<E T="52">X</E> emissions rate limit on each source and assume maximum operating capacity for every such source for purposes of estimating mass NO<E T="52">X</E> emissions; or</P>

            <P>(C) Impose any other regulatory requirement which the State has demonstrated to EPA provides equivalent or greater assurance than options in paragraphs (f)(2)(i)(A) or (f)(2)(i)(B) of this section that the State will comply with its NO<E T="52">X</E> budget in the 2007 ozone season; and</P>

            <P>(ii) Impose enforceable mechanisms, in accordance with paragraphs (b)(1) (i) and (ii) of this section, to assure that collectively all such sources, including new or modified units, will not exceed in the 2007 ozone season the total NO<E T="52">X</E> emissions projected for such sources by the State pursuant to paragraph (g) of this section.</P>

            <P>(3) For purposes of paragraph (f)(2) of this section, the term “fossil fuel-fired” means, with regard to a NO<E T="52">X</E> source:</P>

            <P>(i) The combustion of fossil fuel, alone or in combination with any other fuel, where fossil fuel actually combusted comprises more than 50 percent of the annual heat input on a Btu basis during any year starting in 1995 or, if a NO<E T="52">X</E> source had no heat input starting in 1995, during the last year of operation of the NO<E T="52">X</E> source prior to 1995; or</P>

            <P>(ii) The combustion of fossil fuel, alone or in combination with any other fuel, where fossil fuel is projected to comprise more than 50 percent of the annual heat input on a Btu basis during any year; provided that the NO<E T="52">X</E> source shall be “fossil fuel-fired” as of the date, during such year, on which the NO<E T="52">X</E> source begins combusting fossil fuel.</P>

            <P>(g)(1) Each SIP revision must demonstrate that the control measures contained in it are adequate to provide for the timely compliance with the State's NO<E T="52">X</E> budget during the 2007 ozone season.</P>
            <P>(2) The demonstration must include the following:</P>

            <P>(i) Each revision must contain a detailed baseline inventory of NO<E T="52">X</E> mass emissions from the following sources in the year 2007, absent the control measures specified in the SIP submission: electric generating units (EGU), non-electric generating units (non-EGU), area, nonroad and highway sources. The State must use the same baseline emissions inventory that EPA used in calculating the State's NO<E T="52">X</E> budget, as set forth for the State in paragraph (g)(2)(ii) of this section, except that EPA may direct the State to use different baseline inventory information if the State fails to certify that it has implemented all of the control measures assumed in developing the baseline inventory.</P>
            <P>(ii) The revised NO<E T="52">X</E> emissions sub-inventories for each State, expressed in tons per ozone season, are as follows:</P>
            <GPOTABLE CDEF="s10,9,7,7,7,9,9" COLS="7" OPTS="L2">
              <BOXHD>
                <CHED H="1">State</CHED>
                <CHED H="1">EGU</CHED>
                <CHED H="1">Non-EGU</CHED>
                <CHED H="1">Area</CHED>
                <CHED H="1">Nonroad</CHED>
                <CHED H="1">Highway</CHED>
                <CHED H="1">Total</CHED>
              </BOXHD>
              <ROW>
                <ENT I="01">Alabama</ENT>
                <ENT>29,022</ENT>
                <ENT>43,415</ENT>
                <ENT>28,762</ENT>
                <ENT>20,146</ENT>
                <ENT>51,274</ENT>
                <ENT>172,619</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Connecticut</ENT>
                <ENT>2,652</ENT>
                <ENT>5,216</ENT>
                <ENT>4,821</ENT>
                <ENT>10,736</ENT>
                <ENT>19,424</ENT>
                <ENT>42,849</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Delaware</ENT>
                <ENT>5,250</ENT>
                <ENT>2,473</ENT>
                <ENT>1,129</ENT>
                <ENT>5,651</ENT>
                <ENT>8,358</ENT>
                <ENT>22,861</ENT>
              </ROW>
              <ROW>
                <ENT I="01">District of Columbia</ENT>
                <ENT>207</ENT>
                <ENT>282</ENT>
                <ENT>830</ENT>
                <ENT>3,135</ENT>
                <ENT>2,204</ENT>
                <ENT>6,658</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Georgia</ENT>
                <ENT>30,402</ENT>
                <ENT>29,716</ENT>
                <ENT>13,212</ENT>
                <ENT>26,467</ENT>
                <ENT>88,775</ENT>
                <ENT>188,572</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Illinois</ENT>
                <ENT>32,372</ENT>
                <ENT>59,577</ENT>
                <ENT>9,369</ENT>
                <ENT>56,724</ENT>
                <ENT>112,518</ENT>
                <ENT>270,560</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Indiana</ENT>
                <ENT>47,731</ENT>
                <ENT>47,363</ENT>
                <ENT>29,070</ENT>
                <ENT>26,494</ENT>
                <ENT>79,307</ENT>
                <ENT>229,965</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Kentucky</ENT>
                <ENT>36,503</ENT>
                <ENT>25,669</ENT>
                <ENT>31,807</ENT>
                <ENT>15,025</ENT>
                <ENT>53,268</ENT>
                <ENT>162,272</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Maryland</ENT>
                <ENT>14,656</ENT>
                <ENT>12,585</ENT>
                <ENT>4,448</ENT>
                <ENT>20,026</ENT>
                <ENT>30,183</ENT>
                <ENT>81,898</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Massachusetts</ENT>
                <ENT>15,146</ENT>
                <ENT>10,298</ENT>
                <ENT>11,048</ENT>
                <ENT>20,166</ENT>
                <ENT>28,190</ENT>
                <ENT>84,848</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Michigan</ENT>
                <ENT>32,228</ENT>
                <ENT>60,055</ENT>
                <ENT>31,721</ENT>
                <ENT>26,935</ENT>
                <ENT>78,763</ENT>
                <ENT>229,702</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Missouri</ENT>
                <ENT>24,216</ENT>
                <ENT>21,602</ENT>
                <ENT>7,341</ENT>
                <ENT>20,829</ENT>
                <ENT>51,615</ENT>
                <ENT>125,603</ENT>
              </ROW>
              <ROW>
                <ENT I="01">New Jersey</ENT>
                <ENT>10,250</ENT>
                <ENT>15,464</ENT>
                <ENT>12,431</ENT>
                <ENT>23,565</ENT>
                <ENT>35,166</ENT>
                <ENT>96,876</ENT>
              </ROW>
              <ROW>
                <ENT I="01">New York</ENT>
                <ENT>31,036</ENT>
                <ENT>25,477</ENT>
                <ENT>17,423</ENT>
                <ENT>42,091</ENT>
                <ENT>124,261</ENT>
                <ENT>240,288</ENT>
              </ROW>
              <ROW>
                <PRTPAGE P="152"/>
                <ENT I="01">North Carolina</ENT>
                <ENT>31,821</ENT>
                <ENT>26,434</ENT>
                <ENT>11,067</ENT>
                <ENT>22,005</ENT>
                <ENT>73,695</ENT>
                <ENT>165,022</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Ohio</ENT>
                <ENT>48,990</ENT>
                <ENT>40,194</ENT>
                <ENT>21,860</ENT>
                <ENT>43,380</ENT>
                <ENT>94,850</ENT>
                <ENT>249,274</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Pennsylvania</ENT>
                <ENT>47,469</ENT>
                <ENT>70,132</ENT>
                <ENT>17,842</ENT>
                <ENT>30,571</ENT>
                <ENT>91,578</ENT>
                <ENT>257,592</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Rhode Island</ENT>
                <ENT>997</ENT>
                <ENT>1,635</ENT>
                <ENT>448</ENT>
                <ENT>2,455</ENT>
                <ENT>3,843</ENT>
                <ENT>9,378</ENT>
              </ROW>
              <ROW>
                <ENT I="01">South Carolina</ENT>
                <ENT>16,772</ENT>
                <ENT>27,787</ENT>
                <ENT>9,415</ENT>
                <ENT>14,637</ENT>
                <ENT>54,494</ENT>
                <ENT>123,105</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Tennessee</ENT>
                <ENT>25,814</ENT>
                <ENT>39,636</ENT>
                <ENT>13,333</ENT>
                <ENT>52,920</ENT>
                <ENT>66,342</ENT>
                <ENT>198,045</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Virginia</ENT>
                <ENT>17,187</ENT>
                <ENT>35,216</ENT>
                <ENT>27,738</ENT>
                <ENT>27,859</ENT>
                <ENT>72,195</ENT>
                <ENT>180,195</ENT>
              </ROW>
              <ROW>
                <ENT I="01">West Virginia</ENT>
                <ENT>26,859</ENT>
                <ENT>20,238</ENT>
                <ENT>5,459</ENT>
                <ENT>10,433</ENT>
                <ENT>20,844</ENT>
                <ENT>83,833</ENT>
              </ROW>
              <ROW RUL="n,s">
                <ENT I="01">Wisconsin</ENT>
                <ENT>17,381</ENT>
                <ENT>19,853</ENT>
                <ENT>11,253</ENT>
                <ENT>17,965</ENT>
                <ENT>69,319</ENT>
                <ENT>135,771</ENT>
              </ROW>
              <ROW>
                <ENT I="03">Total</ENT>
                <ENT>544,961</ENT>
                <ENT>640,317</ENT>
                <ENT>321,827</ENT>
                <ENT>540,215</ENT>
                <ENT>1,310,466</ENT>
                <ENT>3,357,786</ENT>
              </ROW>
              <TNOTE>Note to paragraph (g)(2)(ii): Totals may not sum due to rounding.</TNOTE>
            </GPOTABLE>
            <P>(iii) Each revision must contain a summary of NO<E T="52">X</E> mass emissions in 2007 projected to result from implementation of each of the control measures specified in the SIP submission and from all NO<E T="52">X</E> sources together following implementation of all such control measures, compared to the baseline 2007 NO<E T="52">X</E> emissions inventory for the State described in paragraph (g)(2)(i) of this section. The State must provide EPA with a summary of the computations, assumptions, and judgments used to determine the degree of reduction in projected 2007 NO<E T="52">X</E> emissions that will be achieved from the implementation of the new control measures compared to the baseline emissions inventory.</P>
            <P>(iv) Each revision must identify the sources of the data used in the projection of emissions.</P>
            <P>(h) Each revision must comply with § 51.116 of this part (regarding data availability).</P>

            <P>(i) Each revision must provide for monitoring the status of compliance with any control measures adopted to meet the NO<E T="52">X</E> budget. Specifically, the revision must meet the following requirements:</P>
            <P>(1) The revision must provide for legally enforceable procedures for requiring owners or operators of stationary sources to maintain records of and periodically report to the State:</P>
            <P>(i) Information on the amount of NO<E T="52">X</E> emissions from the stationary sources; and</P>
            <P>(ii) Other information as may be necessary to enable the State to determine whether the sources are in compliance with applicable portions of the control measures;</P>
            <P>(2) The revision must comply with § 51.212 of this part (regarding testing, inspection, enforcement, and complaints);</P>
            <P>(3) If the revision contains any transportation control measures, then the revision must comply with § 51.213 of this part (regarding transportation control measures);</P>

            <P>(4) If the revision contains measures to control fossil fuel-fired NO<E T="52">X</E> sources serving electric generators with a nameplate capacity greater than 25 MWe or boilers, combustion turbines or combined cycle units with a maximum design heat input greater than 250 mmBtu/hr, then the revision must require such sources to comply with the monitoring provisions of part 75, subpart H.</P>

            <P>(5) For purposes of paragraph (i)(4) of this section, the term “fossil fuel-fired” means, with regard to a NO<E T="52">X</E> source:</P>

            <P>(i) The combustion of fossil fuel, alone or in combination with any other fuel, where fossil fuel actually combusted comprises more than 50 percent of the annual heat input on a Btu basis during any year starting in 1995 or, if a NO<E T="52">X</E> source had no heat input starting in 1995, during the last year of operation of the NO<E T="52">X</E> source prior to 1995; or</P>

            <P>(ii) The combustion of fossil fuel, alone or in combination with any other fuel, where fossil fuel is projected to comprise more than 50 percent of the annual heat input on a Btu basis during any year, provided that the NO<E T="52">X</E> source shall be “fossil fuel-fired” as of the date, during such year, on which the NO<E T="52">X</E> source begins combusting fossil fuel.<PRTPAGE P="153"/>
            </P>
            <P>(j) Each revision must show that the State has legal authority to carry out the revision, including authority to:</P>

            <P>(1) Adopt emissions standards and limitations and any other measures necessary for attainment and maintenance of the State's NO<E T="52">X</E> budget specified in paragraph (e) of this section;</P>
            <P>(2) Enforce applicable laws, regulations, and standards, and seek injunctive relief;</P>
            <P>(3) Obtain information necessary to determine whether air pollution sources are in compliance with applicable laws, regulations, and standards, including authority to require recordkeeping and to make inspections and conduct tests of air pollution sources;</P>
            <P>(4) Require owners or operators of stationary sources to install, maintain, and use emissions monitoring devices and to make periodic reports to the State on the nature and amounts of emissions from such stationary sources; also authority for the State to make such data available to the public as reported and as correlated with any applicable emissions standards or limitations.</P>
            <P>(k)(1) The provisions of law or regulation which the State determines provide the authorities required under this section must be specifically identified, and copies of such laws or regulations must be submitted with the SIP revision.</P>
            <P>(2) Legal authority adequate to fulfill the requirements of paragraphs (j)(3) and (4) of this section may be delegated to the State under section 114 of the CAA.</P>
            <P>(l)(1) A revision may assign legal authority to local agencies in accordance with § 51.232 of this part.</P>
            <P>(2) Each revision must comply with § 51.240 of this part (regarding general plan requirements).</P>
            <P>(m) Each revision must comply with § 51.280 of this part (regarding resources).</P>
            <P>(n) For purposes of the SIP revisions required by this section, EPA may make a finding as applicable under section 179(a)(1)-(4) of the CAA, 42 U.S.C. 7509(a)(1)-(4), starting the sanctions process set forth in section 179(a) of the CAA. Any such finding will be deemed a finding under § 52.31(c) of this part and sanctions will be imposed in accordance with the order of sanctions and the terms for such sanctions established in § 52.31 of this part.</P>
            <P>(o) Each revision must provide for State compliance with the reporting requirements set forth in § 51.122 of this part.</P>

            <P>(p)(1) Notwithstanding any other provision of this section, if a State adopts regulations substantively identical to 40 CFR part 96 (the model NO<E T="52">X</E> budget trading program for SIPs), incorporates such part by reference into its regulations, or adopts regulations that differ substantively from such part only as set forth in paragraph (p)(2) of this section, then that portion of the State's SIP revision is automatically approved as satisfying the same portion of the State's NO<E T="52">X</E> emission reduction obligations as the State projects such regulations will satisfy, provided that:</P>
            <P>(i) The State has the legal authority to take such action and to implement its responsibilities under such regulations, and</P>
            <P>(ii) The SIP revision accurately reflects the NO<E T="52">X</E> emissions reductions to be expected from the State's implementation of such regulations.</P>
            <P>(2) If a State adopts an emissions trading program that differs substantively from 40 CFR part 96 in only the following respects, then such portion of the State's SIP revision is approved as set forth in paragraph (p)(1) of this section:</P>
            <P>(i) The State may expand the applicability provisions of the trading program to include units (as defined in 40 CFR 96.2) that are smaller than the size criteria thresholds set forth in 40 CFR 96.4(a);</P>
            <P>(ii) The State may decline to adopt the exemption provisions set forth in 40 CFR 96.4(b);</P>
            <P>(iii) The State may decline to adopt the opt-in provisions set forth in subpart I of 40 CFR part 96;</P>

            <P>(iv) The State may decline to adopt the allocation provisions set forth in subpart E of 40 CFR part 96 and may instead adopt any methodology for allocating NO<E T="52">X</E> allowances to individual sources, provided that:</P>

            <P>(A) The State's methodology does not allow the State to allocate NO<E T="52">X</E> allowances in excess of the total amount of <PRTPAGE P="154"/>NO<E T="52">X</E> emissions which the State has assigned to its trading program; and</P>
            <P>(B) The State's methodology conforms with the timing requirements for submission of allocations to the Administrator set forth in 40 CFR 96.41; and</P>
            <P>(v) The State may decline to adopt the early reduction credit provisions set forth in 40 CFR 96.55(c) and may instead adopt any methodology for issuing credit from the State's compliance supplement pool that complies with paragraph (e)(3) of this section.</P>
            <P>(3) If a State adopts an emissions trading program that differs substantively from 40 CFR part 96 other than as set forth in paragraph (p)(2) of this section, then such portion of the State's SIP revision is not automatically approved as set forth in paragraph (p)(1) of this section but will be reviewed by the Administrator for approvability in accordance with the other provisions of this section.</P>
            <P>(q) <E T="03">Stay of Findings of Significant Contribution with respect to the 8-hour standard.</E> Notwithstanding any other provisions of this subpart, the effectiveness of paragraph (a)(2) of this section is stayed.</P>
            <P>(r)(1) Notwithstanding any provisions of paragraph (p) of this section, subparts A through I of part 96 of this chapter, and any State's SIP to the contrary, the Administrator will not carry out any of the functions set forth for the Administrator in subparts A through I of part 96 of this chapter, or in any emissions trading program in a State's SIP approved under paragraph (p) of this section, with regard to any ozone season that occurs after September 30, 2008.</P>

            <P>(2) Except as provided in § 51.123(bb), a State whose SIP is approved as meeting the requirements of this section and that includes an emissions trading program approved under paragraph (p) of this section must revise the SIP to adopt control measures that satisfy the same portion of the State's NO<E T="52">X</E> emission reduction requirements under this section as the State projected such emissions trading program would satisfy.</P>
            <P>(s) Stay of Finding of Significant Contribution with respect to the 1-hour standard. Notwithstanding any other provisions of this subpart, the effectiveness of paragraph (a)(1) of this section is stayed as it relates to the State of Georgia, only as of September 30, 2005.</P>
            <CITA>[63 FR 57491, Oct. 27, 1998, as amended at 63 FR 71225, Dec. 24, 1998; 64 FR 26305, May 14, 1999; 65 FR 11230, Mar. 2, 2000; 65 FR 56251, Sept. 18, 2000; 69 FR 21642, Apr. 21, 2004; 70 FR 25317, May 12, 2005; 70 FR 51597, Aug. 31, 2005]</CITA>
          </SECTION>
          <SECTION>
            <SECTNO>§ 51.122</SECTNO>

            <SUBJECT>Emissions reporting requirements for SIP revisions relating to budgets for NO<E T="52">X</E> emissions.</SUBJECT>

            <P>(a) For its transport SIP revision under § 51.121, each State must submit to EPA NO<E T="52">X</E> emissions data as described in this section.</P>

            <P>(b) Each revision must provide for periodic reporting by the State of NO<E T="52">X</E> emissions data to demonstrate whether the State's emissions are consistent with the projections contained in its approved SIP submission.</P>

            <P>(1) Annual reporting. Each revision must provide for annual reporting of NO<E T="52">X</E> emissions data as follows:</P>

            <P>(i) The State must report to EPA emissions data from all NO<E T="52">X</E> sources within the State for which the State specified control measures in its SIP submission under § 51.121(g) of this part. This would include all sources for which the State has adopted measures that differ from the measures incorporated into the baseline inventory for the year 2007 that the State developed in accordance with § 51.121(g).</P>
            <P>(ii) If sources report NO<E T="52">X</E> emissions data to EPA annually pursuant to a trading program approved under § 51.121(p) or pursuant to the monitoring and reporting requirements of subpart H of 40 CFR part 75, then the State need not provide annual reporting to EPA for such sources.</P>

            <P>(2) Triennial reporting. Each plan must provide for triennial (<E T="03">i.e.</E>, every third year) reporting of NO<E T="52">X</E> emissions data from all sources within the State.</P>
            <P>(3) The data availability requirements in § 51.116 must be followed for all data submitted to meet the requirements of paragraphs (b)(1) and (2) of this section.</P>

            <P>(c) The data reported in paragraph (b) of this section for stationary point sources must meet the following minimum criteria:<PRTPAGE P="155"/>
            </P>
            <P>(1) For annual data reporting purposes the data must include the following minimum elements:</P>
            <P>(i) Inventory year.</P>
            <P>(ii) State Federal Information Placement System code.</P>
            <P>(iii) County Federal Information Placement System code.</P>
            <P>(iv) Federal ID code (plant).</P>
            <P>(v) Federal ID code (point).</P>
            <P>(vi) Federal ID code (process).</P>
            <P>(vii) Federal ID code (stack).</P>
            <P>(viii) Site name.</P>
            <P>(ix) Physical address.</P>
            <P>(x) SCC.</P>
            <P>(xi) Pollutant code.</P>
            <P>(xii) Ozone season emissions.</P>
            <P>(xiii) Area designation.</P>
            <P>(2) In addition, the annual data must include the following minimum elements as applicable to the emissions estimation methodology.</P>
            <P>(i) Fuel heat content (annual).</P>
            <P>(ii) Fuel heat content (seasonal).</P>
            <P>(iii) Source of fuel heat content data.</P>
            <P>(iv) Activity throughput (annual).</P>
            <P>(v) Activity throughput (seasonal).</P>
            <P>(vi) Source of activity/throughput data.</P>
            <P>(vii) Spring throughput (%).</P>
            <P>(viii) Summer throughput (%).</P>
            <P>(ix) Fall throughput (%).</P>
            <P>(x) Work weekday emissions.</P>
            <P>(xi) Emission factor.</P>
            <P>(xii) Source of emission factor.</P>
            <P>(xiii) Hour/day in operation.</P>
            <P>(xiv) Operations Start time (hour).</P>
            <P>(xv) Day/week in operation.</P>
            <P>(xvi) Week/year in operation.</P>
            <P>(3) The triennial inventories must include the following data elements:</P>
            <P>(i) The data required in paragraphs (c)(1) and (c)(2) of this section.</P>
            <P>(ii) X coordinate (longitude).</P>
            <P>(iii) Y coordinate (latitude).</P>
            <P>(iv) Stack height.</P>
            <P>(v) Stack diameter.</P>
            <P>(vi) Exit gas temperature.</P>
            <P>(vii) Exit gas velocity.</P>
            <P>(viii) Exit gas flow rate.</P>
            <P>(ix) SIC.</P>
            <P>(x) Boiler/process throughput design capacity.</P>
            <P>(xi) Maximum design rate.</P>
            <P>(xii) Maximum capacity.</P>
            <P>(xiii) Primary control efficiency.</P>
            <P>(xiv) Secondary control efficiency.</P>
            <P>(xv) Control device type.</P>
            <P>(d) The data reported in paragraph (b) of this section for non-point sources must include the following minimum elements:</P>
            <P>(1) For annual inventories it must include:</P>
            <P>(i) Inventory year.</P>
            <P>(ii) State FIPS code.</P>
            <P>(iii) County FIPS code.</P>
            <P>(iv) SCC.</P>
            <P>(v) Emission factor.</P>
            <P>(vi) Source of emission factor.</P>
            <P>(vii) Activity/throughput level (annual).</P>
            <P>(viii) Activity throughput level (seasonal).</P>
            <P>(ix) Source of activity/throughput data.</P>
            <P>(x) Spring throughput (%).</P>
            <P>(xi) Summer throughput (%).</P>
            <P>(xii) Fall throughput (%).</P>
            <P>(xiii) Control efficiency (%).</P>
            <P>(xiv) Pollutant code.</P>
            <P>(xv) Ozone season emissions.</P>
            <P>(xvi) Source of emissions data.</P>
            <P>(xvii) Hour/day in operation.</P>
            <P>(xviii) Day/week in operation.</P>
            <P>(xix) Week/year in operations.</P>
            <P>(2) The triennial inventories must contain, at a minimum, all the data required in paragraph (d)(1) of this section.</P>
            <P>(e) The data reported in paragraph (b) of this section for mobile sources must meet the following minimum criteria:</P>
            <P>(1) For the annual and triennial inventory purposes, the following data must be reported:</P>
            <P>(i) Inventory year.</P>
            <P>(ii) State FIPS code.</P>
            <P>(iii) County FIPS code.</P>
            <P>(iv) SCC.</P>
            <P>(v) Emission factor.</P>
            <P>(vi) Source of emission factor.</P>

            <P>(vii) Activity (this must be reported for both highway and nonroad activity. Submit nonroad activity in the form of hours of activity at standard load (either full load or average load) for each engine type, application, and horsepower range. Submit highway activity in the form of vehicle miles traveled (VMT) by vehicle class on each roadway type. Report both highway and nonroad activity for a typical ozone season weekday day, if the State uses EPA's default weekday/weekend activity ratio. If the State uses a different weekday/weekend activity ratio, submit separate activity level information for weekday days and weekend days.)<PRTPAGE P="156"/>
            </P>
            <P>(viii) Source of activity data.</P>
            <P>(ix) Pollutant code.</P>
            <P>(x) Summer work weekday emissions.</P>
            <P>(xi) Ozone season emissions.</P>
            <P>(xii) Source of emissions data.</P>
            <P>(2) [Reserved]</P>
            <P>(f) Approval of ozone season calculation by EPA. Each State must submit for EPA approval an example of the calculation procedure used to calculate ozone season emissions along with sufficient information for EPA to verify the calculated value of ozone season emissions.</P>
            <P>(g) <E T="03">Reporting schedules.</E> (1) Data collection is to begin during the ozone season one year prior to the State's NO<E T="52">X</E> SIP Call compliance date.</P>
            <P>(2) Reports are to be submitted according to paragraph (b) of this section and the schedule in Table 1. After 2008, trienniel reports are to be submitted every third year and annual reports are to be submitted each year that a trienniel report is not required.</P>
            <GPOTABLE CDEF="s50,xs40" COLS="2" OPTS="L2">
              <TTITLE>Table 1—Schedule for Submitting Reports</TTITLE>
              <BOXHD>
                <CHED H="1">Data collection year</CHED>
                <CHED H="1">Type of<LI>report required</LI>
                </CHED>
              </BOXHD>
              <ROW>
                <ENT I="01">2002</ENT>
                <ENT>Trienniel.</ENT>
              </ROW>
              <ROW>
                <ENT I="01">2003</ENT>
                <ENT>Annual.</ENT>
              </ROW>
              <ROW>
                <ENT I="01">2004</ENT>
                <ENT>Annual.</ENT>
              </ROW>
              <ROW>
                <ENT I="01">2005</ENT>
                <ENT>Trienniel.</ENT>
              </ROW>
              <ROW>
                <ENT I="01">2006</ENT>
                <ENT>Annual.</ENT>
              </ROW>
              <ROW>
                <ENT I="01">2007</ENT>
                <ENT>Annual.</ENT>
              </ROW>
              <ROW>
                <ENT I="01">2008</ENT>
                <ENT>Trienniel.</ENT>
              </ROW>
            </GPOTABLE>
            <P>(3) States must submit data for a required year no later than 12 months after the end of the calendar year for which the data are collected.</P>
            <P>(h) <E T="03">Data Reporting Procedures.</E> When submitting a formal NO<E T="52">X</E> budget emissions report and associated data, States shall notify the appropriate EPA Regional Office.</P>

            <P>(1) States are required to report emissions data in an electronic format to EPA. Several options are available for data reporting. States can obtain information on the current formats at the following Internet address: <E T="03">http://www.epa.gov/ttn/chief,</E> by calling the EPA Info CHIEF help desk at (919) 541-1000 or by sending an e-mail to <E T="03">info.chief@epa.gov.</E> Because electronic reporting technology continually changes, States are to contact the Emission Inventory Group (EIG) for the latest specific formats.</P>
            <P>(2) For annual reporting (not for triennial reports), a State may have sources submit the data directly to EPA to the extent the sources are subject to a trading program that qualifies for approval under § 51.121(q), and the State has agreed to accept data in this format. The EPA will make both the raw data submitted in this format and summary data available to any State that chooses this option.</P>
            <P>(i) <E T="03">Definitions.</E> As used in this section, the following words and terms shall have the meanings set forth below:</P>
            <P>(1) <E T="03">Annual emissions.</E> Actual emissions for a plant, point, or process, either measured or calculated.</P>
            <P>(2) <E T="03">Ash content.</E> Inert residual portion of a fuel.</P>
            <P>(3) <E T="03">Area designation.</E> The designation of the area in which the reporting source is located with regard to the ozone NAAQS. This would include attainment or nonattainment designations. For nonattainment designations, the classification of the nonattainment area must be specified, <E T="03">i.e.</E>, transitional, marginal, moderate, serious, severe, or extreme.</P>
            <P>(4) <E T="03">Boiler design capacity.</E> A measure of the size of a boiler, based on the reported maximum continuous steam flow. Capacity is calculated in units of MMBtu/hr.</P>
            <P>(5) <E T="03">Control device type.</E> The name of the type of control device (<E T="03">e.g.</E>, wet scrubber, flaring, or process change).</P>
            <P>(6) <E T="03">Control efficiency.</E> The emissions reduction efficiency of a primary control device, which shows the amount of reductions of a particular pollutant from a process's emissions due to controls or material change. Control efficiency is usually expressed as a percentage or in tenths.</P>
            <P>(7) <E T="03">Day/week in operations.</E> Days per week that the emitting process operates.</P>
            <P>(8) <E T="03">Emission factor.</E> Ratio relating emissions of a specific pollutant to an activity or material throughput level.</P>
            <P>(9) <E T="03">Exit gas flow rate.</E> Numeric value of stack gas flow rate.</P>
            <P>(10) <E T="03">Exit gas temperature.</E> Numeric value of an exit gas stream temperature.</P>
            <P>(11) <E T="03">Exit gas velocity.</E> Numeric value of an exit gas stream velocity.<PRTPAGE P="157"/>
            </P>
            <P>(12) <E T="03">Fall throughput (%).</E> Portion of throughput for the 3 fall months (September, October, November). This represents the expression of annual activity information on the basis of four seasons, typically spring, summer, fall, and winter. It can be represented either as a percentage of the annual activity (<E T="03">e.g.</E>, production in summer is 40 percent of the year's production), or in terms of the units of the activity (<E T="03">e.g.</E>, out of 600 units produced, spring = 150 units, summer = 250 units, fall = 150 units, and winter = 50 units).</P>
            <P>(13) <E T="03">Federal ID code (plant).</E> Unique codes for a plant or facility, containing one or more pollutant-emitting sources.</P>
            <P>(14) <E T="03">Federal ID code (point).</E> Unique codes for the point of generation of emissions, typically a physical piece of equipment.</P>
            <P>(15) <E T="03">Federal ID code (stack number).</E> Unique codes for the point where emissions from one or more processes are released into the atmosphere.</P>
            <P>(16) <E T="03">Federal Information Placement System (FIPS).</E> The system of unique numeric codes developed by the government to identify States, counties, towns, and townships for the entire United States, Puerto Rico, and Guam.</P>
            <P>(17) <E T="03">Heat content.</E> The thermal heat energy content of a solid, liquid, or gaseous fuel. Fuel heat content is typically expressed in units of Btu/lb of fuel, Btu/gal of fuel, joules/kg of fuel, etc.</P>
            <P>(18) <E T="03">Hr/day in operations.</E> Hours per day that the emitting process operates.</P>
            <P>(19) <E T="03">Maximum design rate.</E> Maximum fuel use rate based on the equipment's or process' physical size or operational capabilities.</P>
            <P>(20) <E T="03">Maximum nameplate capacity.</E> A measure of the size of a generator which is put on the unit's nameplate by the manufacturer. The data element is reported in megawatts (MW) or kilowatts (KW).</P>
            <P>(21) <E T="03">Mobile source.</E> A motor vehicle, nonroad engine or nonroad vehicle, where:</P>
            <P>(i) Motor vehicle means any self-propelled vehicle designed for transporting persons or property on a street or highway;</P>
            <P>(ii) Nonroad engine means an internal combustion engine (including the fuel system) that is not used in a motor vehicle or a vehicle used solely for competition, or that is not subject to standards promulgated under section 111 or section 202 of the CAA;</P>
            <P>(iii) Nonroad vehicle means a vehicle that is powered by a nonroad engine and that is not a motor vehicle or a vehicle used solely for competition.</P>
            <P>(22) <E T="03">Ozone season.</E> The period May 1 through September 30 of a year.</P>
            <P>(23) <E T="03">Physical address.</E> Street address of facility.</P>
            <P>(24) <E T="03">Point source.</E> A non-mobile source which emits 100 tons of NO<E T="52">X</E> or more per year unless the State designates as a point source a non-mobile source emitting at a specified level lower than 100 tons of NO<E T="52">X</E> per year. A non-mobile source which emits less NO<E T="52">X</E> per year than the point source threshold is a non-point source.</P>
            <P>(25) <E T="03">Pollutant code.</E> A unique code for each reported pollutant that has been assigned in the EIIP Data Model. Character names are used for criteria pollutants, while Chemical Abstracts Service (CAS) numbers are used for all other pollutants. Some States may be using storage and retrieval of aerometric data (SAROAD) codes for pollutants, but these should be able to be mapped to the EIIP Data Model pollutant codes.</P>
            <P>(26) <E T="03">Process rate/throughput.</E> A measurable factor or parameter that is directly or indirectly related to the emissions of an air pollution source. Depending on the type of source category, activity information may refer to the amount of fuel combusted, the amount of a raw material processed, the amount of a product that is manufactured, the amount of a material that is handled or processed, population, employment, number of units, or miles traveled. Activity information is typically the value that is multiplied against an emission factor to generate an emissions estimate.</P>
            <P>(27) <E T="03">SCC.</E> Source category code. A process-level code that describes the equipment or operation emitting pollutants.</P>
            <P>(28) <E T="03">Secondary control efficiency (%).</E> The emissions reductions efficiency of a secondary control device, which shows the amount of reductions of a particular pollutant from a process' <PRTPAGE P="158"/>emissions due to controls or material change. Control efficiency is usually expressed as a percentage or in tenths.</P>
            <P>(29) <E T="03">SIC.</E> Standard Industrial Classification code. U.S. Department of Commerce's categorization of businesses by their products or services.</P>
            <P>(30) <E T="03">Site name.</E> The name of the facility.</P>
            <P>(31) <E T="03">Spring throughput (%).</E> Portion of throughput or activity for the 3 spring months (March, April, May). See the definition of Fall Throughput.</P>
            <P>(32) <E T="03">Stack diameter.</E> Stack physical diameter.</P>
            <P>(33) <E T="03">Stack height.</E> Stack physical height above the surrounding terrain.</P>
            <P>(34) <E T="03">Start date (inventory year).</E> The calendar year that the emissions estimates were calculated for and are applicable to.</P>
            <P>(35) <E T="03">Start time (hour).</E> Start time (if available) that was applicable and used for calculations of emissions estimates.</P>
            <P>(36) <E T="03">Summer throughput (%).</E> Portion of throughput or activity for the 3 summer months (June, July, August). See the definition of Fall Throughput.</P>
            <P>(37) <E T="03">Summer work weekday emissions.</E> Average day's emissions for a typical day.</P>
            <P>(38) <E T="03">VMT by Roadway Class.</E> This is an expression of vehicle activity that is used with emission factors. The emission factors are usually expressed in terms of grams per mile of travel. Since VMT does not directly correlate to emissions that occur while the vehicle is not moving, these non-moving emissions are incorporated into EPA's MOBILE model emission factors.</P>
            <P>(39) <E T="03">Week/year in operation.</E> Weeks per year that the emitting process operates.</P>
            <P>(40) <E T="03">Work Weekday.</E> Any day of the week except Saturday or Sunday.</P>
            <P>(41) <E T="03">X coordinate (longitude).</E> An object's east-west geographical coordinate.</P>
            <P>(42) <E T="03">Y coordinate (latitude).</E> An object's north-south geographical coordinate.</P>
            <CITA>[70 FR 25317, May 12, 2005]</CITA>
          </SECTION>
          <SECTION>
            <SECTNO>§ 51.123</SECTNO>
            <SUBJECT>Findings and requirements for submission of State implementation plan revisions relating to emissions of oxides of nitrogen pursuant to the Clean Air Interstate Rule.</SUBJECT>

            <P>(a)(1) Under section 110(a)(1) of the CAA, 42 U.S.C. 7410(a)(1), the Administrator determines that each State identified in paragraph (c)(1) and (2) of this section must submit a SIP revision to comply with the requirements of section 110(a)(2)(D)(i)(I) of the CAA, 42 U.S.C. 7410(a)(2)(D)(i)(I), through the adoption of adequate provisions prohibiting sources and other activities from emitting NO<E T="52">X</E> in amounts that will contribute significantly to nonattainment in, or interfere with maintenance by, one or more other States with respect to the fine particles (PM<E T="52">2.5</E>) NAAQS.</P>

            <P>(2)(a) Under section 110(a)(1) of the CAA, 42 U.S.C. 7410(a)(1), the Administrator determines that each State identified in paragraph (c)(1) and (3) of this section must submit a SIP revision to comply with the requirements of section 110(a)(2)(D)(i)(I) of the CAA, 42 U.S.C. 7410(a)(2)(D)(i)(I), through the adoption of adequate provisions prohibiting sources and other activities from emitting NO<E T="52">X</E> in amounts that will contribute significantly to nonattainment in, or interfere with maintenance by, one or more other States with respect to the 8-hour ozone NAAQS.</P>
            <P>(b) For each State identified in paragraph (c) of this section, the SIP revision required under paragraph (a) of this section will contain adequate provisions, for purposes of complying with section 110(a)(2)(D)(i)(I) of the CAA, 42 U.S.C. 7410(a)(2)(D)(i)(I), only if the SIP revision contains control measures that assure compliance with the applicable requirements of this section.</P>
            <P>(c) In addition to being subject to the requirements in paragraphs (b) and (d) of this section:</P>

            <P>(1) Alabama, Delaware, Florida, Illinois, Indiana, Iowa, Kentucky, Louisiana, Maryland, Michigan, Mississippi, Missouri, New Jersey, New York, North Carolina, Ohio, Pennsylvania, South Carolina, Tennessee, Virginia, West Virginia, Wisconsin, and the District of Columbia shall be subject to the requirements contained in paragraphs (e) through (cc) of this section;<PRTPAGE P="159"/>
            </P>
            <P>(2) Georgia, Minnesota, and Texas shall be subject to the requirements in paragraphs (e) through (o) and (cc) of this section; and</P>
            <P>(3) Arkansas, Connecticut, and Massachusetts shall be subject to the requirements contained in paragraphs (q) through (cc) of this section.</P>
            <P>(d)(1) The State's SIP revision under paragraph (a) of this section must be submitted to EPA by no later than September 11, 2006.</P>
            <P>(2) The requirements of appendix V to this part shall apply to the SIP revision under paragraph (a) of this section.</P>
            <P>(3) The State shall deliver 5 copies of the SIP revision under paragraph (a) of this section to the appropriate Regional Office, with a letter giving notice of such action.</P>

            <P>(e) The State's SIP revision shall contain control measures and demonstrate that they will result in compliance with the State's Annual EGU NO<E T="52">X</E> Budget, if applicable, and achieve the State's Annual Non-EGU NO<E T="52">X</E> Reduction Requirement, if applicable, for the appropriate periods. The amounts of the State's Annual EGU NO<E T="52">X</E> Budget and Annual Non-EGU NO<E T="52">X</E> Reduction Requirement shall be determined as follows:</P>
            <P>(1)(i) The Annual EGU NO<E T="52">X</E> Budget for the State is defined as the total amount of NO<E T="52">X</E> emissions from all EGUs in that State for a year, if the State meets the requirements of paragraph (a)(1) of this section by imposing control measures, at least in part, on EGUs. If the State imposes control measures under this section on only EGUs, the Annual EGU NO<E T="52">X</E> Budget for the State shall not exceed the amount, during the indicated periods, specified in paragraph (e)(2) of this section.</P>
            <P>(ii) The Annual Non-EGU NO<E T="52">X</E> Reduction Requirement, if applicable, is defined as the total amount of NO<E T="52">X</E> emission reductions that the State demonstrates, in accordance with paragraph (g) of this section, it will achieve from non-EGUs during the appropriate period. If the State meets the requirements of paragraph (a)(1) of this section by imposing control measures on only non-EGUs, then the State's Annual Non-EGU NO<E T="52">X</E> Reduction Requirement shall equal or exceed, during the appropriate periods, the amount determined in accordance with paragraph (e)(3) of this section.</P>
            <P>(iii) If a State meets the requirements of paragraph (a)(1) of this section by imposing control measures on both EGUs and non-EGUs, then:</P>
            <P>(A) The Annual Non-EGU NO<E T="52">X</E> Reduction Requirement shall equal or exceed the difference between the amount specified in paragraph (e)(2) of this section for the appropriate period and the amount of the State's Annual EGU NO<E T="52">X</E> Budget specified in the SIP revision for the appropriate period; and</P>
            <P>(B) The Annual EGU NO<E T="52">X</E> Budget shall not exceed, during the indicated periods, the amount specified in paragraph (e)(2) of this section plus the amount of the Annual Non-EGU NO<E T="52">X</E> Reduction Requirement under paragraph (e)(1)(iii)(A) of this section for the appropriate period.</P>

            <P>(2) For a State that complies with the requirements of paragraph (a)(1) of this section by imposing control measures on only EGUs, the amount of the Annual EGU NO<E T="52">X</E> Budget, in tons of NO<E T="52">X</E> per year, shall be as follows, for the indicated State for the indicated period:</P>
            <GPOTABLE CDEF="s50,12,12" COLS="3" OPTS="L2">
              <BOXHD>
                <CHED H="1">State</CHED>
                <CHED H="1">Annual EGU NO<E T="52">X</E> budget for 2009-2014 (tons)</CHED>
                <CHED H="1">Annual EGU NO<E T="52">X</E> budget for 2015 and thereafter (tons)</CHED>
              </BOXHD>
              <ROW>
                <ENT I="01">Alabama</ENT>
                <ENT>69,020</ENT>
                <ENT>57,517</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Delaware</ENT>
                <ENT>4,166</ENT>
                <ENT>3,472</ENT>
              </ROW>
              <ROW>
                <ENT I="01">District of Columbia</ENT>
                <ENT>144</ENT>
                <ENT>120</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Florida</ENT>
                <ENT>99,445</ENT>
                <ENT>82,871</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Georgia</ENT>
                <ENT>66,321</ENT>
                <ENT>55,268</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Illinois</ENT>
                <ENT>76,230</ENT>
                <ENT>63,525</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Indiana</ENT>
                <ENT>108,935</ENT>
                <ENT>90,779</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Iowa</ENT>
                <ENT>32,692</ENT>
                <ENT>27,243</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Kentucky</ENT>
                <ENT>83,205</ENT>
                <ENT>69,337</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Louisiana</ENT>
                <ENT>35,512</ENT>
                <ENT>29,593</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Maryland</ENT>
                <ENT>27,724</ENT>
                <ENT>23,104</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Michigan</ENT>
                <ENT>65,304</ENT>
                <ENT>54,420</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Minnesota</ENT>
                <ENT>31,443</ENT>
                <ENT>26,203</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Mississippi</ENT>
                <ENT>17,807</ENT>
                <ENT>14,839</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Missouri</ENT>
                <ENT>59,871</ENT>
                <ENT>49,892</ENT>
              </ROW>
              <ROW>
                <ENT I="01">New Jersey</ENT>
                <ENT>12,670</ENT>
                <ENT>10,558</ENT>
              </ROW>
              <ROW>
                <ENT I="01">New York</ENT>
                <ENT>45,617</ENT>
                <ENT>38,014</ENT>
              </ROW>
              <ROW>
                <ENT I="01">North Carolina</ENT>
                <ENT>62,183</ENT>
                <ENT>51,819</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Ohio</ENT>
                <ENT>108,667</ENT>
                <ENT>90,556</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Pennsylvania</ENT>
                <ENT>99,049</ENT>
                <ENT>82,541</ENT>
              </ROW>
              <ROW>
                <ENT I="01">South Carolina</ENT>
                <ENT>32,662</ENT>
                <ENT>27,219</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Tennessee</ENT>
                <ENT>50,973</ENT>
                <ENT>42,478</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Texas</ENT>
                <ENT>181,014</ENT>
                <ENT>150,845</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Virginia</ENT>
                <ENT>36,074</ENT>
                <ENT>30,062</ENT>
              </ROW>
              <ROW>
                <ENT I="01">West Virginia</ENT>
                <ENT>74,220</ENT>
                <ENT>61,850</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Wisconsin</ENT>
                <ENT>40,759</ENT>
                <ENT>33,966</ENT>
              </ROW>
            </GPOTABLE>

            <P>(3) For a State that complies with the requirements of paragraph (a)(1) of <PRTPAGE P="160"/>this section by imposing control measures on only non-EGUs, the amount of the Annual Non-EGU NO<E T="52">X</E> Reduction Requirement, in tons of NO<E T="52">X</E> per year, shall be determined, for the State for 2009 and thereafter, by subtracting the amount of the State's Annual EGU NO<E T="52">X</E> Budget for the appropriate year, specified in paragraph (e)(2) of this section from the amount of the State's NO<E T="52">X</E> baseline EGU emissions inventory projected for the appropriate year, specified in Table 5 of “Regional and State SO<E T="52">2</E> and NO<E T="52">X</E> Budgets”, March 2005 (available at <E T="03">http://www.epa.gov/cleanairinterstaterule</E>).</P>
            <P>(4)(i) Notwithstanding the State's obligation to comply with paragraph (e)(2) or (3) of this section, the State's SIP revision may allow sources required by the revision to implement control measures to demonstrate compliance using credit issued from the State's compliance supplement pool, as set forth in paragraph (e)(4)(ii) of this section.</P>
            <P>(ii) The State-by-State amounts of the compliance supplement pool are as follows:</P>
            <GPOTABLE CDEF="s50,12" COLS="2" OPTS="L2">
              <BOXHD>
                <CHED H="1">State</CHED>
                <CHED H="1">Compliance supplement pool</CHED>
              </BOXHD>
              <ROW>
                <ENT I="01">Alabama</ENT>
                <ENT>10,166</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Delaware</ENT>
                <ENT>843</ENT>
              </ROW>
              <ROW>
                <ENT I="01">District of Columbia</ENT>
                <ENT>0</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Florida</ENT>
                <ENT>8,335</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Georgia</ENT>
                <ENT>12,397</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Illinois</ENT>
                <ENT>11,299</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Indiana</ENT>
                <ENT>20,155</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Iowa</ENT>
                <ENT>6,978</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Kentucky</ENT>
                <ENT>14,935</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Louisiana</ENT>
                <ENT>2,251</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Maryland</ENT>
                <ENT>4,670</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Michigan</ENT>
                <ENT>8,347</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Minnesota</ENT>
                <ENT>6,528</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Mississippi</ENT>
                <ENT>3,066</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Missouri</ENT>
                <ENT>9,044</ENT>
              </ROW>
              <ROW>
                <ENT I="01">New Jersey</ENT>
                <ENT>660</ENT>
              </ROW>
              <ROW>
                <ENT I="01">New York</ENT>
                <ENT>0</ENT>
              </ROW>
              <ROW>
                <ENT I="01">North Carolina</ENT>
                <ENT>0</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Ohio</ENT>
                <ENT>25,037</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Pennsylvania</ENT>
                <ENT>16,009</ENT>
              </ROW>
              <ROW>
                <ENT I="01">South Carolina</ENT>
                <ENT>2,600</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Tennessee</ENT>
                <ENT>8,944</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Texas</ENT>
                <ENT>772</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Virginia</ENT>
                <ENT>5,134</ENT>
              </ROW>
              <ROW>
                <ENT I="01">West Virginia</ENT>
                <ENT>16,929</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Wisconsin</ENT>
                <ENT>4,898</ENT>
              </ROW>
            </GPOTABLE>
            <P>(iii) The SIP revision may provide for the distribution of credits from the compliance supplement pool to sources that are required to implement control measures using one or both of the following two mechanisms:</P>

            <P>(A) The State may issue credit from compliance supplement pool to sources that are required by the SIP revision to implement NO<E T="52">X</E> emission control measures and that implement NO<E T="52">X</E> emission reductions in 2007 and 2008 that are not necessary to comply with any State or federal emissions limitation applicable at any time during such years. Such a source may be issued one credit from the compliance supplement pool for each ton of such emission reductions in 2007 and 2008.</P>
            <P>(<E T="03">1</E>) The State shall complete the issuance process by January 1, 2010.</P>
            <P>(<E T="03">2</E>) The emissions reductions for which credits are issued must have been demonstrated by the owners and operators of the source to have occurred during 2007 and 2008 and not to be necessary to comply with any applicable State or federal emissions limitation.</P>
            <P>(<E T="03">3</E>) The emissions reductions for which credits are issued must have been quantified by the owners and operators of the source:</P>
            <P>(<E T="03">i</E>) For EGUs and for fossil-fuel-fired non-EGUs that are boilers or combustion turbines with a maximum design heat input greater than 250 mmBut/hr, using emissions data determined in accordance with subpart H of part 75 of this chapter; and</P>
            <P>(<E T="03">ii</E>) For non-EGUs not described in paragraph (e)(4)(iii)(A)(3)(i) of this section, using emissions data determined in accordance with subpart H of part 75 of this chapter or, if the State demonstrates that compliance with subpart H of part 75 of this chapter is not practicable, determined, to the extent practicable, with the same degree of assurance with which emissions data are determined for sources subject to subpart H of part 75.</P>
            <P>(<E T="03">4</E>) If the SIP revision contains approved provisions for an emissions trading program, the owners and operators of sources that receive credit according to the requirements of this paragraph may transfer the credit to other sources or persons according to the provisions in the emissions trading program.</P>

            <P>(B) The State may issue credit from the compliance supplement pool to sources that are required by the SIP revision to implement NO<E T="52">X</E> emission <PRTPAGE P="161"/>control measures and whose owners and operators demonstrate a need for an extension, beyond 2009, of the deadline for the source for implementing such emission controls.</P>
            <P>(<E T="03">1</E>) The State shall complete the issuance process by January 1, 2010.</P>
            <P>(<E T="03">2</E>) The State shall issue credit to a source only if the owners and operators of the source demonstrate that:</P>
            <P>(<E T="03">i</E>) For a source used to generate electricity, implementation of the SIP revision's applicable control measures by 2009 would create undue risk for the reliability of the electricity supply. This demonstration must include a showing that it would not be feasible for the owners and operators of the source to obtain a sufficient amount of electricity, to prevent such undue risk, from other electricity generation facilities during the installation of control technology at the source necessary to comply with the SIP revision.</P>
            <P>(<E T="03">ii</E>) For a source not used to generate electricity, compliance with the SIP revision's applicable control measures by 2009 would create undue risk for the source or its associated industry to a degree that is comparable to the risk described in paragraph (e)(4)(iii)(B)(2)(i) of this section.</P>
            <P>(<E T="03">iii</E>) This demonstration must include a showing that it would not be possible for the source to comply with applicable control measures by obtaining sufficient credits under paragraph (e)(4)(iii)(A) of this section, or by acquiring sufficient credits from other sources or persons, to prevent undue risk.</P>
            <P>(f) Each SIP revision must set forth control measures to meet the amounts specified in paragraph (e) of this section, as applicable, including the following:</P>
            <P>(1) A description of enforcement methods including, but not limited to:</P>
            <P>(i) Procedures for monitoring compliance with each of the selected control measures;</P>
            <P>(ii) Procedures for handling violations; and</P>
            <P>(iii) A designation of agency responsibility for enforcement of implementation.</P>

            <P>(2)(i) If a State elects to impose control measures on EGUs, then those measures must impose an annual NO<E T="52">X</E> mass emissions cap on all such sources in the State.</P>

            <P>(ii) If a State elects to impose control measures on fossil fuel-fired non-EGUs that are boilers or combustion turbines with a maximum design heat input greater than 250 mmBtu/hr, then those measures must impose an annual NO<E T="52">X</E> mass emissions cap on all such sources in the State.</P>

            <P>(iii) If a State elects to impose control measures on non-EGUs other than those described in paragraph (f)(2)(ii) of this section, then those measures must impose an annual NO<E T="52">X</E> mass emissions cap on all such sources in the State or the State must demonstrate why such emissions cap is not practicable and adopt alternative requirements that ensure that the State will comply with its requirements under paragraph (e) of this section, as applicable, in 2009 and subsequent years.</P>

            <P>(g)(1) Each SIP revision that contains control measures covering non-EGUs as part or all of a State's obligation in meeting its requirement under paragraph (a)(1) of this section must demonstrate that such control measures are adequate to provide for the timely compliance with the State's Annual Non-EGU NO<E T="52">X</E> Reduction Requirement under paragraph (e) of this section and are not adopted or implemented by the State, as of May 12, 2005, and are not adopted or implemented by the Federal government, as of the date of submission of the SIP revision by the State to EPA.</P>
            <P>(2) The demonstration under paragraph (g)(1) of this section must include the following, with respect to each source category of non-EGUs for which the SIP revision requires control measures:</P>
            <P>(i) A detailed historical baseline inventory of NO<E T="52">X</E> mass emissions from the source category in a representative year consisting, at the State's election, of 2002, 2003, 2004, or 2005, or an average of 2 or more of those years, absent the control measures specified in the SIP revision.</P>

            <P>(A) This inventory must represent estimates of actual emissions based on monitoring data in accordance with subpart H of part 75 of this chapter, if <PRTPAGE P="162"/>the source category is subject to monitoring requirements in accordance with subpart H of part 75 of this chapter.</P>
            <P>(B) In the absence of monitoring data in accordance with subpart H of part 75 of this chapter, actual emissions must be quantified, to the maximum extent practicable, with the same degree of assurance with which emissions are quantified for sources subject to subpart H of part 75 of this chapter and using source-specific or source-category-specific assumptions that ensure a source's or source category's actual emissions are not overestimated. If a State uses factors to estimate emissions, production or utilization, or effectiveness of controls or rules for a source category, such factors must be chosen to ensure that emissions are not overestimated.</P>
            <P>(C) For measures to reduce emissions from motor vehicles, emission estimates must be based on an emissions model that has been approved by EPA for use in SIP development and must be consistent with the planning assumptions regarding vehicle miles traveled and other factors current at the time of the SIP development.</P>
            <P>(D) For measures to reduce emissions from nonroad engines or vehicles, emission estimates methodologies must be approved by EPA.</P>
            <P>(ii) A detailed baseline inventory of NO<E T="52">X</E> mass emissions from the source category in the years 2009 and 2015, absent the control measures specified in the SIP revision and reflecting changes in these emissions from the historical baseline year to the years 2009 and 2015, based on projected changes in the production input or output, population, vehicle miles traveled, economic activity, or other factors as applicable to this source category.</P>

            <P>(A) These inventories must account for implementation of any control measures that are otherwise required by final rules already promulgated, as of May 12, 2005, or adopted or implemented by any federal agency, as of the date of submission of the SIP revision by the State to EPA, and must exclude any control measures specified in the SIP revision to meet the NO<E T="52">X</E> emissions reduction requirements of this section.</P>
            <P>(B) Economic and population forecasts must be as specific as possible to the applicable industry, State, and county of the source or source category and must be consistent with both national projections and relevant official planning assumptions, including estimates of population and vehicle miles traveled developed through consultation between State and local transportation and air quality agencies. However, if these official planning assumptions are inconsistent with official U.S. Census projections of population or with energy consumption projections contained in the U.S. Department of Energy's most recent Annual Energy Outlook, then the SIP revision must make adjustments to correct the inconsistency or must demonstrate how the official planning assumptions are more accurate.</P>
            <P>(C) These inventories must account for any changes in production method, materials, fuels, or efficiency that are expected to occur between the historical baseline year and 2009 or 2015, as appropriate.</P>
            <P>(iii) A projection of NO<E T="52">X</E> mass emissions in 2009 and 2015 from the source category assuming the same projected changes as under paragraph (g)(2)(ii) of this section and resulting from implementation of each of the control measures specified in the SIP revision.</P>
            <P>(A) These inventories must address the possibility that the State's new control measures may cause production or utilization, and emissions, to shift to unregulated or less stringently regulated sources in the source category in the same or another State, and these inventories must include any such amounts of emissions that may shift to such other sources.</P>

            <P>(B) The State must provide EPA with a summary of the computations, assumptions, and judgments used to determine the degree of reduction in projected 2009 and 2015 NO<E T="52">X</E> emissions that will be achieved from the implementation of the new control measures compared to the relevant baseline emissions inventory.</P>

            <P>(iv) The result of subtracting the amounts in paragraph (g)(2)(iii) of this section for 2009 and 2015, respectively, from the lower of the amounts in paragraph (g)(2)(i) or (g)(2)(ii) of this section for 2009 and 2015, respectively, may be credited towards the State's Annual <PRTPAGE P="163"/>Non-EGU NO<E T="52">X</E> Reduction Requirement in paragraph (e)(3) of this section for the appropriate period.</P>
            <P>(v) Each SIP revision must identify the sources of the data used in each estimate and each projection of emissions.</P>
            <P>(h) Each SIP revision must comply with § 51.116 (regarding data availability).</P>
            <P>(i) Each SIP revision must provide for monitoring the status of compliance with any control measures adopted to meet the State's requirements under paragraph (e) of this section as follows:</P>
            <P>(1) The SIP revision must provide for legally enforceable procedures for requiring owners or operators of stationary sources to maintain records of, and periodically report to the State:</P>
            <P>(i) Information on the amount of NO<E T="52">X</E> emissions from the stationary sources; and</P>
            <P>(ii) Other information as may be necessary to enable the State to determine whether the sources are in compliance with applicable portions of the control measures;</P>
            <P>(2) The SIP revision must comply with § 51.212 (regarding testing, inspection, enforcement, and complaints);</P>
            <P>(3) If the SIP revision contains any transportation control measures, then the SIP revision must comply with § 51.213 (regarding transportation control measures);</P>
            <P>(4)(i) If the SIP revision contains measures to control EGUs, then the SIP revision must require such sources to comply with the monitoring, recordkeeping, and reporting provisions of subpart H of part 75 of this chapter.</P>
            <P>(ii) If the SIP revision contains measures to control fossil fuel-fired non-EGUs that are boilers or combustion turbines with a maximum design heat input greater than 250 mmBtu/hr, then the SIP revision must require such sources to comply with the monitoring, recordkeeping, and reporting provisions of subpart H of part 75 of this chapter.</P>
            <P>(iii) If the SIP revision contains measures to control any other non-EGUs that are not described in paragraph (i)(4)(ii) of this section, then the SIP revision must require such sources to comply with the monitoring, recordkeeping, and reporting provisions of subpart H of part 75 of this chapter, or the State must demonstrate why such requirements are not practicable and adopt alternative requirements that ensure that the required emissions reductions will be quantified, to the maximum extent practicable, with the same degree of assurance with which emissions are quantified for sources subject to subpart H of part 75 of this chapter.</P>
            <P>(j) Each SIP revision must show that the State has legal authority to carry out the SIP revision, including authority to:</P>

            <P>(1) Adopt emissions standards and limitations and any other measures necessary for attainment and maintenance of the State's relevant Annual EGU NO<E T="52">X</E> Budget or the Annual Non-EGU NO<E T="52">X</E> Reduction Requirement, as applicable, under paragraph (e) of this section;</P>
            <P>(2) Enforce applicable laws, regulations, and standards and seek injunctive relief;</P>
            <P>(3) Obtain information necessary to determine whether air pollution sources are in compliance with applicable laws, regulations, and standards, including authority to require recordkeeping and to make inspections and conduct tests of air pollution sources; and</P>
            <P>(4)(i) Require owners or operators of stationary sources to install, maintain, and use emissions monitoring devices and to make periodic reports to the State on the nature and amounts of emissions from such stationary sources; and</P>
            <P>(ii) Make the data described in paragraph (j)(4)(i) of this section available to the public within a reasonable time after being reported and as correlated with any applicable emissions standards or limitations.</P>
            <P>(k)(1) The provisions of law or regulation that the State determines provide the authorities required under this section must be specifically identified, and copies of such laws or regulations must be submitted with the SIP revision.</P>

            <P>(2) Legal authority adequate to fulfill the requirements of paragraphs (j)(3) and (4) of this section may be delegated <PRTPAGE P="164"/>to the State under section 114 of the CAA.</P>
            <P>(l)(1) A SIP revision may assign legal authority to local agencies in accordance with § 51.232.</P>
            <P>(2) Each SIP revision must comply with § 51.240 (regarding general plan requirements).</P>
            <P>(m) Each SIP revision must comply with § 51.280 (regarding resources).</P>
            <P>(n) Each SIP revision must provide for State compliance with the reporting requirements in § 51.125.</P>

            <P>(o)(1) Notwithstanding any other provision of this section, if a State adopts regulations substantively identical to subparts AA through II of part 96 of this chapter (CAIR NO<E T="52">X</E> Annual Trading Program), incorporates such subparts by reference into its regulations, or adopts regulations that differ substantively from such subparts only as set forth in paragraph (o)(2) of this section, then such emissions trading program in the State's SIP revision is automatically approved as meeting the requirements of paragraph (e) of this section, provided that the State has the legal authority to take such action and to implement its responsibilities under such regulations.</P>
            <P>(2) If a State adopts an emissions trading program that differs substantively from subparts AA through II of part 96 of this chapter only as follows, then the emissions trading program is approved as set forth in paragraph (o)(1) of this section.</P>
            <P>(i) The State may decline to adopt the CAIR NO<E T="52">X</E> opt-in provisions of:</P>

            <P>(A) Subpart II of this part and the provisions applicable only to CAIR NO<E T="52">X</E> opt-in units in subparts AA through HH of this part;</P>

            <P>(B) Section 96.188(b) of this chapter and the provisions of subpart II of this part applicable only to CAIR NO<E T="52">X</E> opt-in units under § 96.188(b); or</P>

            <P>(C) Section 96.188(c) of this chapter and the provisions of subpart II of this part applicable only to CAIR NO<E T="52">X</E> opt-in units under § 96.188(c).</P>

            <P>(ii) The State may decline to adopt the allocation provisions set forth in subpart EE of part 96 of this chapter and may instead adopt any methodology for allocating CAIR NO<E T="52">X</E> allowances to individual sources, as follows:</P>

            <P>(A) The State's methodology must not allow the State to allocate CAIR NO<E T="52">X</E> allowances for a year in excess of the amount in the State's Annual EGU NO<E T="52">X</E> Budget for such year;</P>

            <P>(B) The State's methodology must require that, for EGUs commencing operation before January 1, 2001, the State will determine, and notify the Administrator of, each unit's allocation of CAIR NO<E T="52">X</E> allowances by October 31, 2006 for 2009, 2010, and 2011 and by October 31, 2008 and October 31 of each year thereafter for 4th the year after the year of the notification deadline;</P>

            <P>(C) The State's methodology must require that, for EGUs commencing operation on or after January 1, 2001, the State will determine, and notify the Administrator of, each unit's allocation of CAIR NO<E T="52">X</E> allowances by October 31 of the year for which the CAIR NO<E T="52">X</E> allowances are allocated; and</P>
            <P>(D) The State's methodology for allocating the compliance supplement pool must be substantively identical to § 97.143 (except that the permitting authority makes the allocations and the Administrator records the allocations made by the permitting authority) or otherwise in accordance with paragraph (e)(4) of this section.</P>
            <P>(3) A State that adopts an emissions trading program in accordance with paragraph (o)(1) or (2) of this section is not required to adopt an emissions trading program in accordance with paragraph (aa)(1) or (2) of this section or § 96.124(o)(1) or (2).</P>

            <P>(4) If a State adopts an emissions trading program that differs substantively from subparts AA through HH of part 96 of this chapter, other than as set forth in paragraph (o)(2) of this section, then such emissions trading program is not automatically approved as set forth in paragraph (o)(1) or (2) of this section and will be reviewed by the Administrator for approvability in accordance with the other provisions of this section, provided that the NO<E T="52">X</E> allowances issued under such emissions trading program shall not, and the SIP revision shall state that such NO<E T="52">X</E> allowances shall not, qualify as CAIR NO<E T="52">X</E> allowances or CAIR NO<E T="52">X</E> Ozone Season allowances under any emissions trading program <PRTPAGE P="165"/>approved under paragraphs (o)(1) or (2) or (aa)(1) or (2) of this section.</P>

            <P>(p) Notwithstanding any other provision of this section, a State may adopt, and include in a SIP revision submitted by March 31, 2007, regulations relating to the Federal CAIR NO<E T="52">X</E> Annual Trading Program under subparts AA through HH of part 97 of this chapter as follows:</P>
            <P>(1) The State may adopt, as CAIR NO<E T="52">X</E> allowance allocation provisions replacing the provisions in subpart EE of part 97 of this chapter:</P>
            <P>(i) Allocation provisions substantively identical to subpart EE of part 96 of this chapter, under which the permitting authority makes the allocations; or</P>
            <P>(ii) Any methodology for allocating CAIR NO<E T="52">X</E> allowances to individual sources under which the permitting authority makes the allocations, provided that:</P>

            <P>(A) The State's methodology must not allow the permitting authority to allocate CAIR NO<E T="52">X</E> allowances for a year in excess of the amount in the State's Annual EGU NO<E T="52">X</E> budget for such year.</P>

            <P>(B) The State's methodology must require that, for EGUs commencing operation before January 1, 2001, the permitting authority will determine, and notify the Administrator of, each unit's allocation of CAIR NO<E T="52">X</E> allowances by April 30, 2007 for 2009, 2010, and 2011 and by October 31, 2008 and October 31 of each year thereafter for the 4th year after the year of the notification deadline.</P>

            <P>(C) The State's methodology must require that, for EGUs commencing operation on or after January 1, 2001, the permitting authority will determine, and notify the Administrator of, each unit's allocation of CAIR NO<E T="52">X</E> allowances by October 31 of the year for which the CAIR NO<E T="52">X</E> allowances are allocated.</P>
            <P>(2) The State may adopt, as compliance supplement pool provisions replacing the provisions in ( 97.143 of this chapter:</P>
            <P>(i) Provisions for allocating the State's compliance supplement pool that are substantively identical to § 97.143 of this chapter, except that the permitting authority makes the allocations and the Administrator records the allocations made by the permitting authority;</P>
            <P>(ii) Provisions for allocating the State's compliance supplement pool that are substantively identical to § 96.143 of this chapter; or</P>
            <P>(iii) Other provisions for allocating the State's compliance supplement pool that are in accordance with paragraph (e)(4) of this section.</P>
            <P>(3) The State may adopt CAIR opt-in unit provisions as follows:</P>

            <P>(i) Provisions for CAIR opt-in units, including provisions for applications for CAIR opt-in permits, approval of CAIR opt-in permits, treatment of units as CAIR opt-in units, and allocation and recordation of CAIR NO<E T="52">X</E> allowances for CAIR opt-in units, that are substantively identical to subpart II of part 96 of this chapter and the provisions of subparts AA through HH that are applicable to CAIR opt-in units or units for which a CAIR opt-in permit application is submitted and not withdrawn and a CAIR opt-in permit is not yet issued or denied;</P>

            <P>(ii) Provisions for CAIR opt-in units, including provisions for applications for CAIR opt-in permits, approval of CAIR opt-in permits, treatment of units as CAIR opt-in units, and allocation and recordation of CAIR NO<E T="52">X</E> allowances for CAIR opt-in units, that are substantively identical to subpart II of part 96 of this chapter and the provisions of subparts AA through HH that are applicable to CAIR opt-in units or units for which a CAIR opt-in permit application is submitted and not withdrawn and a CAIR opt-in permit is not yet issued or denied, except that the provisions exclude § 96.188(b) of this chapter and the provisions of subpart II of part 96 of this chapter that apply only to units covered by § 96.188(b) of this chapter; or</P>

            <P>(iii) Provisions for applications for CAIR opt-in units, including provisions for CAIR opt-in permits, approval of CAIR opt-in permits, treatment of units as CAIR opt-in units, and allocation and recordation of CAIR NO<E T="52">X</E> allowances for CAIR opt-in units, that are substantively identical to subpart II of part 96 of this chapter and the provisions of subparts AA through HH that are applicable to CAIR opt-in <PRTPAGE P="166"/>units or units for which a CAIR opt-in permit application is submitted and not withdrawn and a CAIR opt-in permit is not yet issued or denied, except that the provisions exclude § 96.188(c) of this chapter and the provisions of subpart II of part 96 of this chapter that apply only to units covered by § 96.188(c) of this chapter.</P>

            <P>(q) The State's SIP revision shall contain control measures and demonstrate that they will result in compliance with the State's Ozone Season EGU NO<E T="52">X</E> Budget, if applicable, and achieve the State's Ozone Season Non-EGU NO<E T="52">X</E> Reduction Requirement, if applicable, for the appropriate periods. The amounts of the State's Ozone Season EGU NO<E T="52">X</E> Budget and Ozone Season Non-EGU NO<E T="52">X</E> Reduction Requirement shall be determined as follows:</P>
            <P>(1)(i) The Ozone Season EGU NO<E T="52">X</E> Budget for the State is defined as the total amount of NO<E T="52">X</E> emissions from all EGUs in that State for an ozone season, if the State meets the requirements of paragraph (a)(2) of this section by imposing control measures, at least in part, on EGUs. If the State imposes control measures under this section on only EGUs, the Ozone Season EGU NO<E T="52">X</E> Budget for the State shall not exceed the amount, during the indicated periods, specified in paragraph (q)(2) of this section.</P>
            <P>(ii) The Ozone Season Non-EGU NO<E T="52">X</E> Reduction Requirement, if applicable, is defined as the total amount of NO<E T="52">X</E> emission reductions that the State demonstrates, in accordance with paragraph (s) of this section, it will achieve from non-EGUs during the appropriate period. If the State meets the requirements of paragraph (a)(2) of this section by imposing control measures on only non-EGUs, then the State's Ozone Season Non-EGU NO<E T="52">X</E> Reduction Requirement shall equal or exceed, during the appropriate periods, the amount determined in accordance with paragraph (q)(3) of this section.</P>
            <P>(iii) If a State meets the requirements of paragraph (a)(2) of this section by imposing control measures on both EGUs and non-EGUs, then:</P>
            <P>(A) The Ozone Season Non-EGU NO<E T="52">X</E> Reduction Requirement shall equal or exceed the difference between the amount specified in paragraph (q)(2) of this section for the appropriate period and the amount of the State's Ozone Season EGU NO<E T="52">X</E> Budget specified in the SIP revision for the appropriate period; and</P>
            <P>(B) The Ozone Season EGU NO<E T="52">X</E> Budget shall not exceed, during the indicated periods, the amount specified in paragraph (e)(2) of this section plus the amount of the Ozone Season Non-EGU NO<E T="52">X</E> Reduction Requirement under paragraph (q)(1)(iii)(A) of this section for the appropriate period.</P>

            <P>(2) For a State that complies with the requirements of paragraph (a)(2) of this section by imposing control measures on only EGUs, the amount of the Ozone Season EGU NO<E T="52">X</E> Budget, in tons of NO<E T="52">X</E> per ozone season, shall be as follows, for the indicated State for the indicated period:</P>
            <GPOTABLE CDEF="s50,12,12" COLS="3" OPTS="L2">
              <BOXHD>
                <CHED H="1">State</CHED>
                <CHED H="1">Ozone season EGU NO<E T="52">X</E> budget for 2009-2014 (tons)</CHED>
                <CHED H="1">Ozone season EGU NO<E T="52">X</E> budget for 2015 and thereafter (tons)</CHED>
              </BOXHD>
              <ROW>
                <ENT I="01">Alabama</ENT>
                <ENT>32,182</ENT>
                <ENT>26,818</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Arkansas</ENT>
                <ENT>11,515</ENT>
                <ENT>9,596</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Connecticut</ENT>
                <ENT>2,559</ENT>
                <ENT>2,559</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Delaware</ENT>
                <ENT>2,226</ENT>
                <ENT>1,855</ENT>
              </ROW>
              <ROW>
                <ENT I="01">District of Columbia</ENT>
                <ENT>112</ENT>
                <ENT>94</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Florida</ENT>
                <ENT>47,912</ENT>
                <ENT>39,926</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Illinois</ENT>
                <ENT>30,701</ENT>
                <ENT>28,981</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Indiana</ENT>
                <ENT>45,952</ENT>
                <ENT>39,273</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Iowa</ENT>
                <ENT>14,263</ENT>
                <ENT>11,886</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Kentucky</ENT>
                <ENT>36,045</ENT>
                <ENT>30,587</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Louisiana</ENT>
                <ENT>17,085</ENT>
                <ENT>14,238</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Maryland</ENT>
                <ENT>12,834</ENT>
                <ENT>10,695</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Massachusetts</ENT>
                <ENT>7,551</ENT>
                <ENT>6,293</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Michigan</ENT>
                <ENT>28,971</ENT>
                <ENT>24,142</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Mississippi</ENT>
                <ENT>8,714</ENT>
                <ENT>7,262</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Missouri</ENT>
                <ENT>26,678</ENT>
                <ENT>22,231</ENT>
              </ROW>
              <ROW>
                <ENT I="01">New Jersey</ENT>
                <ENT>6,654</ENT>
                <ENT>5,545</ENT>
              </ROW>
              <ROW>
                <ENT I="01">New York</ENT>
                <ENT>20,632</ENT>
                <ENT>17,193</ENT>
              </ROW>
              <ROW>
                <ENT I="01">North Carolina</ENT>
                <ENT>28,392</ENT>
                <ENT>23,660</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Ohio</ENT>
                <ENT>45,664</ENT>
                <ENT>39,945</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Pennsylvania</ENT>
                <ENT>42,171</ENT>
                <ENT>35,143</ENT>
              </ROW>
              <ROW>
                <ENT I="01">South Carolina</ENT>
                <ENT>15,249</ENT>
                <ENT>12,707</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Tennessee</ENT>
                <ENT>22,842</ENT>
                <ENT>19,035</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Virginia</ENT>
                <ENT>15,994</ENT>
                <ENT>13,328</ENT>
              </ROW>
              <ROW>
                <ENT I="01">West Virginia</ENT>
                <ENT>26,859</ENT>
                <ENT>26,525</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Wisconsin</ENT>
                <ENT>17,987</ENT>
                <ENT>14,989</ENT>
              </ROW>
            </GPOTABLE>

            <P>(3) For a State that complies with the requirements of paragraph (a)(2) of this section by imposing control measures on only non-EGUs, the amount of the Ozone Season Non-EGU NO<E T="52">X</E> Reduction Requirement, in tons of NO<E T="52">X</E> per ozone season, shall be determined, for the State for 2009 and thereafter, by subtracting the amount of the State's Ozone Season EGU NO<E T="52">X</E> Budget for the appropriate year, specified in paragraph (e)(2) of this section, from the <PRTPAGE P="167"/>amount of the State's NO<E T="52">X</E> baseline EGU emissions inventory projected for the ozone season in the appropriate year, specified in Table 7 of “Regional and State SO<E T="52">2</E> and NO<E T="52">X</E> Budgets”, March 2005 (available at: <E T="03">http://www.epa.gov/cleanairinterstaterule</E>).</P>

            <P>(4) Notwithstanding the State's obligation to comply with paragraph (q)(2) or (3) of this section, the State's SIP revision may allow sources required by the revision to implement NO<E T="52">X</E> emission control measures to demonstrate compliance using NO<E T="52">X</E> SIP Call allowances allocated under the NO<E T="52">X</E> Budget Trading Program for any ozone season during 2003 through 2008 that have not been deducted by the Administrator under the NO<E T="52">X</E> Budget Trading Program, if the SIP revision ensures that such allowances will not be available for such deduction under the NO<E T="52">X</E> Budget Trading Program.</P>
            <P>(r) Each SIP revision must set forth control measures to meet the amounts specified in paragraph (q) of this section, as applicable, including the following:</P>
            <P>(1) A description of enforcement methods including, but not limited to:</P>
            <P>(i) Procedures for monitoring compliance with each of the selected control measures;</P>
            <P>(ii) Procedures for handling violations; and</P>
            <P>(iii) A designation of agency responsibility for enforcement of implementation.</P>

            <P>(2)(i) If a State elects to impose control measures on EGUs, then those measures must impose an ozone season NO<E T="52">X</E> mass emissions cap on all such sources in the State.</P>

            <P>(ii) If a State elects to impose control measures on fossil fuel-fired non-EGUs that are boilers or combustion turbines with a maximum design heat input greater than 250 mmBtu/hr, then those measures must impose an ozone season NO<E T="52">X</E> mass emissions cap on all such sources in the State.</P>

            <P>(iii) If a State elects to impose control measures on non-EGUs other than those described in paragraph (r)(2)(ii) of this section, then those measures must impose an ozone season NO<E T="52">X</E> mass emissions cap on all such sources in the State or the State must demonstrate why such emissions cap is not practicable and adopt alternative requirements that ensure that the State will comply with its requirements under paragraph (q) of this section, as applicable, in 2009 and subsequent years.</P>

            <P>(s)(1) Each SIP revision that contains control measures covering non-EGUs as part or all of a State's obligation in meeting its requirement under paragraph (a)(2) of this section must demonstrate that such control measures are adequate to provide for the timely compliance with the State's Ozone Season Non-EGU NO<E T="52">X</E> Reduction Requirement under paragraph (q) of this section and are not adopted or implemented by the State, as of May 12, 2005, and are not adopted or implemented by the federal government, as of the date of submission of the SIP revision by the State to EPA.</P>
            <P>(2) The demonstration under paragraph (s)(1) of this section must include the following, with respect to each source category of non-EGUs for which the SIP revision requires control measures:</P>
            <P>(i) A detailed historical baseline inventory of NO<E T="52">X</E> mass emissions from the source category in a representative ozone season consisting, at the State's election, of the ozone season in 2002, 2003, 2004, or 2005, or an average of 2 or more of those ozone seasons, absent the control measures specified in the SIP revision.</P>
            <P>(A) This inventory must represent estimates of actual emissions based on monitoring data in accordance with subpart H of part 75 of this chapter, if the source category is subject to monitoring requirements in accordance with subpart H of part 75 of this chapter.</P>

            <P>(B) In the absence of monitoring data in accordance with subpart H of part 75 of this chapter, actual emissions must be quantified, to the maximum extent practicable, with the same degree of assurance with which emissions are quantified for sources subject to subpart H of part 75 of this chapter and using source-specific or source-category-specific assumptions that ensure a source's or source category's actual emissions are not overestimated. If a State uses factors to estimate emissions, production or utilization, or effectiveness of controls or rules for a <PRTPAGE P="168"/>source category, such factors must be chosen to ensure that emissions are not overestimated.</P>
            <P>(C) For measures to reduce emissions from motor vehicles, emission estimates must be based on an emissions model that has been approved by EPA for use in SIP development and must be consistent with the planning assumptions regarding vehicle miles traveled and other factors current at the time of the SIP development.</P>
            <P>(D) For measures to reduce emissions from nonroad engines or vehicles, emission estimates methodologies must be approved by EPA.</P>
            <P>(ii) A detailed baseline inventory of NO<E T="52">X</E> mass emissions from the source category in ozone seasons 2009 and 2015, absent the control measures specified in the SIP revision and reflecting changes in these emissions from the historical baseline ozone season to the ozone seasons 2009 and 2015, based on projected changes in the production input or output, population, vehicle miles traveled, economic activity, or other factors as applicable to this source category.</P>

            <P>(A) These inventories must account for implementation of any control measures that are adopted or implemented by the State, as of May 12, 2005, or adopted or implemented by the federal government, as of the date of submission of the SIP revision by the State to EPA, and must exclude any control measures specified in the SIP revision to meet the NO<E T="52">X</E> emissions reduction requirements of this section.</P>
            <P>(B) Economic and population forecasts must be as specific as possible to the applicable industry, State, and county of the source or source category and must be consistent with both national projections and relevant official planning assumptions including estimates of population and vehicle miles traveled developed through consultation between State and local transportation and air quality agencies. However, if these official planning assumptions are inconsistent with official U.S. Census projections of population or with energy consumption projections contained in the U.S. Department of Energy's most recent Annual Energy Outlook, then the SIP revision must make adjustments to correct the inconsistency or must demonstrate how the official planning assumptions are more accurate.</P>
            <P>(C) These inventories must account for any changes in production method, materials, fuels, or efficiency that are expected to occur between the historical baseline ozone season and ozone season 2009 or ozone season 2015, as appropriate.</P>
            <P>(iii) A projection of NO<E T="52">X</E> mass emissions in ozone season 2009 and ozone season 2015 from the source category assuming the same projected changes as under paragraph (s)(2)(ii) of this section and resulting from implementation of each of the control measures specified in the SIP revision.</P>
            <P>(A) These inventories must address the possibility that the State's new control measures may cause production or utilization, and emissions, to shift to unregulated or less stringently regulated sources in the source category in the same or another State, and these inventories must include any such amounts of emissions that may shift to such other sources.</P>

            <P>(B) The State must provide EPA with a summary of the computations, assumptions, and judgments used to determine the degree of reduction in projected ozone season 2009 and ozone season 2015 NO<E T="52">X</E> emissions that will be achieved from the implementation of the new control measures compared to the relevant baseline emissions inventory.</P>

            <P>(iv) The result of subtracting the amounts in paragraph (s)(2)(iii) of this section for ozone season 2009 and ozone season 2015, respectively, from the lower of the amounts in paragraph (s)(2)(i) or (s)(2)(ii) of this section for ozone season 2009 and ozone season 2015, respectively, may be credited towards the State's Ozone Season Non-EGU NO<E T="52">X</E> Reduction Requirement in paragraph (q)(3) of this section for the appropriate period.</P>
            <P>(v) Each SIP revision must identify the sources of the data used in each estimate and each projection of emissions.</P>

            <P>(t) Each SIP revision must comply with § 51.116 (regarding data availability).<PRTPAGE P="169"/>
            </P>
            <P>(u) Each SIP revision must provide for monitoring the status of compliance with any control measures adopted to meet the State's requirements under paragraph (q) of this section as follows:</P>
            <P>(1) The SIP revision must provide for legally enforceable procedures for requiring owners or operators of stationary sources to maintain records of, and periodically report to the State:</P>
            <P>(i) Information on the amount of NO<E T="52">X</E> emissions from the stationary sources; and</P>
            <P>(ii) Other information as may be necessary to enable the State to determine whether the sources are in compliance with applicable portions of the control measures;</P>
            <P>(2) The SIP revision must comply with § 51.212 (regarding testing, inspection, enforcement, and complaints);</P>
            <P>(3) If the SIP revision contains any transportation control measures, then the SIP revision must comply with § 51.213 (regarding transportation control measures);</P>
            <P>(4)(i) If the SIP revision contains measures to control EGUs, then the SIP revision must require such sources to comply with the monitoring, recordkeeping, and reporting provisions of subpart H of part 75 of this chapter.</P>
            <P>(ii) If the SIP revision contains measures to control fossil fuel-fired non-EGUs that are boilers or combustion turbines with a maximum design heat input greater than 250 mmBtu/hr, then the SIP revision must require such sources to comply with the monitoring, recordkeeping, and reporting provisions of subpart H of part 75 of this chapter.</P>
            <P>(iii) If the SIP revision contains measures to control any other non-EGUs that are not described in paragraph (u)(4)(ii) of this section, then the SIP revision must require such sources to comply with the monitoring, recordkeeping, and reporting provisions of subpart H of part 75 of this chapter, or the State must demonstrate why such requirements are not practicable and adopt alternative requirements that ensure that the required emissions reductions will be quantified, to the maximum extent practicable, with the same degree of assurance with which emissions are quantified for sources subject to subpart H of part 75 of this chapter.</P>
            <P>(v) Each SIP revision must show that the State has legal authority to carry out the SIP revision, including authority to:</P>

            <P>(1) Adopt emissions standards and limitations and any other measures necessary for attainment and maintenance of the State's relevant Ozone Season EGU NO<E T="52">X</E> Budget or the Ozone Season Non-EGU NO<E T="52">X</E> Reduction Requirement, as applicable, under paragraph (q) of this section;</P>
            <P>(2) Enforce applicable laws, regulations, and standards and seek injunctive relief;</P>
            <P>(3) Obtain information necessary to determine whether air pollution sources are in compliance with applicable laws, regulations, and standards, including authority to require recordkeeping and to make inspections and conduct tests of air pollution sources; and</P>
            <P>(4)(i) Require owners or operators of stationary sources to install, maintain, and use emissions monitoring devices and to make periodic reports to the State on the nature and amounts of emissions from such stationary sources; and</P>
            <P>(ii) Make the data described in paragraph (v)(4)(i) of this section available to the public within a reasonable time after being reported and as correlated with any applicable emissions standards or limitations.</P>
            <P>(w)(1) The provisions of law or regulation that the State determines provide the authorities required under this section must be specifically identified, and copies of such laws or regulations must be submitted with the SIP revision.</P>
            <P>(2) Legal authority adequate to fulfill the requirements of paragraphs (v)(3) and (4) of this section may be delegated to the State under section 114 of the CAA.</P>
            <P>(x)(1) A SIP revision may assign legal authority to local agencies in accordance with § 51.232.</P>
            <P>(2) Each SIP revision must comply with § 51.240 (regarding general plan requirements).</P>

            <P>(y) Each SIP revision must comply with § 51.280 (regarding resources).<PRTPAGE P="170"/>
            </P>
            <P>(z) Each SIP revision must provide for State compliance with the reporting requirements in § 51.125.</P>

            <P>(aa)(1) Notwithstanding any other provision of this section, if a State adopts regulations substantively identical to subparts AAAA through IIII of part 96 of this chapter (CAIR Ozone Season NO<E T="52">X</E> Trading Program), incorporates such subparts by reference into its regulations, or adopts regulations that differ substantively from such subparts only as set forth in paragraph (aa)(2) of this section, then such emissions trading program in the State's SIP revision is automatically approved as meeting the requirements of paragraph (q) of this section, provided that the State has the legal authority to take such action and to implement its responsibilities under such regulations.</P>
            <P>(2) If a State adopts an emissions trading program that differs substantively from subparts AAAA through IIII of part 96 of this chapter only as follows, then the emissions trading program is approved as set forth in paragraph (aa)(1) of this section.</P>
            <P>(i) The State may expand the applicability provisions in § 96.304 to include all non-EGUs subject to the State's emissions trading program approved under § 51.121(p).</P>
            <P>(ii) The State may decline to adopt the CAIR NO<E T="52">X</E> Ozone Season opt-in provisions of:</P>

            <P>(A) Subpart IIII of this part and the provisions applicable only to CAIR NO<E T="52">X</E> Ozone Season opt-in units in subparts AAAA through HHHH of this part;</P>

            <P>(B) Section 96.388(b) of this chapter and the provisions of subpart IIII of this part applicable only to CAIR NO<E T="52">X</E> Ozone Season opt-in units under § 96.388(b); or</P>

            <P>(C) Section 96.388(c) of this chapter and the provisions of subpart IIII of this part applicable only to CAIR NO<E T="52">X</E> Ozone Season opt-in units under § 96.388(c).</P>

            <P>(iii) The State may decline to adopt the allocation provisions set forth in subpart EEEE of part 96 of this chapter and may instead adopt any methodology for allocating CAIR NO<E T="52">X</E> Ozone Season allowances to individual sources, as follows:</P>

            <P>(A) The State may provide for issuance of an amount of CAIR Ozone Season NO<E T="52">X</E> allowances for an ozone season, in addition to the amount in the State's Ozone Season EGU NO<E T="52">X</E> Budget for such ozone season, not exceeding the amount of NO<E T="52">X</E> SIP Call allowances allocated for the ozone season under the NO<E T="52">X</E> Budget Trading Program to non-EGUs that the applicability provisions in § 96.304 are expanded to include under paragraph (aa)(2)(i) of this section;</P>

            <P>(B) The State's methodology must not allow the State to allocate CAIR Ozone Season NO<E T="52">X</E> allowances for an ozone season in excess of the amount in the State's Ozone Season EGU NO<E T="52">X</E> Budget for such ozone season plus any additional amount of CAIR Ozone Season NO<E T="52">X</E> allowances issued under paragraph (aa)(2)(iii)(A) of this section for such ozone season;</P>

            <P>(C) The State's methodology must require that, for EGUs commencing operation before January 1, 2001, the State will determine, and notify the Administrator of, each unit's allocation of CAIR NO<E T="52">X</E> allowances by October 31, 2006 for the ozone seasons 2009, 2010, and 2011 and by October 31, 2008 and October 31 of each year thereafter for the ozone season in the 4th year after the year of the notification deadline; and</P>

            <P>(D) The State's methodology must require that, for EGUs commencing operation on or after January 1, 2001, the State will determine, and notify the Administrator of, each unit's allocation of CAIR Ozone Season NO<E T="52">X</E> allowances by July 31 of the calendar year of the ozone season for which the CAIR Ozone Season NO<E T="52">X</E> allowances are allocated.</P>
            <P>(3) A State that adopts an emissions trading program in accordance with paragraph (aa)(1) or (2) of this section is not required to adopt an emissions trading program in accordance with paragraph (o)(1) or (2) of this section or § 51.153(o)(1) or (2).</P>

            <P>(4) If a State adopts an emissions trading program that differs substantively from subparts AAAA through IIII of part 96 of this chapter, other than as set forth in paragraph <PRTPAGE P="171"/>(aa)(2) of this section, then such emissions trading program is not automatically approved as set forth in paragraph (aa)(1) or (2) of this section and will be reviewed by the Administrator for approvability in accordance with the other provisions of this section, provided that the NO<E T="52">X</E> allowances issued under such emissions trading program shall not, and the SIP revision shall state that such NO<E T="52">X</E> allowances shall not, qualify as CAIR NO<E T="52">X</E> allowances or CAIR Ozone Season NO<E T="52">X</E> allowances under any emissions trading program approved under paragraphs (o)(1) or (2) or (aa)(1) or (2) of this section.</P>
            <P>(bb)(1)(i) The State may revise its SIP to provide that, for each ozone season during which a State implements control measures on EGUs or non-EGUs through an emissions trading program approved under paragraph (aa)(1) or (2) of this section, such EGUs and non-EGUs shall not be subject to the requirements of the State's SIP meeting the requirements of § 51.121, if the State meets the requirement in paragraph (bb)(1)(ii) of this section.</P>

            <P>(ii) For a State under paragraph (bb)(1)(i) of this section, if the State's amount of tons specified in paragraph (q)(2) of this section exceeds the State's amount of NO<E T="52">X</E> SIP Call allowances allocated for the ozone season in 2009 or in any year thereafter for the same types and sizes of units as those covered by the amount of tons specified in paragraph (q)(2) of this section, then the State must replace the former amount for such ozone season by the latter amount for such ozone season in applying paragraph (q) of this section.</P>
            <P>(2) Rhode Island may revise its SIP to provide that, for each ozone season during which Rhode Island implements control measures on EGUs and non-EGUs through an emissions trading program adopted in regulations that differ substantively from subparts AAAA through IIII of part 96 of this chapter as set forth in this paragraph, such EGUs and non-EGUs shall not be subject to the requirements of the State's SIP meeting the requirements of § 51.121.</P>
            <P>(i) Rhode Island must expand the applicability provisions in § 96.304 to include all non-EGUs subject to Rhode Island's emissions trading program approved under § 51.121(p).</P>
            <P>(ii) Rhode Island may decline to adopt the CAIR NO<E T="52">X</E> Ozone Season opt-in provisions of:</P>

            <P>(A) Subpart IIII of this part and the provisions applicable only to CAIR NO<E T="52">X</E> Ozone Season opt-in units in subparts AAAA through HHHH of this part;</P>

            <P>(B) Section 96.388(b) of this chapter and the provisions of subpart IIII of this part applicable only to CAIR NO<E T="52">X</E> Ozone Season opt-in units under § 96.388(b); or</P>

            <P>(C) Section 96.388(c) of this chapter and the provisions of subpart IIII of this part applicable only to CAIR NO<E T="52">X</E> Ozone Season opt-in units under § 96.388(c).</P>

            <P>(iii) Rhode Island may adopt the allocation provisions set forth in subpart EEEE of part 96 of this chapter, provided that Rhode Island must provide for issuance of an amount of CAIR Ozone Season NO<E T="52">X</E> allowances for an ozone season not exceeding 936 tons for 2009 and thereafter;</P>

            <P>(iv) Rhode Island may adopt any methodology for allocating CAIR NO<E T="52">X</E> Ozone Season allowances to individual sources, as follows:</P>

            <P>(A) Rhode Island's methodology must not allow Rhode Island to allocate CAIR Ozone Season NO<E T="52">X</E> allowances for an ozone season in excess of 936 tons for 2009 and thereafter;</P>

            <P>(B) Rhode Island's methodology must require that, for EGUs commencing operation before January 1, 2001, Rhode Island will determine, and notify the Administrator of, each unit's allocation of CAIR NO<E T="52">X</E> allowances by October 31, 2006 for the ozone seasons 2009, 2010, and 2011 and by October 31, 2008 and October 31 of each year thereafter for the ozone season in the 4th year after the year of the notification deadline; and</P>

            <P>(C) Rhode Island's methodology must require that, for EGUs commencing operation on or after January 1, 2001, Rhode Island will determine, and notify the Administrator of, each unit's allocation of CAIR Ozone Season NO<E T="52">X</E> allowances by July 31 of the calendar year of the ozone season for which the CAIR Ozone Season NO<E T="52">X</E> allowances are allocated.<PRTPAGE P="172"/>
            </P>
            <P>(3) Notwithstanding a SIP revision by a State authorized under paragraph (bb)(1) of this section or by Rhode Island under paragraph (bb)(2) of this section, if the State's or Rhode Island's SIP that, without such SIP revision, imposes control measures on EGUs or non-EGUs under § 51.121 is determined by the Administrator to meet the requirements of § 51.121, such SIP shall be deemed to continue to meet the requirements of § 51.121.</P>
            <P>(cc) The terms used in this section shall have the following meanings:</P>
            <P>
              <E T="03">Administrator</E> means the Administrator of the United States Environmental Protection Agency or the Administrator's duly authorized representative.</P>
            <P>
              <E T="03">Allocate</E> or <E T="03">allocation</E> means, with regard to allowances, the determination of the amount of allowances to be initially credited to a source.</P>
            <P>
              <E T="03">Boiler</E> means an enclosed fossil- or other-fuel-fired combustion device used to produce heat and to transfer heat to recirculating water, steam, or other medium.</P>
            <P>
              <E T="03">Bottoming-cycle cogeneration unit</E> means a cogeneration unit in which the energy input to the unit is first used to produce useful thermal energy and at least some of the reject heat from the useful thermal energy application or process is then used for electricity production.</P>
            <P>
              <E T="03">Clean Air Act</E> or <E T="03">CAA</E> means the Clean Air Act, 42 U.S.C. 7401, <E T="03">et seq.</E>
            </P>
            <P>
              <E T="03">Cogeneration unit</E> means a stationary, fossil-fuel-fired boiler or stationary, fossil-fuel-fired combustion turbine:</P>
            <P>(1) Having equipment used to produce electricity and useful thermal energy for industrial, commercial, heating, or cooling purposes through the sequential use of energy; and</P>
            <P>(2) Producing during the 12-month period starting on the date the unit first produces electricity and during any calendar year after which the unit first produces electricity—</P>
            <P>(i) For a topping-cycle cogeneration unit,</P>
            <P>(A) Useful thermal energy not less than 5 percent of total energy output; and</P>
            <P>(B) Useful power that, when added to one-half of useful thermal energy produced, is not less then 42.5 percent of total energy input, if useful thermal energy produced is 15 percent or more of total energy output, or not less than 45 percent of total energy input, if useful thermal energy produced is less than 15 percent of total energy output.</P>
            <P>(ii) For a bottoming-cycle cogeneration unit, useful power not less than 45 percent of total energy input.</P>
            <P>
              <E T="03">Combustion turbine</E> means:</P>
            <P>(1) An enclosed device comprising a compressor, a combustor, and a turbine and in which the flue gas resulting from the combustion of fuel in the combustor passes through the turbine, rotating the turbine; and</P>
            <P>(2) If the enclosed device under paragraph (1) of this definition is combined cycle, any associated heat recovery steam generator and steam turbine.</P>
            <P>
              <E T="03">Commence operation</E> means to have begun any mechanical, chemical, or electronic process, including, with regard to a unit, start-up of a unit's combustion chamber.</P>
            <P>
              <E T="03">Electric generating unit</E> or <E T="03">EGU</E> means:</P>
            <P>(1)(i) Except as provided in paragraph (2) of this definition, a stationary, fossil-fuel-fired boiler or stationary, fossil-fuel-fired combustion turbine serving at any time, since the later of November 15, 1990 or the start-up of the unit's combustion chamber, a generator with nameplate capacity of more than 25 MWe producing electricity for sale.</P>
            <P>(ii) If a stationary boiler or stationary combustion turbine that, under paragraph (1)(i) of this section, is not an electric generating unit begins to combust fossil fuel or to serve a generator with nameplate capacity of more than 25 MWe producing electricity for sale, the unit shall become an electric generating unit as provided in paragraph (1)(i) of this section on the first date on which it both combusts fossil fuel and serves such generator.</P>
            <P>(2) A unit that meets the requirements set forth in paragraphs (2)(i)(A), (2)(ii)(A), or (2)(ii)(B) of this definition paragraph shall not be an electric generating unit:</P>
            <P>(i)(A) Any unit that is an electric generating unit under paragraph (1)(i) or (ii) of this definition:</P>
            <P>
              <E T="03">(1)</E> Qualifying as a cogeneration unit during the 12-month period starting on <PRTPAGE P="173"/>the date the unit first produces electricity and continuing to qualify as a cogeneration unit; and</P>
            <P>
              <E T="03">(2)</E> Not serving at any time, since the later of November 15, 1990 or the start-up of the unit's combustion chamber, a generator with nameplate capacity of more than 25 MWe supplying in any calendar year more than one-third of the unit's potential electric output capacity or 219,000 MWh, whichever is greater, to any utility power distribution system for sale.</P>

            <P>(B) If a unit qualifies as a cogeneration unit during the 12-month period starting on the date the unit first produces electricity and meets the requirements of paragraphs (2)(i)(A) of this section for at least one calendar year, but subsequently no longer meets all such requirements, the unit shall become an electric generating unit starting on the earlier of January 1 after the first calendar year during which the unit first no longer qualifies as a cogeneration unit or January 1 after the first calendar year during which the unit no longer meets the requirements of paragraph (2)(i)(A)<E T="03">(2)</E> of this section.</P>
            <P>(ii)(A) Any unit that is an electric generating unit under paragraph (1)(i) or (ii) of this definition commencing operation before January 1, 1985:</P>
            <P>
              <E T="03">(1)</E> Qualifying as a solid waste incineration unit; and</P>
            <P>
              <E T="03">(2)</E> With an average annual fuel consumption of non-fossil fuel for 1985-1987 exceeding 80 percent (on a Btu basis) and an average annual fuel consumption of non-fossil fuel for any 3 consecutive calendar years after 1990 exceeding 80 percent (on a Btu basis).</P>
            <P>(B) Any unit that is an electric generating unit under paragraph (1)(i) or (ii) of this definition commencing operation on or after January 1, 1985:</P>
            <P>
              <E T="03">(1)</E> Qualifying as a solid waste incineration unit; and</P>
            <P>
              <E T="03">(2)</E> With an average annual fuel consumption of non-fossil fuel for the first 3 calendar years of operation exceeding 80 percent (on a Btu basis) and an average annual fuel consumption of non-fossil fuel for any 3 consecutive calendar years after 1990 exceeding 80 percent (on a Btu basis).</P>
            <P>(C) If a unit qualifies as a solid waste incineration unit and meets the requirements of paragraph (2)(ii)(A) or (B) of this section for at least 3 consecutive calendar years, but subsequently no longer meets all such requirements, the unit shall become an electric generating unit starting on the earlier of January 1 after the first calendar year during which the unit first no longer qualifies as a solid waste incineration unit or January 1 after the first 3 consecutive calendar years after 1990 for which the unit has an average annual fuel consumption of fossil fuel of 20 percent or more.</P>
            <P>
              <E T="03">Fossil fuel</E> means natural gas, petroleum, coal, or any form of solid, liquid, or gaseous fuel derived from such material.</P>
            <P>
              <E T="03">Fossil-fuel-fired</E> means, with regard to a unit, combusting any amount of fossil fuel in any calendar year.</P>
            <P>
              <E T="03">Generator</E> means a device that produces electricity.</P>
            <P>
              <E T="03">Maximum design heat input</E> means:</P>
            <P>(1) Starting from the initial installation of a unit, the maximum amount of fuel per hour (in Btu/hr) that a unit is capable of combusting on a steady state basis as specified by the manufacturer of the unit;</P>
            <P>(2)(i) Except as provided in paragraph (2)(ii) of this definition, starting from the completion of any subsequent physical change in the unit resulting in an increase in the maximum amount of fuel per hour (in Btu/hr) that a unit is capable of combusting on a steady state basis, such increased maximum amount as specified by the person conducting the physical change; or</P>
            <P>(ii) For purposes of applying the definition of the term “potential electrical output capacity,” starting from the completion of any subsequent physical change in the unit resulting in a decrease in the maximum amount of fuel per hour (in Btu/hr) that a unit is capable of combusting on a steady state basis, such decreased maximum amount as specified by the person conducting the physical change.</P>
            <P>
              <E T="03">NAAQS</E> means National Ambient Air Quality Standard.</P>
            <P>
              <E T="03">Nameplate capacity</E> means, starting from the initial installation of a generator, the maximum electrical generating output (in MWe) that the generator is capable of producing on a <PRTPAGE P="174"/>steady state basis and during continuous operation (when not restricted by seasonal or other deratings) as specified by the manufacturer of the generator or, starting from the completion of any subsequent physical change in the generator resulting in an increase in the maximum electrical generating output (in MWe) that the generator is capable of producing on a steady state basis and during continuous operation (when not restricted by seasonal or other deratings), such increased maximum amount as specified by the person conducting the physical change.</P>
            <P>
              <E T="03">Non-EGU</E> means a source of NO<E T="52">X</E> emissions that is not an EGU.</P>
            <P>
              <E T="03">NO</E>
              <E T="52">X</E>
              <E T="03">Budget Trading Program</E> means a multi-state nitrogen oxides air pollution control and emission reduction program approved and administered by the Administrator in accordance with subparts A through I of this part and § 51.121, as a means of mitigating interstate transport of ozone and nitrogen oxides.</P>
            <P>
              <E T="03">NO</E>
              <E T="52">X</E>
              <E T="03">SIP Call allowance</E> means a limited authorization issued by the Administrator under the NO<E T="52">X</E> Budget Trading Program to emit up to one ton of nitrogen oxides during the ozone season of the specified year or any year thereafter, provided that the provision in § 51.121(b)(2)(ii)(E) shall not be used in applying this definition.</P>
            <P>
              <E T="03">Ozone season</E> means the period, which begins May 1 and ends September 30 of any year.</P>
            <P>
              <E T="03">Potential electrical output capacity</E> means 33 percent of a unit's maximum design heat input, divided by 3,413 Btu/kWh, divided by 1,000 kWh/MWh, and multiplied by 8,760 hr/yr.</P>
            <P>
              <E T="03">Sequential use of energy</E> means:</P>
            <P>(1) For a topping-cycle cogeneration unit, the use of reject heat from electricity production in a useful thermal energy application or process; or</P>
            <P>(2) For a bottoming-cycle cogeneration unit, the use of reject heat from useful thermal energy application or process in electricity production.</P>
            <P>
              <E T="03">Solid waste incineration unit</E> means a stationary, fossil-fuel-fired boiler or stationary, fossil-fuel-fired combustion turbine that is a “solid waste incineration unit” as defined in section 129(g)(1) of the Clean Air Act.</P>
            <P>
              <E T="03">Topping-cycle cogeneration unit</E> means a cogeneration unit in which the energy input to the unit is first used to produce useful power, including electricity, and at least some of the reject heat from the electricity production is then used to provide useful thermal energy.</P>
            <P>
              <E T="03">Total energy input</E> means, with regard to a cogeneration unit, total energy of all forms supplied to the cogeneration unit, excluding energy produced by the cogeneration unit itself.</P>
            <P>
              <E T="03">Total energy output</E> means, with regard to a cogeneration unit, the sum of useful power and useful thermal energy produced by the cogeneration unit.</P>
            <P>
              <E T="03">Unit</E> means a stationary, fossil-fuel-fired boiler or a stationary, fossil-fuel-fired combustion turbine.</P>
            <P>
              <E T="03">Useful power</E> means, with regard to a cogeneration unit, electricity or mechanical energy made available for use, excluding any such energy used in the power production process (which process includes, but is not limited to, any on-site processing or treatment of fuel combusted at the unit and any on-site emission controls).</P>
            <P>
              <E T="03">Useful thermal energy</E> means, with regard to a cogeneration unit, thermal energy that is:</P>
            <P>(1) Made available to an industrial or commercial process, excluding any heat contained in condensate return or makeup water;</P>
            <P>(2) Used in a heat application (<E T="03">e.g.</E>, space heating or domestic hot water heating); or</P>
            <P>(3) Used in a space cooling application (<E T="03">i.e.</E>, thermal energy used by an absorption chiller).</P>
            <P>
              <E T="03">Utility power distribution system</E> means the portion of an electricity grid owned or operated by a utility and dedicated to delivering electricity to customers.</P>
            <P>(dd) New Hampshire may revise its SIP to implements control measures on EGUs and non-EGUs through an emissions trading program adopted in regulations that differ substantively from subparts AAAA through IIII of part 96 of this chapter as set forth in this paragraph.</P>

            <P>(1) New Hampshire must expand the applicability provisions in § 96.304 of this chapter to include all non-EGUs subject to New Hampshire's emissions trading program at New Hampshire <PRTPAGE P="175"/>Code of Administrative Rules, chapter Env-A 3200 (2004).</P>
            <P>(2) New Hampshire may decline to adopt the CAIR NO<E T="52">X</E> Ozone Season opt-in provisions of:</P>

            <P>(i) Subpart IIII of this part and the provisions applicable only to CAIR NO<E T="52">X</E> Ozone Season opt-in units in subparts AAAA through HHHH of this part;</P>

            <P>(ii) Section 96.388(b) of this chapter and the provisions of subpart IIII of this part applicable only to CAIR NO<E T="52">X</E> Ozone Season opt-in units under § 96.388(b); or</P>

            <P>(iii) Section 96.388(c) of this chapter and the provisions of subpart IIII of this part applicable only to CAIR NO<E T="52">X</E> Ozone Season opt-in units under § 96.388(c).</P>

            <P>(3) New Hampshire may adopt the allocation provisions set forth in subpart EEEE of part 96 of this chapter, provided that New Hampshire must provide for issuance of an amount of CAIR Ozone Season NO<E T="52">X</E> allowances for an ozone season not exceeding 3,000 tons for 2009 and thereafter;</P>

            <P>(4) New Hampshire may adopt any methodology for allocating CAIR NO<E T="52">X</E> Ozone Season allowances to individual sources, as follows:</P>

            <P>(i) New Hampshire's methodology must not allow New Hampshire to allocate CAIR Ozone Season NO<E T="52">X</E> allowances for an ozone season in excess of 3,000 tons for 2009 and thereafter;</P>

            <P>(ii) New Hampshire's methodology must require that, for EGUs commencing operation before January 1, 2001, New Hampshire will determine, and notify the Administrator of, each unit's allocation of CAIR NO<E T="52">X</E> allowances by October 31, 2006 for the ozone seasons 2009, 2010, and 2011 and by October 31, 2008 and October 31 of each year thereafter for the ozone season in the 4th year after the year of the notification deadline; and</P>

            <P>(iii) New Hampshire's methodology must require that, for EGUs commencing operation on or after January 1, 2001, New Hampshire will determine, and notify the Administrator of, each unit's allocation of CAIR Ozone Season NO<E T="52">X</E> allowances by July 31 of the calendar year of the ozone season for which the CAIR Ozone Season NO<E T="52">X</E> allowances are allocated.</P>

            <P>(ee) Notwithstanding any other provision of this section, a State may adopt, and include in a SIP revision submitted by March 31, 2007, regulations relating to the Federal CAIR NO<E T="52">X</E> Ozone Season Trading Program under subparts AAAA through HHHH of part 97 of this chapter as follows:</P>
            <P>(1) The State adopt, as applicability provisions replacing the provisions in § 97.304 of this chapter, provisions for applicability that are substantively identical to the provisions in § 96.304 of this chapter expanded to include all non-EGUs subject to the State's emissions trading program approved under § 51.121(p).</P>
            <P>(2) The State may adopt, as CAIR NO<E T="52">X</E> Ozone Season allowance allocation provisions replacing the provisions in subpart EEEE of part 97 of this chapter:</P>
            <P>(i) Allocation provisions substantively identical to subpart EEEE of part 96 of this chapter, under which the permitting authority makes the allocations; or</P>
            <P>(ii) Any methodology for allocating CAIR NO<E T="52">X</E> Ozone Season allowances to individual sources under which the permitting authority makes the allocations, provided that:</P>

            <P>(A) The State may provide for issuance of an amount of CAIR Ozone Season NO<E T="52">X</E> allowances for an ozone season, in addition to the amount in the State's Ozone Season EGU NO<E T="52">X</E> Budget for such ozone season, not exceeding the portion of the State's trading program budget, under the State's emissions trading program approved under § 51.121(p), attributed to the non-EGUs that the applicability provisions in § 96.304 of this chapter are expanded to include under paragraph (ee)(1) of this section.</P>

            <P>(B) The State's methodology must not allow the State to allocate CAIR Ozone Season NO<E T="52">X</E> allowances for an ozone season in excess of the amount in the State's Ozone Season EGU NO<E T="52">X</E> Budget for such ozone season plus any additional amount of CAIR Ozone Season NO<E T="52">X</E> allowances issued under paragraph (ee)(2)(ii)(A) of this section for such ozone season.<PRTPAGE P="176"/>
            </P>

            <P>(C) The State's methodology must require that, for EGUs commencing operation before January 1, 2001, the permitting authority will determine, and notify the Administrator of, each unit's allocation of CAIR NO<E T="52">X</E> Ozone Season allowances by April 30, 2007 for 2009, 2010, and 2011 and by October 31, 2008 and October 31 of each year thereafter for the 4th year after the year of the notification deadline.</P>

            <P>(D) The State's methodology must require that, for EGUs commencing operation on or after January 1, 2001, the permitting authority will determine, and notify the Administrator of, each unit's allocation of CAIR NO<E T="52">X</E> Ozone Season allowances by July 31 of the year for which the CAIR NO<E T="52">X</E> Ozone Season allowances are allocated.</P>
            <P>(3) The State may adopt CAIR opt-in unit provisions as follows:</P>

            <P>(i) Provisions for CAIR opt-in units, including provisions for applications for CAIR opt-in permits, approval of CAIR opt-in permits, treatment of units as CAIR opt-in units, and allocation and recordation of CAIR NO<E T="52">X</E> Ozone Season allowances for CAIR opt-in units, that are substantively identical to subpart IIII of part 96 of this chapter and the provisions of subparts AAAA through HHHH that are applicable to CAIR opt-in units or units for which a CAIR opt-in permit application is submitted and not withdrawn and a CAIR opt-in permit is not yet issued or denied;</P>

            <P>(ii) Provisions for CAIR opt-in units, including provisions for applications for CAIR opt-in permits, approval of CAIR opt-in permits, treatment of units as CAIR opt-in units, and allocation and recordation of CAIR NO<E T="52">X</E> Ozone Season allowances for CAIR opt-in units, that are substantively identical to subpart IIII of part 96 of this chapter and the provisions of subparts AAAA through HHHH that are applicable to CAIR opt-in units or units for which a CAIR opt-in permit application is submitted and not withdrawn and a CAIR opt-in permit is not yet issued or denied, except that the provisions exclude § 96.388(b) of this chapter and the provisions of subpart IIII of part 96 of this chapter that apply only to units covered by § 96.388(b) of this chapter; or</P>

            <P>(iii) Provisions for applications for CAIR opt-in units, including provisions for CAIR opt-in permits, approval of CAIR opt-in permits, treatment of units as CAIR opt-in units, and allocation and recordation of CAIR NO<E T="52">X</E> allowances for CAIR opt-in units, that are substantively identical to subpart IIII of part 96 of this chapter and the provisions of subparts AAAA through HHHH that are applicable to CAIR opt-in units or units for which a CAIR opt-in permit application is submitted and not withdrawn and a CAIR opt-in permit is not yet issued or denied, except that the provisions exclude § 96.388(c) of this chapter and the provisions of subpart IIII of part 96 of this chapter that apply only to units covered by § 96.388(c) of this chapter.</P>
            <CITA>[70 FR 25319, May 12, 2005, as amended at 71 FR 25301, 25370, Apr. 28, 2006]</CITA>
          </SECTION>
          <SECTION>
            <SECTNO>§ 51.124</SECTNO>
            <SUBJECT>Findings and requirements for submission of State implementation plan revisions relating to emissions of sulfur dioxide pursuant to the Clean Air Interstate Rule.</SUBJECT>

            <P>(a) Under section 110(a)(1) of the CAA, 42 U.S.C. 7410(a)(1), the Administrator determines that each State identified in paragraph (c) of this section must submit a SIP revision to comply with the requirements of section 110(a)(2)(D)(i)(I) of the CAA, 42 U.S.C. 7410(a)(2)(D)(i)(I), through the adoption of adequate provisions prohibiting sources and other activities from emitting SO<E T="52">2</E> in amounts that will contribute significantly to nonattainment in, or interfere with maintenance by, one or more other States with respect to the fine particles (PM<E T="52">2.5</E>) NAAQS.</P>
            <P>(b) For each State identified in paragraph (c) of this section, the SIP revision required under paragraph (a) of this section will contain adequate provisions, for purposes of complying with section 110(a)(2)(D)(i)(I) of the CAA, 42 U.S.C. 7410(a)(2)(D)(i)(I), only if the SIP revision contains control measures that assure compliance with the applicable requirements of this section.</P>

            <P>(c) The following States are subject to the requirements of this section: Alabama, Delaware, Florida, Georgia, <PRTPAGE P="177"/>Illinois, Indiana, Iowa, Kentucky, Louisiana, Maryland, Michigan, Minnesota, Mississippi, Missouri, New Jersey, New York, North Carolina, Ohio, Pennsylvania, South Carolina, Tennessee, Texas, Virginia, West Virginia, Wisconsin, and the District of Columbia.</P>
            <P>(d)(1) The SIP revision under paragraph (a) of this section must be submitted to EPA by no later than September 11, 2006.</P>
            <P>(2) The requirements of appendix V to this part shall apply to the SIP revision under paragraph (a) of this section.</P>
            <P>(3) The State shall deliver 5 copies of the SIP revision under paragraph (a) of this section to the appropriate Regional Office, with a letter giving notice of such action.</P>

            <P>(e) The State's SIP revision shall contain control measures and demonstrate that they will result in compliance with the State's Annual EGU SO<E T="52">2</E> Budget, if applicable, and achieve the State's Annual Non-EGU SO<E T="52">2</E> Reduction Requirement, if applicable, for the appropriate periods. The amounts of the State's Annual EGU SO<E T="52">2</E> Budget and Annual Non-EGU SO<E T="52">2</E> Reduction Requirement shall be determined as follows:</P>
            <P>(1)(i) The Annual EGU SO<E T="52">2</E> Budget for the State is defined as the total amount of SO<E T="52">2</E> emissions from all EGUs in that State for a year, if the State meets the requirements of paragraph (a) of this section by imposing control measures, at least in part, on EGUs. If the State imposes control measures under this section on only EGUs, the Annual EGU SO<E T="52">2</E> Budget for the State shall not exceed the amount, during the indicated periods, specified in paragraph (e)(2) of this section.</P>
            <P>(ii) The Annual Non-EGU SO<E T="52">2</E> Reduction Requirement, if applicable, is defined as the total amount of SO<E T="52">2</E> emission reductions that the State demonstrates, in accordance with paragraph (g) of this section, it will achieve from non-EGUs during the appropriate period. If the State meets the requirements of paragraph (a) of this section by imposing control measures on only non-EGUs, then the State's Annual Non-EGU SO<E T="52">2</E> Reduction Requirement shall equal or exceed, during the appropriate periods, the amount determined in accordance with paragraph (e)(3) of this section.</P>
            <P>(iii) If a State meets the requirements of paragraph (a) of this section by imposing control measures on both EGUs and non-EGUs, then:</P>
            <P>(A) The Annual Non-EGU SO<E T="52">2</E> Reduction Requirement shall equal or exceed the difference between the amount specified in paragraph (e)(2) of this section for the appropriate period and the amount of the State's Annual EGU SO<E T="52">2</E> Budget specified in the SIP revision for the appropriate period; and</P>
            <P>(B) The Annual EGU SO<E T="52">2</E> Budget shall not exceed, during the indicated periods, the amount specified in paragraph (e)(2) of this section plus the amount of the Annual Non-EGU SO<E T="52">2</E> Reduction Requirement under paragraph (e)(1)(iii)(A) of this section for the appropriate period.</P>

            <P>(2) For a State that complies with the requirements of paragraph (a) of this section by imposing control measures on only EGUs, the amount of the Annual EGU SO<E T="52">2</E> Budget, in tons of SO<E T="52">2</E> per year, shall be as follows, for the indicated State for the indicated period:</P>
            <GPOTABLE CDEF="s50,18,18" COLS="3" OPTS="L2">
              <BOXHD>
                <CHED H="1">State</CHED>
                <CHED H="1">Annual EGU SO<E T="52">2</E> budget for 2010-2014 (tons)</CHED>
                <CHED H="1">Annual EGU SO<E T="52">2</E> budget for 2015 and thereafter (tons)</CHED>
              </BOXHD>
              <ROW>
                <ENT I="01">Alabama</ENT>
                <ENT>157,582</ENT>
                <ENT>110,307</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Delaware</ENT>
                <ENT>22,411</ENT>
                <ENT>15,687</ENT>
              </ROW>
              <ROW>
                <ENT I="01">District of Columbia</ENT>
                <ENT>708</ENT>
                <ENT>495</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Florida</ENT>
                <ENT>253,450</ENT>
                <ENT>177,415</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Georgia</ENT>
                <ENT>213,057</ENT>
                <ENT>149,140</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Illinois</ENT>
                <ENT>192,671</ENT>
                <ENT>134,869</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Indiana</ENT>
                <ENT>254,599</ENT>
                <ENT>178,219</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Iowa</ENT>
                <ENT>64,095</ENT>
                <ENT>44,866</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Kentucky</ENT>
                <ENT>188,773</ENT>
                <ENT>132,141</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Louisiana</ENT>
                <ENT>59,948</ENT>
                <ENT>41,963</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Maryland</ENT>
                <ENT>70,697</ENT>
                <ENT>49,488</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Michigan</ENT>
                <ENT>178,605</ENT>
                <ENT>125,024</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Minnesota</ENT>
                <ENT>49,987</ENT>
                <ENT>34,991</ENT>
              </ROW>
              <ROW>
                <PRTPAGE P="178"/>
                <ENT I="01">Mississippi</ENT>
                <ENT>33,763</ENT>
                <ENT>23,634</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Missouri</ENT>
                <ENT>137,214</ENT>
                <ENT>96,050</ENT>
              </ROW>
              <ROW>
                <ENT I="01">New Jersey</ENT>
                <ENT>32,392</ENT>
                <ENT>22,674</ENT>
              </ROW>
              <ROW>
                <ENT I="01">New York</ENT>
                <ENT>135,139</ENT>
                <ENT>94,597</ENT>
              </ROW>
              <ROW>
                <ENT I="01">North Carolina</ENT>
                <ENT>137,342</ENT>
                <ENT>96,139</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Ohio</ENT>
                <ENT>333,520</ENT>
                <ENT>233,464</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Pennsylvania</ENT>
                <ENT>275,990</ENT>
                <ENT>193,193</ENT>
              </ROW>
              <ROW>
                <ENT I="01">South Carolina</ENT>
                <ENT>57,271</ENT>
                <ENT>40,089</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Tennessee</ENT>
                <ENT>137,216</ENT>
                <ENT>96,051</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Texas</ENT>
                <ENT>320,946</ENT>
                <ENT>224,662</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Virginia</ENT>
                <ENT>63,478</ENT>
                <ENT>44,435</ENT>
              </ROW>
              <ROW>
                <ENT I="01">West Virginia</ENT>
                <ENT>215,881</ENT>
                <ENT>151,117</ENT>
              </ROW>
              <ROW>
                <ENT I="01">Wisconsin</ENT>
                <ENT>87,264</ENT>
                <ENT>61,085</ENT>
              </ROW>
            </GPOTABLE>

            <P>(3) For a State that complies with the requirements of paragraph (a) of this section by imposing control measures on only non-EGUs, the amount of the Annual Non-EGU SO<E T="52">2</E> Reduction Requirement, in tons of SO<E T="52">2</E> per year, shall be determined, for the State for 2010 and thereafter, by subtracting the amount of the State's Annual EGU SO<E T="52">2</E> Budget for the appropriate year, specified in paragraph (e)(2) of this section, from an amount equal to 2 times the State's Annual EGU SO<E T="52">2</E> Budget for 2010 through 2014, specified in paragraph (e)(2) of this section.</P>
            <P>(f) Each SIP revision must set forth control measures to meet the amounts specified in paragraph (e) of this section, as applicable, including the following:</P>
            <P>(1) A description of enforcement methods including, but not limited to:</P>
            <P>(i) Procedures for monitoring compliance with each of the selected control measures;</P>
            <P>(ii) Procedures for handling violations; and</P>
            <P>(iii) A designation of agency responsibility for enforcement of implementation.</P>

            <P>(2)(i) If a State elects to impose control measures on EGUs, then those measures must impose an annual SO<E T="52">2</E> mass emissions cap on all such sources in the State.</P>

            <P>(ii) If a State elects to impose control measures on fossil fuel-fired non-EGUs that are boilers or combustion turbines with a maximum design heat input greater than 250 mmBtu/hr, then those measures must impose an annual SO<E T="52">2</E> mass emissions cap on all such sources in the State.</P>

            <P>(iii) If a State elects to impose control measures on non-EGUs other than those described in paragraph (f)(2)(ii) of this section, then those measures must impose an annual SO<E T="52">2</E> mass emissions cap on all such sources in the State, or the State must demonstrate why such emissions cap is not practicable, and adopt alternative requirements that ensure that the State will comply with its requirements under paragraph (e) of this section, as applicable, in 2010 and subsequent years.</P>

            <P>(g)(1) Each SIP revision that contains control measures covering non-EGUs as part or all of a State's obligation in meeting its requirement under paragraph (a) of this section must demonstrate that such control measures are adequate to provide for the timely compliance with the State's Annual Non-EGU SO<E T="52">2</E> Reduction Requirement under paragraph (e) of this section and are not adopted or implemented by the State, as of May 12, 2005, and are not adopted or implemented by the federal government, as of the date of submission of the SIP revision by the State to EPA.</P>
            <P>(2) The demonstration under paragraph (g)(1) of this section must include the following, with respect to each source category of non-EGUs for which the SIP revision requires control measures:</P>
            <P>(i) A detailed historical baseline inventory of SO<E T="52">2</E> mass emissions from the source category in a representative year consisting, at the State's election, of 2002, 2003, 2004, or 2005, or an average of 2 or more of those years, absent the control measures specified in the SIP revision.<PRTPAGE P="179"/>
            </P>
            <P>(A) This inventory must represent estimates of actual emissions based on monitoring data in accordance with part 75 of this chapter, if the source category is subject to part 75 monitoring requirements in accordance with part 75 of this chapter.</P>
            <P>(B) In the absence of monitoring data in accordance with part 75 of this chapter, actual emissions must be quantified, to the maximum extent practicable, with the same degree of assurance with which emissions are quantified for sources subject to part 75 of this chapter and using source-specific or source-category-specific assumptions that ensure a source's or source category's actual emissions are not overestimated. If a State uses factors to estimate emissions, production or utilization, or effectiveness of controls or rules for a source category, such factors must be chosen to ensure that emissions are not overestimated.</P>
            <P>(C) For measures to reduce emissions from motor vehicles, emission estimates must be based on an emissions model that has been approved by EPA for use in SIP development and must be consistent with the planning assumptions regarding vehicle miles traveled and other factors current at the time of the SIP development.</P>
            <P>(D) For measures to reduce emissions from nonroad engines or vehicles, emission estimates methodologies must be approved by EPA.</P>
            <P>(ii) A detailed baseline inventory of SO<E T="52">2</E> mass emissions from the source category in the years 2010 and 2015, absent the control measures specified in the SIP revision and reflecting changes in these emissions from the historical baseline year to the years 2010 and 2015, based on projected changes in the production input or output, population, vehicle miles traveled, economic activity, or other factors as applicable to this source category.</P>

            <P>(A) These inventories must account for implementation of any control measures that are adopted or implemented by the State, as of May 12, 2005, or adopted or implemented by the federal government, as of the date of submission of the SIP revision by the State to EPA, and must exclude any control measures specified in the SIP revision to meet the SO<E T="52">2</E> emissions reduction requirements of this section.</P>
            <P>(B) Economic and population forecasts must be as specific as possible to the applicable industry, State, and county of the source or source category and must be consistent with both national projections and relevant official planning assumptions, including estimates of population and vehicle miles traveled developed through consultation between State and local transportation and air quality agencies. However, if these official planning assumptions are inconsistent with official U.S. Census projections of population or with energy consumption projections contained in the U.S. Department of Energy's most recent Annual Energy Outlook, then the SIP revision must make adjustments to correct the inconsistency or must demonstrate how the official planning assumptions are more accurate.</P>
            <P>(C) These inventories must account for any changes in production method, materials, fuels, or efficiency that are expected to occur between the historical baseline year and 2010 or 2015, as appropriate.</P>
            <P>(iii) A projection of SO<E T="52">2</E> mass emissions in 2010 and 2015 from the source category assuming the same projected changes as under paragraph (g)(2)(ii) of this section and resulting from implementation of each of the control measures specified in the SIP revision.</P>
            <P>(A) These inventories must address the possibility that the State's new control measures may cause production or utilization, and emissions, to shift to unregulated or less stringently regulated sources in the source category in the same or another State, and these inventories must include any such amounts of emissions that may shift to such other sources.</P>

            <P>(B) The State must provide EPA with a summary of the computations, assumptions, and judgments used to determine the degree of reduction in projected 2010 and 2015 SO<E T="52">2</E> emissions that will be achieved from the implementation of the new control measures compared to the relevant baseline emissions inventory.</P>

            <P>(iv) The result of subtracting the amounts in paragraph (g)(2)(iii) of this section for 2010 and 2015, respectively, <PRTPAGE P="180"/>from the lower of the amounts in paragraph (g)(2)(i) or (g)(2)(ii) of this section for 2010 and 2015, respectively, may be credited towards the State's Annual Non-EGU SO<E T="52">2</E> Reduction Requirement in paragraph (e)(3) of this section for the appropriate period.</P>
            <P>(v) Each SIP revision must identify the sources of the data used in each estimate and each projection of emissions.</P>
            <P>(h) Each SIP revision must comply with § 51.116 (regarding data availability).</P>
            <P>(i) Each SIP revision must provide for monitoring the status of compliance with any control measures adopted to meet the State's requirements under paragraph (e) of this section, as follows:</P>
            <P>(1) The SIP revision must provide for legally enforceable procedures for requiring owners or operators of stationary sources to maintain records of, and periodically report to the State:</P>
            <P>(i) Information on the amount of SO<E T="52">2</E> emissions from the stationary sources; and</P>
            <P>(ii) Other information as may be necessary to enable the State to determine whether the sources are in compliance with applicable portions of the control measures;</P>
            <P>(2) The SIP revision must comply with § 51.212 (regarding testing, inspection, enforcement, and complaints);</P>
            <P>(3) If the SIP revision contains any transportation control measures, then the SIP revision must comply with § 51.213 (regarding transportation control measures);</P>
            <P>(4)(i) If the SIP revision contains measures to control EGUs, then the SIP revision must require such sources to comply with the monitoring, recordkeeping, and reporting provisions of part 75 of this chapter.</P>
            <P>(ii) If the SIP revision contains measures to control fossil fuel-fired non-EGUs that are boilers or combustion turbines with a maximum design heat input greater than 250 mmBtu/hr, then the SIP revision must require such sources to comply with the monitoring, recordkeeping, and reporting provisions of part 75 of this chapter.</P>
            <P>(iii) If the SIP revision contains measures to control any other non-EGUs that are not described in paragraph (i)(4)(ii) of this section, then the SIP revision must require such sources to comply with the monitoring, recordkeeping, and reporting provisions of part 75 of this chapter, or the State must demonstrate why such requirements are not practicable and adopt alternative requirements that ensure that the required emissions reductions will be quantified, to the maximum extent practicable, with the same degree of assurance with which emissions are quantified for sources subject to part 75 of this chapter.</P>
            <P>(j) Each SIP revision must show that the State has legal authority to carry out the SIP revision, including authority to:</P>

            <P>(1) Adopt emissions standards and limitations and any other measures necessary for attainment and maintenance of the State's relevant Annual EGU SO<E T="52">2</E> Budget or the Annual Non-EGU SO<E T="52">2</E> Reduction Requirement, as applicable, under paragraph (e) of this section;</P>
            <P>(2) Enforce applicable laws, regulations, and standards and seek injunctive relief;</P>
            <P>(3) Obtain information necessary to determine whether air pollution sources are in compliance with applicable laws, regulations, and standards, including authority to require recordkeeping and to make inspections and conduct tests of air pollution sources; and</P>
            <P>(4)(i) Require owners or operators of stationary sources to install, maintain, and use emissions monitoring devices and to make periodic reports to the State on the nature and amounts of emissions from such stationary sources; and</P>
            <P>(ii) Make the data described in paragraph (j)(4)(i) of this section available to the public within a reasonable time after being reported and as correlated with any applicable emissions standards or limitations.</P>
            <P>(k)(1) The provisions of law or regulation that the State determines provide the authorities required under this section must be specifically identified, and copies of such laws or regulations must be submitted with the SIP revision.</P>

            <P>(2) Legal authority adequate to fulfill the requirements of paragraphs (j)(3) <PRTPAGE P="181"/>and (4) of this section may be delegated to the State under section 114 of the CAA.</P>
            <P>(l)(1) A SIP revision may assign legal authority to local agencies in accordance with § 51.232.</P>
            <P>(2) Each SIP revision must comply with § 51.240 (regarding general plan requirements).</P>
            <P>(m) Each SIP revision must comply with § 51.280 (regarding resources).</P>
            <P>(n) Each SIP revision must provide for State compliance with the reporting requirements in § 51.125.</P>

            <P>(o)(1) Notwithstanding any other provision of this section, if a State adopts regulations substantively identical to subparts AAA through III of part 96 of this chapter (CAIR SO<E T="52">2</E> Trading Program), incorporates such subparts by reference into its regulations, or adopts regulations that differ substantively from such subparts only as set forth in paragraph (o)(2) of this section, then such emissions trading program in the State's SIP revision is automatically approved as meeting the requirements of paragraph (e) of this section, provided that the State has the legal authority to take such action and to implement its responsibilities under such regulations.</P>
            <P>(2) If a State adopts an emissions trading program that differs substantively from subparts AAA through III of part 96 of this chapter only as follows, then the emissions trading program is approved as set forth in paragraph (o)(1) of this section.</P>
            <P>(i) The State may decline to adopt the CAIR SO<E T="52">2</E> opt-in provisions of subpart III of this part and the provisions applicable only to CAIR SO<E T="52">2</E> opt-in units in subparts AAA through HHH of this part.</P>
            <P>(ii) The State may decline to adopt the CAIR SO<E T="52">2</E> opt-in provisions of § 96.288(b) of this chapter and the provisions of subpart III of this part applicable only to CAIR SO<E T="52">2</E> opt-in units under § 96.288(b).</P>
            <P>(iii) The State may decline to adopt the CAIR SO<E T="52">2</E> opt-in provisions of § 96.288(c) of this chapter and the provisions of subpart II of this part applicable only to CAIR SO<E T="52">2</E> opt-in units under § 96.288(c).</P>
            <P>(3) A State that adopts an emissions trading program in accordance with paragraph (o)(1) or (2) of this section is not required to adopt an emissions trading program in accordance with § 96.123 (o)(1) or (2) or (aa)(1) or (2) of this chapter.</P>

            <P>(4) If a State adopts an emissions trading program that differs substantively from subparts AAA through III of part 96 of this chapter, other than as set forth in paragraph (o)(2) of this section, then such emissions trading program is not automatically approved as set forth in paragraph (o)(1) or (2) of this section and will be reviewed by the Administrator for approvability in accordance with the other provisions of this section, provided that the SO<E T="52">2</E> allowances issued under such emissions trading program shall not, and the SIP revision shall state that such SO<E T="52">2</E> allowances shall not, qualify as CAIR SO<E T="52">2</E> allowances under any emissions trading program approved under paragraph (o)(1) or (2) of this section.</P>
            <P>(p) If a State's SIP revision does not contain an emissions trading program approved under paragraph (o)(1) or (2) of this section but contains control measures on EGUs as part or all of a State's obligation in meeting its requirement under paragraph (a) of this section:</P>
            <P>(1) The SIP revision shall provide, for each year that the State has such obligation, for the permanent retirement of an amount of Acid Rain allowances allocated to sources in the State for that year and not deducted by the Administrator under the Acid Rain Program and any emissions trading program approved under paragraph (o)(1) or (2) of this section, equal to the difference between—</P>
            <P>(A) The total amount of Acid Rain allowances allocated under the Acid Rain Program to the sources in the State for that year; and</P>

            <P>(B) If the State's SIP revision contains only control measures on EGUs, the State's Annual EGU SO<E T="52">2</E> Budget for the appropriate period as specified in paragraph (e)(2) of this section or, if the State's SIP revision contains control measures on EGUs and non-EGUs, the State's Annual EGU SO<E T="52">2</E> Budget for the appropriate period as specified in the SIP revision.<PRTPAGE P="182"/>
            </P>
            <P>(2) The SIP revision providing for permanent retirement of Acid Rain allowances under paragraph (p)(1) of this section must ensure that such allowances are not available for deduction by the Administrator under the Acid Rain Program and any emissions trading program approved under paragraph (o)(1) or (2) of this section.</P>
            <P>(q) The terms used in this section shall have the following meanings:</P>
            <P>
              <E T="03">Acid Rain allowance</E> means a limited authorization issued by the Administrator under the Acid Rain Program to emit up to one ton of sulfur dioxide during the specified year or any year thereafter, except as otherwise provided by the Administrator.</P>
            <P>
              <E T="03">Acid Rain Program</E> means a multi-State sulfur dioxide and nitrogen oxides air pollution control and emissions reduction program established by the Administrator under title IV of the CAA and parts 72 through 78 of this chapter.</P>
            <P>
              <E T="03">Administrator</E> means the Administrator of the United States Environmental Protection Agency or the Administrator's duly authorized representative.</P>
            <P>
              <E T="03">Allocate</E> or <E T="03">allocation</E> means, with regard to allowances, the determination of the amount of allowances to be initially credited to a source.</P>
            <P>
              <E T="03">Boiler</E> means an enclosed fossil- or other-fuel-fired combustion device used to produce heat and to transfer heat to recirculating water, steam, or other medium.</P>
            <P>
              <E T="03">Bottoming-cycle cogeneration unit</E> means a cogeneration unit in which the energy input to the unit is first used to produce useful thermal energy and at least some of the reject heat from the useful thermal energy application or process is then used for electricity production.</P>
            <P>
              <E T="03">Clean Air Act</E> or <E T="03">CAA</E> means the Clean Air Act, 42 U.S.C. 7401, <E T="03">et seq.</E>
            </P>
            <P>
              <E T="03">Cogeneration unit</E> means a stationary, fossil-fuel-fired boiler or stationary, fossil-fuel-fired combustion turbine:</P>
            <P>(1) Having equipment used to produce electricity and useful thermal energy for industrial, commercial, heating, or cooling purposes through the sequential use of energy; and</P>
            <P>(2) Producing during the 12-month period starting on the date the unit first produces electricity and during any calendar year after which the unit first produces electricity—</P>
            <P>(i) For a topping-cycle cogeneration unit,</P>
            <P>(A) Useful thermal energy not less than 5 percent of total energy output; and</P>
            <P>(B) Useful power that, when added to one-half of useful thermal energy produced, is not less then 42.5 percent of total energy input, if useful thermal energy produced is 15 percent or more of total energy output, or not less than 45 percent of total energy input, if useful thermal energy produced is less than 15 percent of total energy output.</P>
            <P>(ii) For a bottoming-cycle cogeneration unit, useful power not less than 45 percent of total energy input.</P>
            <P>
              <E T="03">Combustion turbine</E> means:</P>
            <P>(1) An enclosed device comprising a compressor, a combustor, and a turbine and in which the flue gas resulting from the combustion of fuel in the combustor passes through the turbine, rotating the turbine; and</P>
            <P>(2) If the enclosed device under paragraph (1) of this definition is combined cycle, any associated heat recovery steam generator and steam turbine.</P>
            <P>
              <E T="03">Commence operation</E> means to have begun any mechanical, chemical, or electronic process, including, with regard to a unit, start-up of a unit's combustion chamber.</P>
            <P>
              <E T="03">Electric generating unit</E> or <E T="03">EGU</E> means:</P>
            <P>(1)(i) Except as provided in paragraph (2) of this definition, a stationary, fossil-fuel-fired boiler or stationary, fossil-fuel-fired combustion turbine serving at any time, since the later of November 15, 1990 or the start-up of the unit's combustion chamber, a generator with nameplate capacity of more than 25 MWe producing electricity for sale.</P>

            <P>(ii) If a stationary boiler or stationary combustion turbine that, under paragraph (1)(i) of this section, is not an electric generating unit begins to combust fossil fuel or to serve a generator with nameplate capacity of more than 25 MWe producing electricity for sale, the unit shall become an electric generating unit as provided in paragraph (1)(i) of this section on the first date on which it both combusts fossil fuel and serves such generator.<PRTPAGE P="183"/>
            </P>
            <P>(2) A unit that meets the requirements set forth in paragraphs (2)(i)(A), (2)(ii)(A), or (2)(ii)(B) of this definition paragraph shall not be an electric generating unit:</P>
            <P>(i)(A) Any unit that is an electric generating unit under paragraph (1)(i) or (ii) of this definition:</P>
            <P>
              <E T="03">(1)</E> Qualifying as a cogeneration unit during the 12-month period starting on the date the unit first produces electricity and continuing to qualify as a cogeneration unit; and</P>
            <P>
              <E T="03">(2)</E> Not serving at any time, since the later of November 15, 1990 or the start-up of the unit's combustion chamber, a generator with nameplate capacity of more than 25 MWe supplying in any calendar year more than one-third of the unit's potential electric output capacity or 219,000 MWh, whichever is greater, to any utility power distribution system for sale.</P>

            <P>(B) If a unit qualifies as a cogeneration unit during the 12-month period starting on the date the unit first produces electricity and meets the requirements of paragraphs (2)(i)(A) of this section for at least one calendar year, but subsequently no longer meets all such requirements, the unit shall become an electric generating unit starting on the earlier of January 1 after the first calendar year during which the unit first no longer qualifies as a cogeneration unit or January 1 after the first calendar year during which the unit no longer meets the requirements of paragraph (2)(i)(A)<E T="03">(2)</E> of this section.</P>
            <P>(ii)(A) Any unit that is an electric generating unit under paragraph (1)(i) or (ii) of this definition commencing operation before January 1, 1985:</P>
            <P>
              <E T="03">(1)</E> Qualifying as a solid waste incineration unit; and</P>
            <P>
              <E T="03">(2)</E> With an average annual fuel consumption of non-fossil fuel for 1985-1987 exceeding 80 percent (on a Btu basis) and an average annual fuel consumption of non-fossil fuel for any 3 consecutive calendar years after 1990 exceeding 80 percent (on a Btu basis).</P>
            <P>(B) Any unit that is an electric generating unit under paragraph (1)(i) or (ii) of this definition commencing operation on or after January 1, 1985:</P>
            <P>
              <E T="03">(1)</E> Qualifying as a solid waste incineration unit; and</P>
            <P>
              <E T="03">(2)</E> With an average annual fuel consumption of non-fossil fuel for the first 3 calendar years of operation exceeding 80 percent (on a Btu basis) and an average annual fuel consumption of non-fossil fuel for any 3 consecutive calendar years after 1990 exceeding 80 percent (on a Btu basis).</P>
            <P>(C) If a unit qualifies as a solid waste incineration unit and meets the requirements of paragraph (2)(ii)(A) or (B) of this section for at least 3 consecutive calendar years, but subsequently no longer meets all such requirements, the unit shall become an electric generating unit starting on the earlier of January 1 after the first calendar year during which the unit first no longer qualifies as a solid waste incineration unit or January 1 after the first 3 consecutive calendar years after 1990 for which the unit has an average annual fuel consumption of fossil fuel of 20 percent or more.</P>
            <P>
              <E T="03">Fossil fuel</E> means natural gas, petroleum, coal, or any form of solid, liquid, or gaseous fuel derived from such material.</P>
            <P>
              <E T="03">Fossil-fuel-fired</E> means, with regard to a unit, combusting any amount of fossil fuel in any calendar year.</P>
            <P>
              <E T="03">Generator</E> means a device that produces electricity.</P>
            <P>
              <E T="03">Maximum design heat input</E> means:</P>
            <P>(1) Starting from the initial installation of a unit, the maximum amount of fuel per hour (in Btu/hr) that a unit is capable of combusting on a steady state basis as specified by the manufacturer of the unit;</P>
            <P>(2)(i) Except as provided in paragraph (2)(ii) of this definition, starting from the completion of any subsequent physical change in the unit resulting in an increase in the maximum amount of fuel per hour (in Btu/hr) that a unit is capable of combusting on a steady state basis, such increased maximum amount as specified by the person conducting the physical change; or</P>

            <P>(ii) For purposes of applying the definition of the term “potential electrical output capacity,” starting from the completion of any subsequent physical change in the unit resulting in a decrease in the maximum amount of fuel per hour (in Btu/hr) that a unit is capable of combusting on a steady state basis, such decreased maximum <PRTPAGE P="184"/>amount as specified by the person conducting the physical change.</P>
            <P>
              <E T="03">NAAQS</E> means National Ambient Air Quality Standard.</P>
            <P>
              <E T="03">Nameplate capacity</E> means, starting from the initial installation of a generator, the maximum electrical generating output (in MWe) that the generator is capable of producing on a steady state basis and during continuous operation (when not restricted by seasonal or other deratings) as specified by the manufacturer of the generator or, starting from the completion of any subsequent physical change in the generator resulting in an increase in the maximum electrical generating output (in MWe) that the generator is capable of producing on a steady state basis and during continuous operation (when not restricted by seasonal or other deratings), such increased maximum amount as specified by the person conducting the physical change.</P>
            <P>
              <E T="03">Non-EGU</E> means a source of SO<E T="52">2</E> emissions that is not an EGU.</P>
            <P>
              <E T="03">Potential electrical output capacity</E> means 33 percent of a unit's maximum design heat input, divided by 3,413 Btu/kWh, divided by 1,000 kWh/MWh, and multiplied by 8,760 hr/yr.</P>
            <P>
              <E T="03">Sequential use of energy</E> means:</P>
            <P>(1) For a topping-cycle cogeneration unit, the use of reject heat from electricity production in a useful thermal energy application or process; or</P>
            <P>(2) For a bottoming-cycle cogeneration unit, the use of reject heat from useful thermal energy application or process in electricity production.</P>
            <P>
              <E T="03">Solid waste incineration unit</E> means a stationary, fossil-fuel-fired boiler or stationary, fossil-fuel-fired combustion turbine that is a “solid waste incineration unit” as defined in section 129(g)(1) of the Clean Air Act.</P>
            <P>
              <E T="03">Topping-cycle cogeneration unit</E> means a cogeneration unit in which the energy input to the unit is first used to produce useful power, including electricity, and at least some of the reject heat from the electricity production is then used to provide useful thermal energy.</P>
            <P>
              <E T="03">Total energy input</E> means, with regard to a cogeneration unit, total energy of all forms supplied to the cogeneration unit, excluding energy produced by the cogeneration unit itself.</P>
            <P>
              <E T="03">Total energy output</E> means, with regard to a cogeneration unit, the sum of useful power and useful thermal energy produced by the cogeneration unit.</P>
            <P>
              <E T="03">Unit</E> means a stationary, fossil-fuel-fired boiler or a stationary, fossil-fuel fired combustion turbine.</P>
            <P>
              <E T="03">Useful power</E> means, with regard to a cogeneration unit, electricity or mechanical energy made available for use, excluding any such energy used in the power production process (which process includes, but is not limited to, any on-site processing or treatment of fuel combusted at the unit and any on-site emission controls).</P>
            <P>
              <E T="03">Useful thermal energy</E> means, with regard to a cogeneration unit, thermal energy that is:</P>
            <P>(1) Made available to an industrial or commercial process, excluding any heat contained in condensate return or makeup water;</P>
            <P>(2) Used in a heat application (<E T="03">e.g.</E>, space heating or domestic hot water heating); or</P>
            <P>(3) Used in a space cooling application (<E T="03">i.e.</E>, thermal energy used by an absorption chiller).</P>
            <P>
              <E T="03">Utility power distribution system</E> means the portion of an electricity grid owned or operated by a utility and dedicated to delivering electricity to customers.</P>

            <P>(r) Notwithstanding any other provision of this section, a State may adopt, and include in a SIP revision submitted by March 31, 2007, regulations relating to the Federal CAIR SO<E T="52">2</E> Trading Program under subparts AAA through HHH of part 97 of this chapter as follows. The State may adopt the following CAIR opt-in unit provisions:</P>

            <P>(1) Provisions for CAIR opt-in units, including provisions for applications for CAIR opt-in permits, approval of CAIR opt-in permits, treatment of units as CAIR opt-in units, and allocation and recordation of CAIR SO<E T="52">2</E> allowances for CAIR opt-in units, that are substantively identical to subpart III of part 96 of this chapter and the provisions of subparts AAA through HHH that are applicable to CAIR opt-in units or units for which a CAIR opt-in permit application is submitted and not withdrawn and a CAIR opt-in permit is not yet issued or denied;</P>

            <P>(2) Provisions for CAIR opt-in units, including provisions for applications <PRTPAGE P="185"/>for CAIR opt-in permits, approval of CAIR opt-in permits, treatment of units as CAIR opt-in units, and allocation and recordation of CAIR SO<E T="52">2</E> allowances for CAIR opt-in units, that are substantively identical to subpart III of part 96 of this chapter and the provisions of subparts AAA through HHH that are applicable to CAIR opt-in units or units for which a CAIR opt-in permit application is submitted and not withdrawn and a CAIR opt-in permit is not yet issued or denied, except that the provisions exclude § 96.288(b) of this chapter and the provisions of subpart III of part 96 of this chapter that apply only to units covered by § 96.288(b) of this chapter; or</P>

            <P>(3) Provisions for applications for CAIR opt-in units, including provisions for CAIR opt-in permits, approval of CAIR opt-in permits, treatment of units as CAIR opt-in units, and allocation and recordation of CAIR SO<E T="52">2</E> allowances for CAIR opt-in units, that are substantively identical to subpart III of part 96 of this chapter and the provisions of subparts AAA through HHH that are applicable to CAIR opt-in units or units for which a CAIR opt-in permit application is submitted and not withdrawn and a CAIR opt-in permit is not yet issued or denied, except that the provisions exclude § 96.288(c) of this chapter and the provisions of subpart III of part 96 of this chapter that apply only to units covered by § 96.288(c) of this chapter.</P>
            <CITA>[70 FR 25328, May 12, 2005, as amended at 71 FR 25302, 25372, Apr. 28, 2006]</CITA>
          </SECTION>
          <SECTION>
            <SECTNO>§ 51.125</SECTNO>

            <SUBJECT>Emissions reporting requirements for SIP revisions relating to budgets for SO<E T="52">2</E> and NO<E T="52">X</E> emissions.</SUBJECT>

            <P>(a) For its transport SIP revision under § 51.123 and/or 51.124, each State must submit to EPA SO<E T="52">2</E> and/or NO<E T="52">X</E> emissions data as described in this section.</P>
            <P>(1) Alabama, Delaware, Florida, Georgia, Illinois, Indiana, Iowa, Kentucky, Louisiana, Maryland, Michigan, Minnesota, Mississippi, Missouri, New Jersey, New York, North Carolina, Ohio, Pennsylvania, South Carolina, Tennessee, Texas, Virginia, West Virginia, Wisconsin, and the District of Columbia.</P>

            <P>(2) Alabama, Arkansas, Connecticut, Deleware, Florida, Illinois, Indinia, Iowa, Kentucky, Lousianna, Maryland, Massachusetts, Michigan, Mississippi, Missouri, New Jersey, New York, North Carolina, Ohio, Pennsylvania, South Carolina, Tennessee, Virginia, West Virginia, Wisconsin and the District of Columbia must report ozone season (May 1 through September 30) emissions of NO<E T="52">X</E>.</P>

            <P>(b) Each revision must provide for periodic reporting by the State of SO<E T="52">2</E> and/or NO<E T="52">X</E> emissions data as specified in paragraph (a) of this section to demonstrate whether the State's emissions are consistent with the projections contained in its approved SIP submission.</P>

            <P>(1) Every-year reporting cycle. As applicable, each revision must provide for reporting of SO<E T="52">2</E> and NO<E T="52">X</E> emissions data every year as follows:</P>

            <P>(i) The States identified in paragraph (a)(1) of this section must report to EPA annual emissions data every year from all SO<E T="52">2</E> and NO<E T="52">X</E> sources within the State for which the State specified control measures in its SIP submission under §§ 51.123 and/or 51.124.</P>

            <P>(ii) The States identified in paragraph (a)(2) of this section must report to EPA ozone season and summer daily emissions data every year from all NO<E T="52">X</E> sources within the State for which the State specified control measures in its SIP submission under § 51.123.</P>
            <P>(iii) If sources report SO<E T="52">2</E> and NO<E T="52">X</E> emissions data to EPA in a given year pursuant to a trading program approved under § 51.123(o) or § 51.124(o) of this part or pursuant to the monitoring and reporting requirements of 40 CFR part 75, then the State need not provide annual reporting of these pollutants to EPA for such sources.</P>
            <P>(2) <E T="03">Three-year reporting cycle.</E> As applicable, each plan must provide for triennial (<E T="03">i.e.</E>, every third year) reporting of SO<E T="52">2</E> and NO<E T="52">X</E> emissions data from all sources within the State.</P>

            <P>(i) The States identified in paragraph (a)(1) of this section must report to EPA annual emissions data every third year from all SO<E T="52">2</E> and NO<E T="52">X</E> sources within the State.</P>

            <P>(ii) The States identified in paragraph (a)(2) of this section must report to EPA ozone season and ozone daily <PRTPAGE P="186"/>emissions data every third year from all NO<E T="52">X</E> sources within the State.</P>
            <P>(3) The data availability requirements in § 51.116 must be followed for all data submitted to meet the requirements of paragraphs (b)(1) and (2) of this section.</P>
            <P>(c) The data reported in paragraph (b) of this section must meet the requirements of subpart A of this part.</P>
            <P>(d) Approval of annual and ozone season calculation by EPA. Each State must submit for EPA approval an example of the calculation procedure used to calculate annual and ozone season emissions along with sufficient information for EPA to verify the calculated value of annual and ozone season emissions.</P>
            <P>(e) <E T="03">Reporting schedules.</E> (1) Reports are to begin with data for emissions occurring in the year 2008, which is the first year of the 3-year cycle.</P>
            <P>(2) After 2008, 3-year cycle reports are to be submitted every third year and every-year cycle reports are to be submitted each year that a triennial report is not required.</P>
            <P>(3) States must submit data for a required year no later than 17 months after the end of the calendar year for which the data are collected.</P>

            <P>(f) Data reporting procedures are given in subpart A of this part. When submitting a formal NO<E T="52">X</E> budget emissions report and associated data, States shall notify the appropriate EPA Regional Office.</P>
            <P>(g) <E T="03">Definitions.</E> (1) As used in this section, “ozone season” is defined as follows:</P>
            <P>
              <E T="03">Ozone season.</E>—The five month period from May 1 through September 30.</P>
            <P>(2) Other words and terms shall have the meanings set forth in appendix A of subpart A of this part.</P>
            <CITA>[70 FR 25333, May 12, 2005, as amended at 71 FR 25302, Apr. 28, 2006]</CITA>
          </SECTION>
        </SUBPART>
        <SUBPART>
          <HD SOURCE="HED">Subpart H—Prevention of Air Pollution Emergency Episodes</HD>
          <SOURCE>
            <HD SOURCE="HED">Source:</HD>
            <P>51 FR 40668, Nov. 7, 1986, unless otherwise noted.</P>
          </SOURCE>
          <SECTION>
            <SECTNO>§ 51.150</SECTNO>
            <SUBJECT>Classification of regions for episode plans.</SUBJECT>
            <P>(a) This section continues the classification system for episode plans. Each region is classified separately with respect to each of the following pollutants: Sulfur oxides, particulate matter, carbon monoxide, nitrogen dioxide, and ozone.</P>
            <P>(b) <E T="03">Priority I Regions</E> means any area with greater ambient concentrations than the following:</P>
            <P>(1) Sulfur dioxide—100 µg/m<SU>3</SU> (0.04 ppm) annual arithmetic mean; 455 µg/m<SU>3</SU> (0.17 ppm) 24-hour maximum.</P>
            <P>(2) Particulate matter—95 µg/m<SU>3</SU> annual geometric mean; 325 µg/m<SU>3</SU> 24-hour maximum.</P>
            <P>(3) Carbon monoxide—55 mg/m<SU>3</SU> (48 ppm) 1-hour maximum; 14 mg/m<SU>3</SU> (12 ppm) 8-hour maximum.</P>
            <P>(4) Nitrogen dioxide—100 µg/m<SU>3</SU> (0.06 ppm) annual arithmetic mean.</P>
            <P>(5) Ozone—195 µg/m<SU>3</SU> (0.10 ppm) 1-hour maximum.</P>
            <P>(c) <E T="03">Priority IA Region</E> means any area which is Priority I primarily because of emissions from a single point source.</P>
            <P>(d) <E T="03">Priority II Region</E> means any area which is not a Priority I region and has ambient concentrations between the following:</P>
            <P>(1) Sulfur Dioxides—60-100 µg/m<SU>3</SU> (0.02-0.04 ppm) annual arithmetic mean; 260-445 µg/m<SU>3</SU> (0.10-0.17 ppm) 24-hour maximum; any concentration above 1,300 µg/m<SU>3</SU> (0.50 ppm) three-hour average.</P>
            <P>(2) Particulate matter—60-95 µg/m<SU>3</SU> annual geometric mean; 150-325 µg/m<SU>3</SU> 24-hour maximum.</P>
            <P>(e) In the absence of adequate monitoring data, appropriate models must be used to classify an area under paragraph (b) of this section, consistent with the requirements contained in § 51.112(a).</P>
            <P>(f) Areas which do not meet the above criteria are classified Priority III.</P>
            <CITA>[51 FR 40668, Nov. 7, 1986, as amended at 58 FR 38822, July 20, 1993]</CITA>
          </SECTION>
          <SECTION>
            <SECTNO>§ 51.151</SECTNO>
            <SUBJECT>Significant harm levels.</SUBJECT>

            <P>Each plan for a Priority I region must include a contingency plan which must, as a mimimum, provide for taking action necessary to prevent ambient pollutant concentrations at any location in such region from reaching the following levels:
            </P>
            <EXTRACT>
              <FP SOURCE="FP-1">
                <E T="03">Sulfur dioxide</E>—2.620 µg/m<SU>3</SU> (1.0 ppm) 24-hour average.<PRTPAGE P="187"/>
              </FP>
              <FP SOURCE="FP-1">PM<E T="52">10</E>—600 micrograms/cubic meter; 24-hour average.</FP>
              <FP SOURCE="FP-1">
                <E T="03">Carbon monoxide</E>—57.5 mg/m<SU>3</SU> (50 ppm) 8-hour average; 86.3 mg/m<SU>3</SU> (75 ppm) 4-hour average; 144 mg/m<SU>3</SU> (125 ppm) 1-hour average.</FP>
              <FP SOURCE="FP-1">
                <E T="03">Ozone</E>—1,200 ug/m<SU>3</SU> (0.6 ppm) 2-hour average.</FP>
              <FP SOURCE="FP-1">
                <E T="03">Nitrogen dioxide</E>—3.750 ug/m<SU>3</SU> (2.0 ppm) 1-hour average; 938 ug/m<SU>3</SU> (0.5 ppm) 24-hour average.</FP>
            </EXTRACT>
            <CITA>[51 FR 40668, Nov. 7, 1986, as amended at 52 FR 24713, July 1, 1987]</CITA>
          </SECTION>
          <SECTION>
            <SECTNO>§ 51.152</SECTNO>
            <SUBJECT>Contingency plans.</SUBJECT>
            <P>(a) Each contingency plan must—</P>
            <P>(1) Specify two or more stages of episode criteria such as those set forth in appendix L to this part, or their equivalent;</P>
            <P>(2) Provide for public announcement whenever any episode stage has been determined to exist; and</P>
            <P>(3) Specify adequate emission control actions to be taken at each episode stage. (Examples of emission control actions are set forth in appendix L.)</P>
            <P>(b) Each contingency plan for a Priority I region must provide for the following:</P>
            <P>(1) Prompt acquisition of forecasts of atmospheric stagnation conditions and of updates of such forecasts as frequently as they are issued by the National Weather Service.</P>
            <P>(2) Inspection of sources to ascertain compliance with applicable emission control action requirements.</P>
            <P>(3) Communications procedures for transmitting status reports and orders as to emission control actions to be taken during an episode stage, including procedures for contact with public officials, major emission sources, public health, safety, and emergency agencies and news media.</P>
            <P>(c) Each plan for a Priority IA and II region must include a contingency plan that meets, as a minimum, the requirements of paragraphs (b)(1) and (b)(2) of this section. Areas classified Priority III do not need to develop episode plans.</P>
            <P>(d) Notwithstanding the requirements of paragraphs (b) and (c) of this section, the Administrator may, at his discretion—</P>
            <P>(1) Exempt from the requirements of this section those portions of Priority I, IA, or II regions which have been designated as attainment or unclassifiable for national primary and secondary standards under section 107 of the Act; or</P>
            <P>(2) Limit the requirements pertaining to emission control actions in Priority I regions to—</P>
            <P>(i) Urbanized areas as identified in the most recent United States Census, and</P>
            <P>(ii) Major emitting facilities, as defined by section 169(1) of the Act, outside the urbanized areas.</P>
          </SECTION>
          <SECTION>
            <SECTNO>§ 51.153</SECTNO>
            <SUBJECT>Reevaluation of episode plans.</SUBJECT>
            <P>(a) States should periodically reevaluate priority classifications of all Regions or portion of Regions within their borders. The reevaluation must consider the three most recent years of air quality data. If the evaluation indicates a change to a higher priority classification, appropriate changes in the episode plan must be made as expeditiously as practicable.</P>
            <P>(b) [Reserved]</P>
          </SECTION>
        </SUBPART>
        <SUBPART>
          <HD SOURCE="HED">Subpart I—Review of New Sources and Modifications</HD>
          <SOURCE>
            <HD SOURCE="HED">Source:</HD>
            <P>51 FR 40669, Nov. 7, 1986, unless otherwise noted.</P>
          </SOURCE>
          <SECTION>
            <SECTNO>§ 51.160</SECTNO>
            <SUBJECT>Legally enforceable procedures.</SUBJECT>
            <P>(a) Each plan must set forth legally enforceable procedures that enable the State or local agency to determine whether the construction or modification of a facility, building, structure or installation, or combination of these will result in—</P>
            <P>(1) A violation of applicable portions of the control strategy; or</P>
            <P>(2) Interference with attainment or maintenance of a national standard in the State in which the proposed source (or modification) is located or in a neighboring State.</P>
            <P>(b) Such procedures must include means by which the State or local agency responsible for final decisionmaking on an application for approval to construct or modify will prevent such construction or modification if—</P>
            <P>(1) It will result in a violation of applicable portions of the control strategy; or</P>

            <P>(2) It will interfere with the attainment or maintenance of a national standard.<PRTPAGE P="188"/>
            </P>
            <P>(c) The procedures must provide for the submission, by the owner or operator of the building, facility, structure, or installation to be constructed or modified, of such information on—</P>
            <P>(1) The nature and amounts of emissions to be emitted by it or emitted by associated mobile sources;</P>
            <P>(2) The location, design, construction, and operation of such facility, building, structure, or installation as may be necessary to permit the State or local agency to make the determination referred to in paragraph (a) of this section.</P>
            <P>(d) The procedures must provide that approval of any construction or modification must not affect the responsibility to the owner or operator to comply with applicable portions of the control strategy.</P>
            <P>(e) The procedures must identify types and sizes of facilities, buildings, structures, or installations which will be subject to review under this section. The plan must discuss the basis for determining which facilities will be subject to review.</P>
            <P>(f) The procedures must discuss the air quality data and the dispersion or other air quality modeling used to meet the requirements of this subpart.</P>
            <P>(1) All applications of air quality modeling involved in this subpart shall be based on the applicable models, data bases, and other requirements specified in appendix W of this part (Guideline on Air Quality Models).</P>
            <P>(2) Where an air quality model specified in appendix W of this part (Guideline on Air Quality Models) is inappropriate, the model may be modified or another model substituted. Such a modification or substitution of a model may be made on a case-by-case basis or, where appropriate, on a generic basis for a specific State program. Written approval of the Administrator must be obtained for any modification or substitution. In addition, use of a modified or substituted model must be subject to notice and opportunity for public comment under procedures set forth in § 51.102.</P>
            <CITA>[51 FR 40669, Nov. 7, 1986, as amended at 58 FR 38822, July 20, 1993; 60 FR 40468, Aug. 9, 1995; 61 FR 41840, Aug. 12, 1996]</CITA>
          </SECTION>
          <SECTION>
            <SECTNO>§ 51.161</SECTNO>
            <SUBJECT>Public availability of information.</SUBJECT>
            <P>(a) The legally enforceable procedures in § 51.160 must also require the State or local agency to provide opportunity for public comment on information submitted by owners and operators. The public information must include the agency's analysis of the effect of construction or modification on ambient air quality, including the agency's proposed approval or disapproval.</P>
            <P>(b) For purposes of paragraph (a) of this section, opportunity for public comment shall include, as a minimum—</P>
            <P>(1) Availability for public inspection in at least one location in the area affected of the information submitted by the owner or operator and of the State or local agency's analysis of the effect on air quality;</P>
            <P>(2) A 30-day period for submittal of public comment; and</P>
            <P>(3) A notice by prominent advertisement in the area affected of the location of the source information and analysis specified in paragraph (b)(1) of this section.</P>
            <P>(c) Where the 30-day comment period required in paragraph (b) of this section would conflict with existing requirements for acting on requests for permission to construct or modify, the State may submit for approval a comment period which is consistent with such existing requirements.</P>
            <P>(d) A copy of the notice required by paragraph (b) of this section must also be sent to the Administrator through the appropriate Regional Office, and to all other State and local air pollution control agencies having jurisdiction in the region in which such new or modified installation will be located. The notice also must be sent to any other agency in the region having responsibility for implementing the procedures required under this subpart. For lead, a copy of the notice is required for all point sources. The definition of point for lead is given in § 51.100(k)(2).</P>
          </SECTION>
          <SECTION>
            <SECTNO>§ 51.162</SECTNO>
            <SUBJECT>Identification of responsible agency.</SUBJECT>

            <P>Each plan must identify the State or local agency which will be responsible for meeting the requirements of this <PRTPAGE P="189"/>subpart in each area of the State. Where such responsibility rests with an agency other than an air pollution control agency, such agency will consult with the appropriate State or local air pollution control agency in carrying out the provisions of this subpart.</P>
          </SECTION>
          <SECTION>
            <SECTNO>§ 51.163</SECTNO>
            <SUBJECT>Administrative procedures.</SUBJECT>
            <P>The plan must include the administrative procedures, which will be followed in making the determination specified in paragraph (a) of § 51.160.</P>
          </SECTION>
          <SECTION>
            <SECTNO>§ 51.164</SECTNO>
            <SUBJECT>Stack height procedures.</SUBJECT>
            <P>Such procedures must provide that the degree of emission limitation required of any source for control of any air pollutant must not be affected by so much of any source's stack height that exceeds good engineering practice or by any other dispersion technique, except as provided in § 51.118(b). Such procedures must provide that before a State issues a permit to a source based on a good engineering practice stack height that exceeds the height allowed by § 51.100(ii) (1) or (2), the State must notify the public of the availability of the demonstration study and must provide opportunity for public hearing on it. This section does not require such procedures to restrict in any manner the actual stack height of any source.</P>
          </SECTION>
          <SECTION>
            <SECTNO>§ 51.165</SECTNO>
            <SUBJECT>Permit requirements.</SUBJECT>
            <P>(a) State Implementation Plan and Tribal Implementation Plan provisions satisfying sections 172(c)(5) and 173 of the Act shall meet the following conditions:</P>
            <P>(1) All such plans shall use the specific definitions. Deviations from the following wording will be approved only if the State specifically demonstrates that the submitted definition is more stringent, or at least as stringent, in all respects as the corresponding definition below:</P>
            <P>(i) <E T="03">Stationary source</E> means any building, structure, facility, or installation which emits or may emit a regulated NSR pollutant.</P>
            <P>(ii) <E T="03">Building, structure, facility, or installation</E> means all of the pollutant-emitting activities which belong to the same industrial grouping, are located on one or more contiguous or adjacent properties, and are under the control of the same person (or persons under common control) except the activities of any vessel. Pollutant-emitting activities shall be considered as part of the same industrial grouping if they belong to the same <E T="03">Major Group</E> (i.e., which have the same two-digit code) as described in the <E T="03">Standard Industrial Classification Manual, 1972,</E> as amended by the 1977 Supplement (U.S. Government Printing Office stock numbers 4101-0065 and 003-005-00176-0, respectively).</P>
            <P>(iii) <E T="03">Potential to emit</E> means the maximum capacity of a stationary source to emit a pollutant under its physical and operational design. Any physical or operational limitation on the capacity of the source to emit a pollutant, including air pollution control equipment and restrictions on hours of operation or on the type or amount of material combusted, stored, or processed, shall be treated as part of its design only if the limitation or the effect it would have on emissions is federally enforceable. Secondary emissions do not count in determining the potential to emit of a stationary source.</P>
            <P>(iv)(A) <E T="03">Major stationary source</E> means:</P>
            <P>(<E T="03">1</E>) Any stationary source of air pollutants that emits, or has the potential to emit, 100 tons per year or more of any regulated NSR pollutant, except that lower emissions thresholds shall apply in areas subject to subpart 2, subpart 3, or subpart 4 of part D, title I of the Act, according to paragraphs (a)(1)(iv)(A)(<E T="03">1</E>)(<E T="03">i</E>) through (<E T="03">vi</E>) of this section.</P>
            <P>(<E T="03">i</E>) 50 tons per year of volatile organic compounds in any serious ozone nonattainment area.</P>
            <P>(<E T="03">ii</E>) 50 tons per year of volatile organic compounds in an area within an ozone transport region, except for any severe or extreme ozone nonattainment area.</P>
            <P>(<E T="03">iii</E>) 25 tons per year of volatile organic compounds in any severe ozone nonattainment area.</P>
            <P>(<E T="03">iv</E>) 10 tons per year of volatile organic compounds in any extreme ozone nonattainment area.</P>
            <P>(<E T="03">v</E>) 50 tons per year of carbon monoxide in any serious nonattainment area for carbon monoxide, where stationary sources contribute significantly to carbon monoxide levels in the <PRTPAGE P="190"/>area (as determined under rules issued by the Administrator).</P>
            <P>(<E T="03">vi</E>) 70 tons per year of PM-10 in any serious nonattainment area for PM-10;</P>
            <P>(<E T="03">2</E>) For the purposes of applying the requirements of paragraph (a)(8) of this section to stationary sources of nitrogen oxides located in an ozone nonattainment area or in an ozone transport region, any stationary source which emits, or has the potential to emit, 100 tons per year or more of nitrogen oxides emissions, except that the emission thresholds in paragraphs (a)(1)(iv)(A)(<E T="03">2</E>)(<E T="03">i</E>) through (<E T="03">vi</E>) of this section shall apply in areas subject to subpart 2 of part D, title I of the Act.</P>
            <P>(<E T="03">i</E>) 100 tons per year or more of nitrogen oxides in any ozone nonattainment area classified as marginal or moderate.</P>
            <P>(<E T="03">ii</E>) 100 tons per year or more of nitrogen oxides in any ozone nonattainment area classified as a transitional, submarginal, or incomplete or no data area, when such area is located in an ozone transport region.</P>
            <P>(<E T="03">iii</E>) 100 tons per year or more of nitrogen oxides in any area designated under section 107(d) of the Act as attainment or unclassifiable for ozone that is located in an ozone transport region.</P>
            <P>(<E T="03">iv</E>) 50 tons per year or more of nitrogen oxides in any serious nonattainment area for ozone.</P>
            <P>(<E T="03">v</E>) 25 tons per year or more of nitrogen oxides in any severe nonattainment area for ozone.</P>
            <P>(<E T="03">vi</E>) 10 tons per year or more of nitrogen oxides in any extreme nonattainment area for ozone; or</P>
            <P>(<E T="03">3</E>) Any physical change that would occur at a stationary source not qualifying under paragraphs (a)(1)(iv)(A)(<E T="03">1</E>) or (<E T="03">2</E>) of this section as a major stationary source, if the change would constitute a major stationary source by itself.</P>
            <P>(B) A major stationary source that is major for volatile organic compounds shall be considered major for ozone</P>
            <P>(C) The fugitive emissions of a stationary source shall not be included in determining for any of the purposes of this paragraph whether it is a major stationary source, unless the source belongs to one of the following categories of stationary sources:</P>
            <P>(<E T="03">1</E>) Coal cleaning plants (with thermal dryers);</P>
            <P>(<E T="03">2</E>) Kraft pulp mills;</P>
            <P>(<E T="03">3</E>) Portland cement plants;</P>
            <P>(<E T="03">4</E>) Primary zinc smelters;</P>
            <P>(<E T="03">5</E>) Iron and steel mills;</P>
            <P>(<E T="03">6</E>) Primary aluminum ore reduction plants;</P>
            <P>(<E T="03">7</E>) Primary copper smelters;</P>
            <P>(<E T="03">8</E>) Municipal incinerators capable of charging more than 250 tons of refuse per day;</P>
            <P>(<E T="03">9</E>) Hydrofluoric, sulfuric, or nitric acid plants;</P>
            <P>(<E T="03">10</E>) Petroleum refineries;</P>
            <P>(<E T="03">11</E>) Lime plants;</P>
            <P>(<E T="03">12</E>) Phosphate rock processing plants;</P>
            <P>(<E T="03">13</E>) Coke oven batteries;</P>
            <P>(<E T="03">14</E>) Sulfur recovery plants;</P>
            <P>(<E T="03">15</E>) Carbon black plants (furnace process);</P>
            <P>(<E T="03">16</E>) Primary lead smelters;</P>
            <P>(<E T="03">17</E>) Fuel conversion plants;</P>
            <P>(<E T="03">18</E>) Sintering plants;</P>
            <P>(<E T="03">19</E>) Secondary metal production plants;</P>
            <P>(<E T="03">20</E>) Chemical process plants;</P>
            <P>(<E T="03">21</E>) Fossil-fuel boilers (or combination thereof) totaling more than 250 million British thermal units per hour heat input;</P>
            <P>(<E T="03">22</E>) Petroleum storage and transfer units with a total storage capacity exceeding 300,000 barrels;</P>
            <P>(<E T="03">23</E>) Taconite ore processing plants;</P>
            <P>(<E T="03">24</E>) Glass fiber processing plants;</P>
            <P>(<E T="03">25</E>) Charcoal production plants;</P>
            <P>(<E T="03">26</E>) Fossil fuel-fired steam electric plants of more than 250 million British thermal units per hour heat input; and</P>
            <P>(<E T="03">27</E>) Any other stationary source category which, as of August 7, 1980, is being regulated under section 111 or 112 of the Act.</P>
            <P>(v)(A) <E T="03">Major modification</E> means any physical change in or change in the method of operation of a major stationary source that would result in:</P>
            <P>(<E T="03">1</E>) A significant emissions increase of a regulated NSR pollutant (as defined in paragraph (a)(1)(xxxvii) of this section); and</P>
            <P>(<E T="03">2</E>) A significant net emissions increase of that pollutant from the major stationary source.</P>

            <P>(B) Any significant emissions increase (as defined in paragraph (a)(1)(xxvii) of this section) from any <PRTPAGE P="191"/>emissions units or net emissions increase (as defined in paragraph (a)(1)(vi) of this section) at a major stationary source that is significant for volatile organic compounds shall be considered significant for ozone.</P>
            <P>(C) A physical change or change in the method of operation shall not include:</P>
            <P>(<E T="03">1</E>) Routine maintenance, repair and replacement. Routine maintenance, repair and replacement shall include, but not be limited to, any activity(s) that meets the requirements of the equipment replacement provisions contained in paragraph (h) of this section;</P>
            <NOTE>
              <HD SOURCE="HED">Note to paragraph (a)(1)(v)(C)(<E T="03">1</E>):</HD>

              <P>On December 24, 2003, the second sentence of this paragraph (a)(1)(v)(C)(<E T="03">1</E>) is stayed indefinitely by court order. The stayed provisions will become effective immediately if the court terminates the stay. At that time, EPA will publish a document in the <E T="04">Federal Register</E> advising the public of the termination of the stay.</P>
            </NOTE>
            <P>(<E T="03">2</E>) Use of an alternative fuel or raw material by reason of an order under sections 2 (a) and (b) of the Energy Supply and Environmental Coordination Act of 1974 (or any superseding legislation) or by reason of a natural gas curtailment plan pursuant to the Federal Power Act;</P>
            <P>(<E T="03">3</E>) Use of an alternative fuel by reason of an order or rule section 125 of the Act;</P>
            <P>(<E T="03">4</E>) Use of an alternative fuel at a steam generating unit to the extent that the fuel is generated from municipal solid waste;</P>
            <P>(<E T="03">5</E>) Use of an alternative fuel or raw material by a stationary source which;</P>
            <P>(<E T="03">i</E>) The source was capable of accommodating before December 21, 1976, unless such change would be prohibited under any federally enforceable permit condition which was established after December 12, 1976 pursuant to 40 CFR 52.21 or under regulations approved pursuant to 40 CFR subpart I or § 51.166, or</P>
            <P>(<E T="03">ii</E>) The source is approved to use under any permit issued under regulations approved pursuant to this section;</P>
            <P>(<E T="03">6</E>) An increase in the hours of operation or in the production rate, unless such change is prohibited under any federally enforceable permit condition which was established after December 21, 1976 pursuant to 40 CFR 52.21 or regulations approved pursuant to 40 CFR part 51 subpart I or 40 CFR 51.166.</P>
            <P>(<E T="03">7</E>) Any change in ownership at a stationary source.</P>
            <P>(<E T="03">8</E>) The addition, replacement, or use of a PCP, as defined in paragraph (a)(1)(xxv) of this section, at an existing emissions unit meeting the requirements of paragraph (e) of this section. A replacement control technology must provide more effective emissions control than that of the replaced control technology to qualify for this exclusion.</P>
            <P>(<E T="03">9</E>) The installation, operation, cessation, or removal of a temporary clean coal technology demonstration project, provided that the project complies with:</P>
            <P>(<E T="03">i</E>) The State Implementation Plan for the State in which the project is located, and</P>
            <P>(<E T="03">ii</E>) Other requirements necessary to attain and maintain the national ambient air quality standard during the project and after it is terminated.</P>
            <P>(D) This definition shall not apply with respect to a particular regulated NSR pollutant when the major stationary source is complying with the requirements under paragraph (f) of this section for a PAL for that pollutant. Instead, the definition at paragraph (f)(2)(viii) of this section shall apply.</P>
            <P>(E) For the purpose of applying the requirements of (a)(8) of this section to modifications at major stationary sources of nitrogen oxides located in ozone nonattainment areas or in ozone transport regions, whether or not subject to subpart 2, part D, title I of the Act, any significant net emissions increase of nitrogen oxides is considered significant for ozone.</P>

            <P>(F) Any physical change in, or change in the method of operation of, a major stationary source of volatile organic compounds that results in any increase in emissions of volatile organic compounds from any discrete operation, emissions unit, or other pollutant emitting activity at the source shall be considered a significant net emissions increase and a major modification for ozone, if the major stationary source is located in an extreme <PRTPAGE P="192"/>ozone nonattainment area that is subject to subpart 2, part D, title I of the Act.</P>
            <P>(vi)(A) <E T="03">Net emissions increase</E> means, with respect to any regulated NSR pollutant emitted by a major stationary source, the amount by which the sum of the following exceeds zero:</P>
            <P>(<E T="03">1</E>) The increase in emissions from a particular physical change or change in the method of operation at a stationary source as calculated pursuant to paragraph (a)(2)(ii) of this section; and</P>
            <P>(<E T="03">2</E>) Any other increases and decreases in actual emissions at the major stationary source that are contemporaneous with the particular change and are otherwise creditable. Baseline actual emissions for calculating increases and decreases under this paragraph (a)(1)(vi)(A)(<E T="03">2</E>) shall be determined as provided in paragraph (a)(1)(xxxv) of this section, except that paragraphs (a)(1)(xxxv)(A)(<E T="03">3</E>) and (a)(1)(xxxv)(B)(<E T="03">4</E>) of this section shall not apply.</P>
            <P>(B) An increase or decrease in actual emissions is contemporaneous with the increase from the particular change only if it occurs before the date that the increase from the particular change occurs;</P>
            <P>(C) An increase or decrease in actual emissions is creditable only if:</P>
            <P>(<E T="03">1</E>) It occurs within a reasonable period to be specified by the reviewing authority; and</P>
            <P>(<E T="03">2</E>) The reviewing authority has not relied on it in issuing a permit for the source under regulations approved pursuant to this section, which permit is in effect when the increase in actual emissions from the particular change occurs; and</P>
            <P>(<E T="03">3</E>) The increase or decrease in emissions did not occur at a Clean Unit, except as provided in paragraphs (c)(8) and (d)(10) of this section.</P>
            <P>(D) An increase in actual emissions is creditable only to the extent that the new level of actual emissions exceeds the old level.</P>
            <P>(E) A decrease in actual emissions is creditable only to the extent that:</P>
            <P>(<E T="03">1</E>) The old level of actual emission or the old level of allowable emissions whichever is lower, exceeds the new level of actual emissions;</P>
            <P>(<E T="03">2</E>) It is enforceable as a practical matter at and after the time that actual construction on the particular change begins; and</P>
            <P>(<E T="03">3</E>) The reviewing authority has not relied on it in issuing any permit under regulations approved pursuant to 40 CFR part 51 subpart I or the State has not relied on it in demonstrating attainment or reasonable further progress;</P>
            <P>(<E T="03">4</E>) It has approximately the same qualitative significance for public health and welfare as that attributed to the increase from the particular change; and</P>
            <P>(<E T="03">5</E>) The decrease in actual emissions did not result from the installation of add-on control technology or application of pollution prevention practices that were relied on in designating an emissions unit as a Clean Unit under 40 CFR 52.21(y) or under regulations approved pursuant to paragraph (d) of this section or § 51.166(u). That is, once an emissions unit has been designated as a Clean Unit, the owner or operator cannot later use the emissions reduction from the air pollution control measures that the Clean Unit designation is based on in calculating the net emissions increase for another emissions unit (<E T="03">i.e.,</E> must not use that reduction in a “netting analysis” for another emissions unit). However, any new emissions reductions that were not relied upon in a PCP excluded pursuant to paragraph (e) of this section or for a Clean Unit designation are creditable to the extent they meet the requirements in paragraphs (e)(6)(iv) of this section for the PCP and paragraphs (c)(8) or (d)(10) of this section for a Clean Unit.</P>
            <P>(F) An increase that results from a physical change at a source occurs when the emissions unit on which construction occurred becomes operational and begins to emit a particular pollutant. Any replacement unit that requires shakedown becomes operational only after a reasonable shakedown period, not to exceed 180 days.</P>
            <P>(G) Paragraph (a)(1)(xii)(B) of this section shall not apply for determining creditable increases and decreases or after a change.</P>
            <P>(vii) <E T="03">Emissions unit</E> means any part of a stationary source that emits or <PRTPAGE P="193"/>would have the potential to emit any regulated NSR pollutant and includes an electric steam generating unit as defined in paragraph (a)(1)(xx) of this section. For purposes of this section, there are two types of emissions units as described in paragraphs (a)(1)(vii)(A) and (B) of this section.</P>
            <P>(A) A new emissions unit is any emissions unit which is (or will be) newly constructed and which has existed for less than 2 years from the date such emissions unit first operated.</P>
            <P>(B) An existing emissions unit is any emissions unit that does not meet the requirements in paragraph (a)(1)(vii)(A) of this section. A replacement unit, as defined in paragraph (a)(1)(xxi) of this section, is an existing emissions unit.</P>
            <P>(viii) <E T="03">Secondary emissons</E> means emissions which would occur as a result of the construction or operation of a major stationary source or major modification, but do not come from the major stationary source or major modification itself. For the purpose of this section, secondary emissions must be specific, well defined, quantifiable, and impact the same general area as the stationary source or modification which causes the secondary emissions. Secondary emissions include emissions from any offsite support facility which would not be constructed or increase its emissions except as a result of the construction of operation of the major stationary source of major modification. Secondary emissions do not include any emissions which come directly from a mobile source such as emissions from the tailpipe of a motor vehicle, from a train, or from a vessel.</P>
            <P>(ix) <E T="03">Fugitive emissions</E> means those emissions which could not reasonably pass through a stack, chimney, vent or other functionally equivalent opening.</P>
            <P>(x)(A) <E T="03">Significant</E> means, in reference to a net emissions increase or the potential of a source to emit any of the following pollutants, a rate of emissions that would equal or exceed any of the following rates:</P>
            <EXTRACT>
              <HD SOURCE="HD1">Pollutant Emission Rate</HD>
              <FP SOURCE="FP-1">Carbon monoxide: 100 tons per year (tpy)</FP>
              <FP SOURCE="FP-1">Nitrogen oxides: 40 tpy</FP>
              <FP SOURCE="FP-1">Sulfur dioxide: 40 tpy</FP>
              <FP SOURCE="FP-1">Ozone: 40 tpy of volatile organic compounds or NO<E T="52">X</E>
              </FP>
              <FP SOURCE="FP-1">Lead: 0.6 tpy</FP>
              <FP SOURCE="FP-1">PM-10: 15 tpy PM-10</FP>
            </EXTRACT>
            
            <P>(B) Notwithstanding the significant emissions rate for ozone in paragraph (a)(1)(x)(A) of this section, significant means, in reference to an emissions increase or a net emissions increase, any increase in actual emissions of volatile organic compounds that would result from any physical change in, or change in the method of operation of, a major stationary source locating in a serious or severe ozone nonattainment area that is subject to subpart 2, part D, title I of the Act, if such emissions increase of volatile organic compounds exceeds 25 tons per year.</P>
            <P>(C) For the purposes of applying the requirements of paragraph (a)(8) of this section to modifications at major stationary sources of nitrogen oxides located in an ozone nonattainment area or in an ozone transport region, the significant emission rates and other requirements for volatile organic compounds in paragraphs (a)(1)(x)(A), (B), and (E) of this section shall apply to nitrogen oxides emissions.</P>
            <P>(D) Notwithstanding the significant emissions rate for carbon monoxide under paragraph (a)(1)(x)(A) of this section, significant means, in reference to an emissions increase or a net emissions increase, any increase in actual emissions of carbon monoxide that would result from any physical change in, or change in the method of operation of, a major stationary source in a serious nonattainment area for carbon monoxide if such increase equals or exceeds 50 tons per year, provided the Administrator has determined that stationary sources contribute significantly to carbon monoxide levels in that area.</P>

            <P>(E) Notwithstanding the significant emissions rates for ozone under paragraphs (a)(1)(x)(A) and (B) of this section, any increase in actual emissions of volatile organic compounds from any emissions unit at a major stationary source of volatile organic compounds located in an extreme ozone nonattainment area that is subject to subpart 2, part D, title I of the Act shall be considered a significant net emissions increase.
            </P>
            <P>(xi) <E T="03">Allowable emissions</E> means the emissions rate of a stationary source <PRTPAGE P="194"/>calculated using the maximum rated capacity of the source (unless the source is subject to federally enforceable limits which restrict the operating rate, or hours of operation, or both) and the most stringent of the following:</P>
            <P>(A) The applicable standards set forth in 40 CFR part 60 or 61;</P>
            <P>(B) Any applicable State Implementation Plan emissions limitation including those with a future compliance date; or</P>
            <P>(C) The emissions rate specified as a federally enforceable permit condition, including those with a future compliance date.</P>
            <P>(xii)(A) <E T="03">Actual emissions</E> means the actual rate of emissions of a regulated NSR pollutant from an emissions unit, as determined in accordance with paragraphs (a)(1)(xii)(B) through (D) of this section, except that this definition shall not apply for calculating whether a significant emissions increase has occurred, or for establishing a PAL under paragraph (f) of this section. Instead, paragraphs (a)(1)(xxviii) and (xxxv) of this section shall apply for those purposes.</P>
            <P>(B) In general, actual emissions as of a particular date shall equal the average rate, in tons per year, at which the unit actually emitted the pollutant during a consecutive 24-month period which precedes the particular date and which is representative of normal source operation. The reviewing authority shall allow the use of a different time period upon a determination that it is more representative of normal source operation. Actual emissions shall be calculated using the unit's actual operating hours, production rates, and types of materials processed, stored, or combusted during the selected time period.</P>
            <P>(C) The reviewing authority may presume that source-specific allowable emissions for the unit are equivalent to the actual emissions of the unit.</P>
            <P>(D) For any emissions unit that has not begun normal operations on the particular date, actual emissions shall equal the potential to emit of the unit on that date.</P>
            <P>(xiii) <E T="03">Lowest achievable emission rate (LAER)</E> means, for any source, the more stringent rate of emissions based on the following:</P>
            <P>(A) The most stringent emissions limitation which is contained in the implementation plan of any State for such class or category of stationary source, unless the owner or operator of the proposed stationary source demonstrates that such limitations are not achievable; or</P>
            <P>(B) The most stringent emissions limitation which is achieved in practice by such class or category of stationary sources. This limitation, when applied to a modification, means the lowest achievable emissions rate for the new or modified emissions units within or stationary source. In no event shall the application of the term permit a proposed new or modified stationary source to emit any pollutant in excess of the amount allowable under an applicable new source standard of performance.</P>
            <P>(xiv) <E T="03">Federally enforceable</E> means all limitations and conditions which are enforceable by the Administrator, including those requirements developed pursuant to 40 CFR parts 60 and 61, requirements within any applicable State implementation plan, any permit requirements established pursuant to 40 CFR 52.21 or under regulations approved pursuant to 40 CFR part 51, subpart I, including operating permits issued under an EPA-approved program that is incorporated into the State implementation plan and expressly requires adherence to any permit issued under such program.</P>
            <P>(xv) <E T="03">Begin actual construction</E> means in general, initiation of physical on-site construction activities on an emissions unit which are of a permanent nature. Such activities include, but are not limited to, installation of building supports and foundations, laying of underground pipework, and construction of permanent storage structures. With respect to a change in method of operating this term refers to those on-site activities other than preparatory activities which mark the initiation of the change.</P>
            <P>(xvi) <E T="03">Commence</E> as applied to construction of a major stationary source or major modification means that the owner or operator has all necessary <PRTPAGE P="195"/>preconstruction approvals or permits and either has:</P>
            <P>(A) Begun, or caused to begin, a continuous program of actual on-site construction of the source, to be completed within a reasonable time; or</P>
            <P>(B) Entered into binding agreements or contractual obligations, which cannot be canceled or modified without substantial loss to the owner or operator, to undertake a program of actual construction of the source to be completed within a reasonable time.</P>
            <P>(xvii) <E T="03">Necessary preconstruction approvals or permits</E> means those Federal air quality control laws and regulations and those air quality control laws and regulations which are part of the applicable State Implementation Plan.</P>
            <P>(xviii) <E T="03">Construction</E> means any physical change or change in the method of operation (including fabrication, erection, installation, demolition, or modification of an emissions unit) that would result in a change in emissions.</P>
            <P>(xix)<E T="03">Volatile organic compounds (VOC)</E> is as defined in § 51.100(s) of this part.</P>
            <P>(xx) <E T="03">Electric utility steam generating unit</E> means any steam electric generating unit that is constructed for the purpose of supplying more than one-third of its potential electric output capacity and more than 25 MW electrical output to any utility power distribution system for sale. Any steam supplied to a steam distribution system for the purpose of providing steam to a steam-electric generator that would produce electrical energy for sale is also considered in determining the electrical energy output capacity of the affected facility.</P>
            <P>(xxi) <E T="03">Replacement unit</E> means an emissions unit for which all the criteria listed in paragraphs (a)(1)(xxi)(A) through (D) of this section are met. No creditable emission reductions shall be generated from shutting down the existing emissions unit that is replaced.</P>
            <P>(A) The emissions unit is a reconstructed unit within the meaning of § 60.15(b)(1) of this chapter, or the emissions unit completely takes the place of an existing emissions unit.</P>
            <P>(B) The emissions unit is identical to or functionally equivalent to the replaced emissions unit.</P>
            <P>(C) The replacement does not alter the basic design parameters (as discussed in paragraph (h)(2) of this section) of the process unit.</P>
            <P>(D) The replaced emissions unit is permanently removed from the major stationary source, otherwise permanently disabled, or permanently barred from operation by a permit that is enforceable as a practical matter. If the replaced emissions unit is brought back into operation, it shall constitute a new emissions unit.</P>
            <P>(xxii) <E T="03">Temporary clean coal technology demonstration project</E> means a clean coal technology demonstration project that is operated for a period of 5 years or less, and which complies with the State Implementation Plan for the State in which the project is located and other requirements necessary to attain and maintain the national ambient air quality standards during the project and after it is terminated.</P>
            <P>(xxiii) <E T="03">Clean coal technology</E> means any technology, including technologies applied at the precombustion, combustion, or post combustion stage, at a new or existing facility which will achieve significant reductions in air emissions of sulfur dioxide or oxides of nitrogen associated with the utilization of coal in the generation of electricity, or process steam which was not in widespread use as of November 15, 1990.</P>
            <P>(xxiv) <E T="03">Clean coal technology demonstration project</E> means a project using funds appropriated under the heading “Department of Energy-Clean Coal Technology,” up to a total amount of $2,500,000,000 for commercial demonstration of clean coal technology, or similar projects funded through appropriations for the Environmental Protection Agency. The Federal contribution for a qualifying project shall be at least 20 percent of the total cost of the demonstration project.</P>
            <P>(xxv) <E T="03">Pollution control project (PCP)</E> means any activity, set of work practices or project (including pollution prevention as defined under paragraph (a)(1)(xxvi) of this section) undertaken at an existing emissions unit that reduces emissions of air pollutants from such unit. Such qualifying activities or projects can include the replacement or upgrade of an existing emissions control technology with a more effective unit. Other changes that may <PRTPAGE P="196"/>occur at the source are not considered part of the PCP if they are not necessary to reduce emissions through the PCP. Projects listed in paragraphs (a)(1)(xxv)(A) through (F) of this section are presumed to be environmentally beneficial pursuant to paragraph (e)(2)(i) of this section. Projects not listed in these paragraphs may qualify for a case-specific PCP exclusion pursuant to the requirements of paragraphs (e)(2) and (e)(5) of this section.</P>

            <P>(A) Conventional or advanced flue gas desulfurization or sorbent injection for control of SO<E T="52">2</E>.</P>
            <P>(B) Electrostatic precipitators, baghouses, high efficiency multiclones, or scrubbers for control of particulate matter or other pollutants.</P>
            <P>(C) Flue gas recirculation, low-NO<E T="52">X</E> burners or combustors, selective non-catalytic reduction, selective catalytic reduction, low emission combustion (for IC engines), and oxidation/absorption catalyst for control of NO<E T="52">X</E>.</P>
            <P>(D) Regenerative thermal oxidizers, catalytic oxidizers, condensers, thermal incinerators, hydrocarbon combustion flares, biofiltration, absorbers and adsorbers, and floating roofs for storage vessels for control of volatile organic compounds or hazardous air pollutants. For the purpose of this section, “hydrocarbon combustion flare” means either a flare used to comply with an applicable NSPS or MACT standard (including uses of flares during startup, shutdown, or malfunction permitted under such a standard), or a flare that serves to control emissions of waste streams comprised predominately of hydrocarbons and containing no more than 230 mg/dscm hydrogen sulfide.</P>
            <P>(E) Activities or projects undertaken to accommodate switching (or partially switching) to an inherently less polluting fuel, to be limited to the following fuel switches:</P>
            <P>(<E T="03">1</E>) Switching from a heavier grade of fuel oil to a lighter fuel oil, or any grade of oil to 0.05 percent sulfur diesel (<E T="03">i.e.,</E> from a higher sulfur content #2 fuel or from #6 fuel, to CA 0.05 percent sulfur #2 diesel);</P>
            <P>(<E T="03">2</E>) Switching from coal, oil, or any solid fuel to natural gas, propane, or gasified coal;</P>
            <P>(<E T="03">3</E>) Switching from coal to wood, excluding construction or demolition waste, chemical or pesticide treated wood, and other forms of “unclean” wood;</P>
            <P>(<E T="03">4</E>) Switching from coal to #2 fuel oil (0.5 percent maximum sulfur content); and</P>
            <P>(<E T="03">5</E>) Switching from high sulfur coal to low sulfur coal (maximum 1.2 percent sulfur content).</P>

            <P>(F) Activities or projects undertaken to accommodate switching from the use of one ozone depleting substance (ODS) to the use of a substance with a lower or zero ozone depletion potential (ODP), including changes to equipment needed to accommodate the activity or project, that meet the requirements of paragraphs (a)(1)(xxv)(F)(<E T="03">1</E>) and (<E T="03">2</E>) of this section.</P>
            <P>(<E T="03">1</E>) The productive capacity of the equipment is not increased as a result of the activity or project.</P>
            <P>(<E T="03">2</E>) The projected usage of the new substance is lower, on an ODP-weighted basis, than the baseline usage of the replaced ODS. To make this determination, follow the procedure in paragraphs (a)(1)(xxv)(F)(<E T="03">2</E>)(<E T="03">i</E>) through (<E T="03">iv</E>) of this section.</P>
            <P>(<E T="03">i</E>) Determine the ODP of the substances by consulting 40 CFR part 82, subpart A, appendices A and B.</P>
            <P>(<E T="03">ii</E>) Calculate the replaced ODP-weighted amount by multiplying the baseline actual usage (using the annualized average of any 24 consecutive months of usage within the past 10 years) by the ODP of the replaced ODS.</P>
            <P>(<E T="03">iii</E>) Calculate the projected ODP-weighted amount by multiplying the projected future annual usage of the new substance by its ODP.</P>
            <P>(<E T="03">iv</E>) If the value calculated in paragraph (a)(1)(xxv)(F)(<E T="03">2</E>)(<E T="03">ii</E>) of this section is more than the value calculated in paragraph (a)(1)(xxv)(F)(<E T="03">2</E>)(<E T="03">iii</E>) of this section, then the projected use of the new substance is lower, on an ODP-weighted basis, than the baseline usage of the replaced ODS.</P>
            <P>(xxvi) <E T="03">Pollution prevention</E> means any activity that through process changes, product reformulation or redesign, or substitution of less polluting raw materials, eliminates or reduces the release of air pollutants (including fugitive emissions) and other pollutants to <PRTPAGE P="197"/>the environment prior to recycling, treatment, or disposal; it does not mean recycling (other than certain “in-process recycling” practices), energy recovery, treatment, or disposal.</P>
            <P>(xxvii) <E T="03">Significant emissions increase</E> means, for a regulated NSR pollutant, an increase in emissions that is significant (as defined in paragraph (a)(1)(x) of this section) for that pollutant.</P>
            <P>(xxviii)(A) <E T="03">Projected actual emissions</E> means, the maximum annual rate, in tons per year, at which an existing emissions unit is projected to emit a regulated NSR pollutant in any one of the 5 years (12-month period) following the date the unit resumes regular operation after the project, or in any one of the 10 years following that date, if the project involves increasing the emissions unit's design capacity or its potential to emit of that regulated NSR pollutant and full utilization of the unit would result in a significant emissions increase or a significant net emissions increase at the major stationary source.</P>
            <P>(B) In determining the projected actual emissions under paragraph (a)(1)(xxviii)(A) of this section before beginning actual construction, the owner or operator of the major stationary source:</P>
            <P>(<E T="03">1</E>) Shall consider all relevant information, including but not limited to, historical operational data, the company's own representations, the company's expected business activity and the company's highest projections of business activity, the company's filings with the State or Federal regulatory authorities, and compliance plans under the approved plan; and</P>
            <P>(<E T="03">2</E>) Shall include fugitive emissions to the extent quantifiable, and emissions associated with startups, shutdowns, and malfunctions; and</P>
            <P>(<E T="03">3</E>) Shall exclude, in calculating any increase in emissions that results from the particular project, that portion of the unit's emissions following the project that an existing unit could have accommodated during the consecutive 24-month period used to establish the baseline actual emissions under paragraph (a)(1)(xxxv) of this section and that are also unrelated to the particular project, including any increased utilization due to product demand growth; or,</P>
            <P>(<E T="03">4</E>) In lieu of using the method set out in paragraphs (a)(1)(xxviii)(B)(<E T="03">1</E>) through (<E T="03">3</E>) of this section, may elect to use the emissions unit's potential to emit, in tons per year, as defined under paragraph (a)(1)(iii) of this section.</P>
            <P>(xxix) <E T="03">Clean Unit</E> means any emissions unit that has been issued a major NSR permit that requires compliance with BACT or LAER, that is complying with such BACT/LAER requirements, and qualifies as a Clean Unit pursuant to regulations approved by the Administrator in accordance with paragraph (c) of this section; or any emissions unit that has been designated by a reviewing authority as a Clean Unit, based on the criteria in paragraphs (d)(3)(i) through (iv) of this section, using a plan-approved permitting process; or any emissions unit that has been designated as a Clean Unit by the Administrator in accordance with § 52.21(y)(3)(i) through (iv) of this chapter.</P>
            <P>(xxx) <E T="03">Nonattainment major new source review (NSR) program</E> means a major source preconstruction permit program that has been approved by the Administrator and incorporated into the plan to implement the requirements of this section, or a program that implements part 51, appendix S, Sections I through VI of this chapter. Any permit issued under such a program is a major NSR permit.</P>
            <P>(xxxi) <E T="03">Continuous emissions monitoring system (CEMS)</E> means all of the equipment that may be required to meet the data acquisition and availability requirements of this section, to sample, condition (if applicable), analyze, and provide a record of emissions on a continuous basis.</P>
            <P>(xxxii) <E T="03">Predictive emissions monitoring system (PEMS)</E> means all of the equipment necessary to monitor process and control device operational parameters (for example, control device secondary voltages and electric currents) and other information (for example, gas flow rate, O<E T="52">2</E> or CO<E T="52">2</E> concentrations), and calculate and record the mass emissions rate (for example, lb/hr) on a continuous basis.</P>
            <P>(xxxiii) <E T="03">Continuous parameter monitoring system (CPMS)</E> means all of the <PRTPAGE P="198"/>equipment necessary to meet the data acquisition and availability requirements of this section, to monitor process and control device operational parameters (for example, control device secondary voltages and electric currents) and other information (for example, gas flow rate, O<E T="52">2</E> or CO<E T="52">2</E> concentrations), and to record average operational parameter value(s) on a continuous basis.</P>
            <P>(xxxiv) <E T="03">Continuous emissions rate monitoring system (CERMS)</E> means the total equipment required for the determination and recording of the pollutant mass emissions rate (in terms of mass per unit of time).</P>
            <P>(xxxv) <E T="03">Baseline actual emissions</E> means the rate of emissions, in tons per year, of a regulated NSR pollutant, as determined in accordance with paragraphs (a)(1)(xxxv)(A) through (D) of this section.</P>
            <P>(A) For any existing electric utility steam generating unit, baseline actual emissions means the average rate, in tons per year, at which the unit actually emitted the pollutant during any consecutive 24-month period selected by the owner or operator within the 5-year period immediately preceding when the owner or operator begins actual construction of the project. The reviewing authority shall allow the use of a different time period upon a determination that it is more representative of normal source operation.</P>
            <P>(<E T="03">1</E>) The average rate shall include fugitive emissions to the extent quantifiable, and emissions associated with startups, shutdowns, and malfunctions.</P>
            <P>(<E T="03">2</E>) The average rate shall be adjusted downward to exclude any non-compliant emissions that occurred while the source was operating above any emission limitation that was legally enforceable during the consecutive 24-month period.</P>
            <P>(<E T="03">3</E>) For a regulated NSR pollutant, when a project involves multiple emissions units, only one consecutive 24-month period must be used to determine the baseline actual emissions for the emissions units being changed. A different consecutive 24-month period can be used for each regulated NSR pollutant.</P>
            <P>(<E T="03">4</E>) The average rate shall not be based on any consecutive 24-month period for which there is inadequate information for determining annual emissions, in tons per year, and for adjusting this amount if required by paragraph (a)(1)(xxxv)(A)(<E T="03">2</E>) of this section.</P>
            <P>(B) For an existing emissions unit (other than an electric utility steam generating unit), baseline actual emissions means the average rate, in tons per year, at which the emissions unit actually emitted the pollutant during any consecutive 24-month period selected by the owner or operator within the 10-year period immediately preceding either the date the owner or operator begins actual construction of the project, or the date a complete permit application is received by the reviewing authority for a permit required either under this section or under a plan approved by the Administrator, whichever is earlier, except that the 10-year period shall not include any period earlier than November 15, 1990.</P>
            <P>(<E T="03">1</E>) The average rate shall include fugitive emissions to the extent quantifiable, and emissions associated with startups, shutdowns, and malfunctions.</P>
            <P>(<E T="03">2</E>) The average rate shall be adjusted downward to exclude any non-compliant emissions that occurred while the source was operating above an emission limitation that was legally enforceable during the consecutive 24-month period.</P>
            <P>(<E T="03">3</E>) The average rate shall be adjusted downward to exclude any emissions that would have exceeded an emission limitation with which the major stationary source must currently comply, had such major stationary source been required to comply with such limitations during the consecutive 24-month period. However, if an emission limitation is part of a maximum achievable control technology standard that the Administrator proposed or promulgated under part 63 of this chapter, the baseline actual emissions need only be adjusted if the State has taken credit for such emissions reductions in an attainment demonstration or maintenance plan consistent with the requirements of paragraph (a)(3)(ii)(G) of this section.</P>
            <P>(<E T="03">4</E>) For a regulated NSR pollutant, when a project involves multiple emissions units, only one consecutive 24-<PRTPAGE P="199"/>month period must be used to determine the baseline actual emissions for the emissions units being changed. A different consecutive 24-month period can be used For each regulated NSR pollutant.</P>
            <P>(<E T="03">5</E>) The average rate shall not be based on any consecutive 24-month period for which there is inadequate information for determining annual emissions, in tons per year, and for adjusting this amount if required by paragraphs (a)(1)(xxxv)(B)(<E T="03">2</E>) and (<E T="03">3</E>) of this section.</P>
            <P>(C) For a new emissions unit, the baseline actual emissions for purposes of determining the emissions increase that will result from the initial construction and operation of such unit shall equal zero; and thereafter, for all other purposes, shall equal the unit's potential to emit.</P>
            <P>(D) For a PAL for a major stationary source, the baseline actual emissions shall be calculated for existing electric utility steam generating units in accordance with the procedures contained in paragraph (a)(1)(xxxv)(A) of this section, for other existing emissions units in accordance with the procedures contained in paragraph (a)(1)(xxxv)(B) of this section, and for a new emissions unit in accordance with the procedures contained in paragraph (a)(1)(xxxv)(C) of this section.</P>
            <P>(xxxvi) [Reserved]</P>
            <P>(xxxvii) <E T="03">Regulated NSR pollutant,</E> for purposes of this section, means the following:</P>
            <P>(A) Nitrogen oxides or any volatile organic compounds;</P>
            <P>(B) Any pollutant for which a national ambient air quality standard has been promulgated; or</P>
            <P>(C) Any pollutant that is a constituent or precursor of a general pollutant listed under paragraphs (a)(1)(xxxvii)(A) or (B) of this section, provided that a constituent or precursor pollutant may only be regulated under NSR as part of regulation of the general pollutant.</P>
            <P>(xxxviii) <E T="03">Reviewing authority</E> means the State air pollution control agency, local agency, other State agency, Indian tribe, or other agency authorized by the Administrator to carry out a permit program under this section and § 51.166, or the Administrator in the case of EPA-implemented permit programs under § 52.21.</P>
            <P>(xxxix) <E T="03">Project</E> means a physical change in, or change in the method of operation of, an existing major stationary source.</P>
            <P>(xl) <E T="03">Best available control technology (BACT)</E> means an emissions limitation (including a visible emissions standard) based on the maximum degree of reduction for each regulated NSR pollutant which would be emitted from any proposed major stationary source or major modification which the reviewing authority, on a case-by-case basis, taking into account energy, environmental, and economic impacts and other costs, determines is achievable for such source or modification through application of production processes or available methods, systems, and techniques, including fuel cleaning or treatment or innovative fuel combustion techniques for control of such pollutant. In no event shall application of best available control technology result in emissions of any pollutant which would exceed the emissions allowed by any applicable standard under 40 CFR part 60 or 61. If the reviewing authority determines that technological or economic limitations on the application of measurement methodology to a particular emissions unit would make the imposition of an emissions standard infeasible, a design, equipment, work practice, operational standard, or combination thereof, may be prescribed instead to satisfy the requirement for the application of BACT. Such standard shall, to the degree possible, set forth the emissions reduction achievable by implementation of such design, equipment, work practice or operation, and shall provide for compliance by means which achieve equivalent results.</P>
            <P>(xli) <E T="03">Prevention of Significant Deterioration (PSD) permit</E> means any permit that is issued under a major source preconstruction permit program that has been approved by the Administrator and incorporated into the plan to implement the requirements of § 51.166 of this chapter, or under the program in § 52.21 of this chapter.</P>
            <P>(xlii) <E T="03">Federal Land Manager</E> means, with respect to any lands in the United States, the Secretary of the department with authority over such lands.<PRTPAGE P="200"/>
            </P>
            <P>(xliii)(A) In general, <E T="03">process unit</E> means any collection of structures and/or equipment that processes, assembles, applies, blends, or otherwise uses material inputs to produce or store an intermediate or a completed product. A single stationary source may contain more than one process unit, and a process unit may contain more than one emissions unit.</P>
            <P>(B) Pollution control equipment is not part of the process unit, unless it serves a dual function as both process and control equipment. Administrative and warehousing facilities are not part of the process unit.</P>
            <P>(C) For replacement cost purposes, components shared between two or more process units are proportionately allocated based on capacity.</P>
            <P>(D) The following list identifies the process units at specific categories of stationary sources.</P>
            <P>(<E T="03">1</E>) For a steam electric generating facility, the process unit consists of those portions of the plant that contribute directly to the production of electricity. For example, at a pulverized coal-fired facility, the process unit would generally be the combination of those systems from the coal receiving equipment through the emission stack (excluding post-combustion pollution controls), including the coal handling equipment, pulverizers or coal crushers, feedwater heaters, ash handling, boiler, burners, turbine-generator set, condenser, cooling tower, water treatment system, air preheaters, and operating control systems. Each separate generating unit is a separate process unit.</P>
            <P>(<E T="03">2</E>) For a petroleum refinery, there are several categories of process units: those that separate and/or distill petroleum feedstocks; those that change molecular structures; petroleum treating processes; auxiliary facilities, such as steam generators and hydrogen production units; and those that load, unload, blend or store intermediate or completed products.</P>
            <P>(<E T="03">3</E>) For an incinerator, the process unit would consist of components from the feed pit or refuse pit to the stack, including conveyors, combustion devices, heat exchangers and steam generators, quench tanks, and fans.</P>
            <NOTE>
              <HD SOURCE="HED">Note to paragraph (a)(1)(xliii):</HD>

              <P>By a court order on December 24, 2003, this paragraph (a)(1)(xliii) is stayed indefinitely. The stayed provisions will become effective immediately if the court terminates the stay. At that time, EPA will publish a document in the <E T="04">Federal Register</E> advising the public of the termination of the stay.</P>
            </NOTE>
            <P>(xliv) <E T="03">Functionally equivalent component</E> means a component that serves the same purpose as the replaced component.</P>
            <NOTE>
              <HD SOURCE="HED">Note to paragraph (a)(1)(xliv):</HD>

              <P>By a court order on December 24, 2003, this paragraph (a)(1)(xliv) is stayed indefinitely. The stayed provisions will become effective immediately if the court terminates the stay. At that time, EPA will publish a document in the <E T="04">Federal Register</E> advising the public of the termination of the stay.</P>
            </NOTE>
            <P>(xlv) <E T="03">Fixed capital cost</E> means the capital needed to provide all the depreciable components. “Depreciable components” refers to all components of fixed capital cost and is calculated by subtracting land and working capital from the total capital investment, as defined in paragraph (a)(1)(xlvi) of this section.</P>
            <NOTE>
              <HD SOURCE="HED">Note to paragraph (a)(1)(xlv):</HD>

              <P>By a court order on December 24, 2003, this paragraph (a)(1)(xlv) is stayed indefinitely. The stayed provisions will become effective immediately if the court terminates the stay. At that time, EPA will publish a document in the <E T="04">Federal Register</E> advising the public of the termination of the stay.</P>
            </NOTE>
            <P>(xlvi) <E T="03">Total capital investment</E> means the sum of the following: All costs required to purchase needed process equipment (purchased equipment costs); the costs of labor and materials for installing that equipment (direct installation costs); the costs of site preparation and buildings; other costs such as engineering, construction and field expenses, fees to contractors, startup and performance tests, and contingencies (indirect installation costs); land for the process equipment; and working capital for the process equipment.</P>
            <NOTE>
              <HD SOURCE="HED">Note to paragraph (a)(1)(xlvi):</HD>

              <P>By a court order on December 24, 2003, this paragraph (a)(1)(xlvi) is stayed indefinitely. The stayed provisions will become effective immediately if the court terminates the stay. At that time, EPA will publish a document in the <E T="04">Federal Register</E> advising the public of the termination of the stay.</P>
            </NOTE>
            <PRTPAGE P="201"/>
            <P>(2) <E T="03">Applicability procedures.</E> (i) Each plan shall adopt a preconstruction review program to satisfy the requirements of sections 172(c)(5) and 173 of the Act for any area designated nonattainment for any national ambient air quality standard under subpart C of 40 CFR part 81. Such a program shall apply to any new major stationary source or major modification that is major for the pollutant for which the area is designated nonattainment under section 107(d)(1)(A)(i) of the Act, if the stationary source or modification would locate anywhere in the designated nonattainment area.</P>
            <P>(ii) Each plan shall use the specific provisions of paragraphs (a)(2)(ii)(A) through (F) of this section. Deviations from these provisions will be approved only if the State specifically demonstrates that the submitted provisions are more stringent than or at least as stringent in all respects as the corresponding provisions in paragraphs (a)(2)(ii)(A) through (F) of this section.</P>
            <P>(A) Except as otherwise provided in paragraphs (a)(2)(iii) and (iv) of this section, and consistent with the definition of major modification contained in paragraph (a)(1)(v)(A) of this section, a project is a major modification for a regulated NSR pollutant if it causes two types of emissions increases—a significant emissions increase (as defined in paragraph (a)(1)(xxvii) of this section), and a significant net emissions increase (as defined in paragraphs (a)(1)(vi) and (x) of this section). The project is not a major modification if it does not cause a significant emissions increase. If the project causes a significant emissions increase, then the project is a major modification only if it also results in a significant net emissions increase.</P>

            <P>(B) The procedure for calculating (before beginning actual construction) whether a significant emissions increase (<E T="03">i.e.,</E> the first step of the process) will occur depends upon the type of emissions units being modified, according to paragraphs (a)(2)(ii)(C) through (F) of this section. The procedure for calculating (before beginning actual construction) whether a significant net emissions increase will occur at the major stationary source (<E T="03">i.e.,</E> the second step of the process) is contained in the definition in paragraph (a)(1)(vi) of this section. Regardless of any such preconstruction projections, a major modification results if the project causes a significant emissions increase and a significant net emissions increase.</P>
            <P>(C) <E T="03">Actual-to-projected-actual applicability test for projects that only involve existing emissions units.</E> A significant emissions increase of a regulated NSR pollutant is projected to occur if the sum of the difference between the projected actual emissions (as defined in paragraph (a)(1)(xxviii) of this section) and the baseline actual emissions (as defined in paragraphs (a)(1)(xxxv)(A) and (B) of this section, as applicable), for each existing emissions unit, equals or exceeds the significant amount for that pollutant (as defined in paragraph (a)(1)(x) of this section).</P>
            <P>(D) <E T="03">Actual-to-potential test for projects that only involve construction of a new emissions unit(s).</E> A significant emissions increase of a regulated NSR pollutant is projected to occur if the sum of the difference between the potential to emit (as defined in paragraph (a)(1)(iii) of this section) from each new emissions unit following completion of the project and the baseline actual emissions (as defined in paragraph (a)(1)(xxxv)(C) of this section) of these units before the project equals or exceeds the significant amount for that pollutant (as defined in paragraph (a)(1)(x) of this section).</P>
            <P>(E) <E T="03">Emission test for projects that involve Clean Units.</E> For a project that will be constructed and operated at a Clean Unit without causing the emissions unit to lose its Clean Unit designation, no emissions increase is deemed to occur.</P>
            <P>(F) <E T="03">Hybrid test for projects that involve multiple types of emissions units.</E> A significant emissions increase of a regulated NSR pollutant is projected to occur if the sum of the emissions increases for each emissions unit, using the method specified in paragraphs (a)(2)(ii)(C) through (E) of this section as applicable with respect to each <PRTPAGE P="202"/>emissions unit, for each type of emissions unit equals or exceeds the significant amount for that pollutant (as defined in paragraph (a)(1)(x) of this section). For example, if a project involves both an existing emissions unit and a Clean Unit, the projected increase is determined by summing the values determined using the method specified in paragraph (a)(2)(ii)(C) of this section for the existing unit and using the method specified in paragraph (a)(2)(ii)(E) of this section for the Clean Unit.</P>
            <P>(iii) The plan shall require that for any major stationary source for a PAL for a regulated NSR pollutant, the major stationary source shall comply with requirements under paragraph (f) of this section.</P>
            <P>(iv) The plan shall require that an owner or operator undertaking a PCP (as defined in paragraph (a)(1)(xxv) of this section) shall comply with the requirements under paragraph (e) of this section.</P>
            <P>(3)(i) Each plan shall provide that for sources and modifications subject to any preconstruction review program adopted pursuant to this subsection the baseline for determining credit for emissions reductions is the emissions limit under the applicable State Implementation Plan in effect at the time the application to construct is filed, except that the offset baseline shall be the actual emissions of the source from which offset credit is obtained where;</P>
            <P>(A) The demonstration of reasonable further progress and attainment of ambient air quality standards is based upon the actual emissions of sources located within a designated nonattainment area for which the preconstruction review program was adopted; or</P>
            <P>(B) The applicable State Implementation Plan does not contain an emissions limitation for that source or source category.</P>
            <P>(ii) The plan shall further provide that:</P>
            <P>(A) Where the emissions limit under the applicable State Implementation Plan allows greater emissions than the potential to emit of the source, emissions offset credit will be allowed only for control below this potential;</P>
            <P>(B) For an existing fuel combustion source, credit shall be based on the allowable emissions under the applicable State Implementation Plan for the type of fuel being burned at the time the application to construct is filed. If the existing source commits to switch to a cleaner fuel at some future date, emissions offset credit based on the allowable (or actual) emissions for the fuels involved is not acceptable, unless the permit is conditioned to require the use of a specified alternative control measure which would achieve the same degree of emissions reduction should the source switch back to a dirtier fuel at some later date. The reviewing authority should ensure that adequate long-term supplies of the new fuel are available before granting emissions offset credit for fuel switches,</P>
            <P>(C)(<E T="03">1</E>) Emissions reductions achieved by shutting down an existing emission unit or curtailing production or operating hours may be generally credited for offsets if they meet the requirements in paragraphs (a)(3)(ii)(C)(<E T="03">1</E>)(<E T="03">i</E>) through (<E T="03">ii</E>) of this section.</P>
            <P>(<E T="03">i</E>) Such reductions are surplus, permanent, quantifiable, and federally enforceable.</P>
            <P>(<E T="03">ii</E>) The shutdown or curtailment occurred after the last day of the base year for the SIP planning process. For purposes of this paragraph, a reviewing authority may choose to consider a prior shutdown or curtailment to have occurred after the last day of the base year if the projected emissions inventory used to develop the attainment demonstration explicitly includes the emissions from such previously shutdown or curtailed emission units. However, in no event may credit be given for shutdowns that occurred before August 7, 1977.</P>
            <P>(<E T="03">2</E>) Emissions reductions achieved by shutting down an existing emissions unit or curtailing production or operating hours and that do not meet the requirements in paragraph (a)(3)(ii)(C)(<E T="03">1</E>)(<E T="03">ii</E>) of this section may be generally credited only if:</P>
            <P>(<E T="03">i</E>) The shutdown or curtailment occurred on or after the date the construction permit application is filed; or</P>
            <P>(<E T="03">ii</E>) The applicant can establish that the proposed new emissions unit is a <PRTPAGE P="203"/>replacement for the shutdown or curtailed emissions unit, and the emissions reductions achieved by the shutdown or curtailment met the requirements of paragraph (a)(3)(ii)(C)(<E T="03">1</E>)(<E T="03">i</E>) of this section.</P>
            <P>(D) No emissions credit may be allowed for replacing one hydrocarbon compound with another of lesser reactivity, except for those compounds listed in Table 1 of EPA's “Recommended Policy on Control of Volatile Organic Compounds” (42 FR 35314, July 8, 1977; (This document is also available from Mr. Ted Creekmore, Office of Air Quality Planning and Standards, (MD-15) Research Triangle Park, NC 27711.))</P>
            <P>(E) All emission reductions claimed as offset credit shall be federally enforceable;</P>
            <P>(F) Procedures relating to the permissible location of offsetting emissions shall be followed which are at least as stringent as those set out in 40 CFR part 51 appendix S section IV.D.</P>
            <P>(G) Credit for an emissions reduction can be claimed to the extent that the reviewing authority has not relied on it in issuing any permit under regulations approved pursuant to 40 CFR part 51 subpart I or the State has not relied on it in demonstration attainment or reasonable further progress.</P>
            <P>(H) Decreases in actual emissions resulting from the installation of add-on control technology or application of pollution prevention measures that were relied upon in designating an emissions unit as a Clean Unit or a project as a PCP cannot be used as offsets.</P>
            <P>(I) Decreases in actual emissions occurring at a Clean Unit cannot be used as offsets, except as provided in paragraphs (c)(8) and (d)(10) of this section. Similarly, decreases in actual emissions occurring at a PCP cannot be used as offsets, except as provided in paragraph (e)(6)(iv) of this section.</P>
            <P>(J) The total tonnage of increased emissions, in tons per year, resulting from a major modification that must be offset in accordance with section 173 of the Act shall be determined by summing the difference between the allowable emissions after the modification (as defined by paragraph (a)(1)(xi) of this section) and the actual emissions before the modification (as defined in paragraph (a)(1)(xii) of this section) for each emissions unit.</P>
            <P>(4) Each plan may provide that the provisions of this paragraph do not apply to a source or modification that would be a major stationary source or major modification only if fugitive emission to the extent quantifiable are considered in calculating the potential to emit of the stationary source or modification and the source does not belong to any of the following categories:</P>
            <P>(i) Coal cleaning plants (with thermal dryers);</P>
            <P>(ii) Kraft pulp mills;</P>
            <P>(iii) Portland cement plants;</P>
            <P>(iv) Primary zinc smelters;</P>
            <P>(v) Iron and steel mills;</P>
            <P>(vi) Primary aluminum ore reduction plants;</P>
            <P>(vii) Primary copper smelters;</P>
            <P>(viii) Municipal incinerators capable of charging more than 250 tons of refuse per day;</P>
            <P>(ix) Hydrofluoric, sulfuric, or citric acid plants;</P>
            <P>(x) Petroleum refineries;</P>
            <P>(xi) Lime plants;</P>
            <P>(xii) Phosphate rock processing plants;</P>
            <P>(xiii) Coke oven batteries;</P>
            <P>(xiv) Sulfur recovery plants;</P>
            <P>(xv) Carbon black plants (furnace process);</P>
            <P>(xvi) Primary lead smelters;</P>
            <P>(xvii) Fuel conversion plants;</P>
            <P>(xviii) Sintering plants;</P>
            <P>(xix) Secondary metal production plants;</P>
            <P>(xx) Chemical process plants;</P>
            <P>(xxi) Fossil-fuel boilers (or combination thereof) totaling more than 250 million British thermal units per hour heat input;</P>
            <P>(xxii) Petroleum storage and transfer units with a total storage capacity exceeding 300,000 barrels;</P>
            <P>(xxiii) Taconite ore processing plants;</P>
            <P>(xxiv) Glass fiber processing plants;</P>
            <P>(xxv) Charcoal production plants;</P>
            <P>(xxvi) Fossil fuel-fired steam electric plants of more than 250 million British thermal units per hour heat input;</P>

            <P>(xxvii) Any other stationary source category which, as of August 7, 1980, is being regulated under section 111 or 112 of the Act.<PRTPAGE P="204"/>
            </P>
            <P>(5) Each plan shall include enforceable procedures to provide that:</P>
            <P>(i) Approval to construct shall not relieve any owner or operator of the responsibility to comply fully with applicable provision of the plan and any other requirements under local, State or Federal law.</P>
            <P>(ii) At such time that a particular source or modification becomes a major stationary source or major modification solely by virtue of a relaxation in any enforcement limitation which was established after August 7, 1980, on the capacity of the source or modification otherwise to emit a pollutant, such as a restriction on hours of operation, then the requirements of regulations approved pursuant to this section shall apply to the source or modification as though construction had not yet commenced on the source or modification;</P>

            <P>(6) Each plan shall provide that the following specific provisions apply to projects at existing emissions units at a major stationary source (other than projects at a Clean Unit or at a source with a PAL) in circumstances where there is a reasonable possibility that a project that is not a part of a major modification may result in a significant emissions increase and the owner or operator elects to use the method specified in paragraphs (a)(1)(xxviii)(B)(<E T="03">1</E>) through (<E T="03">3</E>) of this section for calculating projected actual emissions. Deviations from these provisions will be approved only if the State specifically demonstrates that the submitted provisions are more stringent than or at least as stringent in all respects as the corresponding provisions in paragraphs (a)(6)(i) through (v) of this section.</P>
            <P>(i) Before beginning actual construction of the project, the owner or operator shall document and maintain a record of the following information:</P>
            <P>(A) A description of the project;</P>
            <P>(B) Identification of the emissions unit(s) whose emissions of a regulated NSR pollutant could be affected by the project; and</P>

            <P>(C) A description of the applicability test used to determine that the project is not a major modification for any regulated NSR pollutant, including the baseline actual emissions, the projected actual emissions, the amount of emissions excluded under paragraph (a)(1)(xxviii)(B)(<E T="03">3</E>) of this section and an explanation for why such amount was excluded, and any netting calculations, if applicable.</P>
            <P>(ii) If the emissions unit is an existing electric utility steam generating unit, before beginning actual construction, the owner or operator shall provide a copy of the information set out in paragraph (a)(6)(i) of this section to the reviewing authority. Nothing in this paragraph (a)(6)(ii) shall be construed to require the owner or operator of such a unit to obtain any determination from the reviewing authority before beginning actual construction.</P>
            <P>(iii) The owner or operator shall monitor the emissions of any regulated NSR pollutant that could increase as a result of the project and that is emitted by any emissions units identified in paragraph (a)(6)(i)(B) of this section; and calculate and maintain a record of the annual emissions, in tons per year on a calendar year basis, for a period of 5 years following resumption of regular operations after the change, or for a period of 10 years following resumption of regular operations after the change if the project increases the design capacity or potential to emit of that regulated NSR pollutant at such emissions unit.</P>
            <P>(iv) If the unit is an existing electric utility steam generating unit, the owner or operator shall submit a report to the reviewing authority within 60 days after the end of each year during which records must be generated under paragraph (a)(6)(iii) of this section setting out the unit's annual emissions during the year that preceded submission of the report.</P>

            <P>(v) If the unit is an existing unit other than an electric utility steam generating unit, the owner or operator shall submit a report to the reviewing authority if the annual emissions, in tons per year, from the project identified in paragraph (a)(6)(i) of this section, exceed the baseline actual emissions (as documented and maintained pursuant to paragraph (a)(6)(i)(C) of this section, by a significant amount (as defined in paragraph (a)(1)(x) of this section) for that regulated NSR pollutant, and if such emissions differ from <PRTPAGE P="205"/>the preconstruction projection as documented and maintained pursuant to paragraph (a)(6)(i)(C) of this section. Such report shall be submitted to the reviewing authority within 60 days after the end of such year. The report shall contain the following:</P>
            <P>(A) The name, address and telephone number of the major stationary source;</P>
            <P>(B) The annual emissions as calculated pursuant to paragraph (a)(6)(iii) of this section; and</P>

            <P>(C) Any other information that the owner or operator wishes to include in the report (<E T="03">e.g.,</E> an explanation as to why the emissions differ from the preconstruction projection).</P>
            <P>(7) Each plan shall provide that the owner or operator of the source shall make the information required to be documented and maintained pursuant to paragraph (a)(6) of this section available for review upon a request for inspection by the reviewing authority or the general public pursuant to the requirements contained in § 70.4(b)(3)(viii) of this chapter.</P>

            <P>(8) The plan shall provide that the requirements of this section applicable to major stationary sources and major modifications of volatile organic compounds shall apply to nitrogen oxides emissions from major stationary sources and major modifications of nitrogen oxides in an ozone transport region or in any ozone nonattainment area, except in ozone nonattainment areas or in portions of an ozone transport region where the Administrator has granted a NO<E T="52">X</E> waiver applying the standards set forth under section 182(f) of the Act and the waiver continues to apply.</P>
            <P>(9)(i) The plan shall require that in meeting the emissions offset requirements of paragraph (a)(3) of this section for ozone nonattainment areas that are subject to subpart 2, part D, title I of the Act, the ratio of total actual emissions reductions of VOC to the emissions increase of VOC shall be as follows:</P>
            <P>(A) In any marginal nonattainment area for ozone—at least 1.1:1;</P>
            <P>(B) In any moderate nonattainment area for ozone—at least 1.15:1;</P>
            <P>(C) In any serious nonattainment area for ozone—at least 1.2:1;</P>
            <P>(D) In any severe nonattainment area for ozone—at least 1.3:1 (except that the ratio may be at least 1.2:1 if the approved plan also requires all existing major sources in such nonattainment area to use BACT for the control of VOC); and</P>
            <P>(E) In any extreme nonattainment area for ozone—at least 1.5:1 (except that the ratio may be at least 1.2:1 if the approved plan also requires all existing major sources in such nonattainment area to use BACT for the control of VOC); and</P>
            <P>(ii) Notwithstanding the requirements of paragraph (a)(9)(i) of this section for meeting the requirements of paragraph (a)(3) of this section, the ratio of total actual emissions reductions of VOC to the emissions increase of VOC shall be at least 1.15:1 for all areas within an ozone transport region that is subject to subpart 2, part D, title I of the Act, except for serious, severe, and extreme ozone nonattainment areas that are subject to subpart 2, part D, title I of the Act.</P>
            <P>(iii) The plan shall require that in meeting the emissions offset requirements of paragraph (a)(3) of this section for ozone nonattainment areas that are subject to subpart 1, part D, title I of the Act (but are not subject to subpart 2, part D, title I of the Act, including 8-hour ozone nonattainment areas subject to 40 CFR 51.902(b)), the ratio of total actual emissions reductions of VOC to the emissions increase of VOC shall be at least 1:1.</P>
            <P>(10) The plan shall require that the requirements of this section applicable to major stationary sources and major modifications of PM-10 shall also apply to major stationary sources and major modifications of PM-10 precursors, except where the Administrator determines that such sources do not contribute significantly to PM-10 levels that exceed the PM-10 ambient standards in the area.</P>

            <P>(b)(1) Each plan shall include a preconstruction review permit program or its equivalent to satisfy the requirements of section 110(a)(2)(D)(i) of the Act for any new major stationary source or major modification as defined in paragraphs (a)(1) (iv) and (v) of this section. Such a program shall <PRTPAGE P="206"/>apply to any such source or modification that would locate in any area designated as attainment or unclassifiable for any national ambient air quality standard pursuant to section 107 of the Act, when it would cause or contribute to a violation of any national ambient air quality standard.</P>
            <P>(2) A major source or major modification will be considered to cause or contribute to a violation of a national ambient air quality standard when such source or modification would, at a minimum, exceed the following significance levels at any locality that does not or would not meet the applicable national standard:</P>
            <GPOTABLE CDEF="s30,r25,r25,r25,r25,r25" COLS="6" OPTS="L2">
              <BOXHD>
                <CHED H="1">Pollutant</CHED>
                <CHED H="1">Annual</CHED>
                <CHED H="1">Averaging time (hours)</CHED>
                <CHED H="2">24</CHED>
                <CHED H="2">8</CHED>
                <CHED H="2">3</CHED>
                <CHED H="2">1</CHED>
              </BOXHD>
              <ROW>
                <ENT I="01">SO<E T="52">2</E>
                </ENT>
                <ENT>1.0 µg/m<SU>3</SU>
                </ENT>
                <ENT>5 µg/m<SU>3</SU>
                </ENT>
                <ENT/>
                <ENT>25 µg/m<SU>3</SU>
                </ENT>
              </ROW>
              <ROW>
                <ENT I="01">PM<E T="52">10</E>
                </ENT>
                <ENT>1.0 µg/m<SU>3</SU>
                </ENT>
                <ENT>5 µg/m<SU>3</SU>
                </ENT>
              </ROW>
              <ROW>
                <ENT I="01">NO<E T="52">2</E>
                </ENT>
                <ENT>1.0 µg/m<SU>3</SU>
                </ENT>
              </ROW>
              <ROW>
                <ENT I="01">CO</ENT>
                <ENT/>
                <ENT/>
                <ENT>0.5 mg/m<SU>3</SU>
                </ENT>
                <ENT/>
                <ENT>2 mg/m<SU>3</SU>
                </ENT>
              </ROW>
            </GPOTABLE>
            <P>(3) Such a program may include a provision which allows a proposed major source or major modification subject to paragraph (b) of this section to reduce the impact of its emissions upon air quality by obtaining sufficient emission reductions to, at a minimum, compensate for its adverse ambient impact where the major source or major modification would otherwise cause or contribute to a violation of any national ambient air quality standard. The plan shall require that, in the absence of such emission reductions, the State or local agency shall deny the proposed construction.</P>
            <P>(4) The requirements of paragraph (b) of this section shall not apply to a major stationary source or major modification with respect to a particular pollutant if the owner or operator demonstrates that, as to that pollutant, the source or modification is located in an area designated as nonattainment pursuant to section 107 of the Act.</P>
            <P>(c) <E T="03">Clean Unit Test for emissions units that are subject to LAER.</E> The plan shall provide an owner or operator of a major stationary source the option of using the Clean Unit Test to determine whether emissions increases at a Clean Unit are part of a project that is a major modification according to the provisions in paragraphs (c)(1) through (9) of this section.</P>
            <P>(1) <E T="03">Applicability.</E> The provisions of this paragraph (c) apply to any emissions unit for which the reviewing authority has issued a major NSR permit within the past 10 years.</P>
            <P>(2) <E T="03">General provisions for Clean Units.</E> The provisions in paragraphs (c)(2)(i) through (v) of this section apply to a Clean Unit.</P>
            <P>(i) Any project for which the owner or operator begins actual construction after the effective date of the Clean Unit designation (as determined in accordance with paragraph (c)(4) of this section) and before the expiration date (as determined in accordance with paragraph (c)(5) of this section) will be considered to have occurred while the emissions unit was a Clean Unit.</P>
            <P>(ii) If a project at a Clean Unit does not cause the need for a change in the emission limitations or work practice requirements in the permit for the unit that were adopted in conjunction with LAER and the project would not alter any physical or operational characteristics that formed the basis for the LAER determination as specified in paragraph (c)(6)(iv) of this section, the emissions unit remains a Clean Unit.</P>

            <P>(iii) If a project causes the need for a change in the emission limitations or work practice requirements in the permit for the unit that were adopted in conjunction with LAER or the project would alter any physical or operational characteristics that formed the basis for the LAER determination as specified in paragraph (c)(6)(iv) of this section, then the emissions unit loses its designation as a Clean Unit upon issuance of the necessary permit revisions (unless the unit requalifies as a Clean Unit pursuant to paragraph (c)(3)(iii) of this section). If the owner or operator begins actual construction <PRTPAGE P="207"/>on the project without first applying to revise the emissions unit's permit, the Clean Unit designation ends immediately prior to the time when actual construction begins.</P>
            <P>(iv) A project that causes an emissions unit to lose its designation as a Clean Unit is subject to the applicability requirements of paragraphs (a)(2)(ii)(A) through (D) and paragraph (a)(2)(ii)(F) of this section as if the emissions unit is not a Clean Unit.</P>
            <P>(v) <E T="03">Certain Emissions Units with PSD permits.</E> For emissions units that meet the requirements of paragraphs (c)(2)(v)(A) and (B) of this section, the BACT level of emissions reductions and/or work practice requirements shall satisfy the requirement for LAER in meeting the requirements for Clean Units under paragraphs (c)(3) through (8) of this section. For these emissions units, all requirements for the LAER determination under paragraphs (c)(2)(ii) and (iii) of this section shall also apply to the BACT permit terms and conditions. In addition, the requirements of paragraph (c)(7)(i)(B) of this section do not apply to emissions units that qualify for Clean Unit status under this paragraph (c)(2)(v).</P>
            <P>(A) The emissions unit must have received a PSD permit within the last 10 years and such permit must require the emissions unit to comply with BACT.</P>
            <P>(B) The emissions unit must be located in an area that was redesignated as nonattainment for the relevant pollutant(s) after issuance of the PSD permit and before the effective date of the Clean Unit Test provisions in the area.</P>
            <P>(3) <E T="03">Qualifying or re-qualifying to use the Clean Unit applicability test.</E> An emissions unit automatically qualifies as a Clean Unit when the unit meets the criteria in paragraphs (c)(3)(i) and (ii) of this section. After the original Clean Unit designation expires in accordance with paragraph (c)(5) of this section or is lost pursuant to paragraph (c)(2)(iii) of this section, such emissions unit may re-qualify as a Clean Unit under either paragraph (c)(3)(iii) of this section, or under the Clean Unit provisions in paragraph (d) of this section. To re-qualify as a Clean Unit under paragraph (c)(3)(iii) of this section, the emissions unit must obtain a new major NSR permit issued through the applicable nonattainment major NSR program and meet all the criteria in paragraph (c)(3)(iii) of this section. Clean Unit designation applies individually for each pollutant emitted by the emissions unit.</P>
            <P>(i) <E T="03">Permitting requirement.</E> The emissions unit must have received a major NSR permit within the past 10 years. The owner or operator must maintain and be able to provide information that would demonstrate that this permitting requirement is met.</P>
            <P>(ii) <E T="03">Qualifying air pollution control technologies.</E> Air pollutant emissions from the emissions unit must be reduced through the use of an air pollution control technology (which includes pollution prevention as defined under paragraph (a)(1)(xxvi) of this section or work practices) that meets both the following requirements in paragraphs (c)(3)(ii)(A) and (B) of this section.</P>
            <P>(A) The control technology achieves the LAER level of emissions reductions as determined through issuance of a major NSR permit within the past 10 years. However, the emissions unit is not eligible for Clean Unit designation if the LAER determination resulted in no requirement to reduce emissions below the level of a standard, uncontrolled, new emissions unit of the same type.</P>
            <P>(B) The owner or operator made an investment to install the control technology. For the purpose of this determination, an investment includes expenses to research the application of a pollution prevention technique to the emissions unit or expenses to apply a pollution prevention technique to an emissions unit.</P>
            <P>(iii) <E T="03">Re-qualifying for the Clean Unit designation.</E> The emissions unit must obtain a new major NSR permit that requires compliance with the current-day LAER, and the emissions unit must meet the requirements in paragraphs (c)(3)(i) and (c)(3)(ii) of this section.</P>
            <P>(4) <E T="03">Effective date of the Clean Unit designation.</E> The effective date of an emissions unit's Clean Unit designation (that is, the date on which the owner or operator may begin to use the Clean Unit Test to determine whether a project at the emissions unit is a major <PRTPAGE P="208"/>modification) is determined according to the applicable paragraph (c)(4)(i) or (c)(4)(ii) of this section.</P>
            <P>(i) <E T="03">Original Clean Unit designation, and emissions units that re-qualify as Clean Units by implementing a new control technology to meet current-day LAER.</E> The effective date is the date the emissions unit's air pollution control technology is placed into service, or 3 years after the issuance date of the major NSR permit, whichever is earlier, but no sooner than the date that provisions for the Clean Unit applicability test are approved by the Administrator for incorporation into the plan and become effective for the State in which the unit is located.</P>
            <P>(ii) <E T="03">Emissions units that re-qualify for the Clean Unit designation using an existing control technology.</E> The effective date is the date the new, major NSR permit is issued.</P>
            <P>(5) <E T="03">Clean Unit expiration.</E> An emissions unit's Clean Unit designation expires (that is, the date on which the owner or operator may no longer use the Clean Unit Test to determine whether a project affecting the emissions unit is, or is part of, a major modification) according to the applicable paragraph (c)(5)(i) or (ii) of this section.</P>
            <P>(i) <E T="03">Original Clean Unit designation, and emissions units that re-qualify by implementing new control technology to meet current-day LAER.</E> For any emissions unit that automatically qualifies as a Clean Unit under paragraphs (c)(3)(i) and (ii) of this section, the Clean Unit designation expires 10 years after the effective date, or the date the equipment went into service, whichever is earlier; or, it expires at any time the owner or operator fails to comply with the provisions for maintaining Clean Unit designation in paragraph (c)(7) of this section.</P>
            <P>(ii) <E T="03">Emissions units that re-qualify for the Clean Unit designation using an existing control technology.</E> For any emissions unit that re-qualifies as a Clean Unit under paragraph (c)(3)(iii) of this section, the Clean Unit designation expires 10 years after the effective date; or, it expires any time the owner or operator fails to comply with the provisions for maintaining the Clean Unit Designation in paragraph (c)(7) of this section.</P>
            <P>(6) <E T="03">Required title V permit content for a Clean Unit.</E> After the effective date of the Clean Unit designation, and in accordance with the provisions of the applicable title V permit program under part 70 or part 71 of this chapter, but no later than when the title V permit is renewed, the title V permit for the major stationary source must include the following terms and conditions in paragraphs (c)(6)(i) through (vi) of this section related to the Clean Unit.</P>
            <P>(i) A statement indicating that the emissions unit qualifies as a Clean Unit and identifying the pollutant(s) for which this Clean Unit designation applies.</P>
            <P>(ii) <E T="03">The effective date of the Clean Unit designation.</E> If this date is not known when the Clean Unit designation is initially recorded in the title V permit (<E T="03">e.g.,</E> because the air pollution control technology is not yet in service), the permit must describe the event that will determine the effective date (<E T="03">e.g.,</E> the date the control technology is placed into service). Once the effective date is determined, the owner or operator must notify the reviewing authority of the exact date. This specific effective date must be added to the source's title V permit at the first opportunity, such as a modification, revision, reopening, or renewal of the title V permit for any reason, whichever comes first, but in no case later than the next renewal.</P>
            <P>(iii) <E T="03">The expiration date of the Clean Unit designation.</E> If this date is not known when the Clean Unit designation is initially recorded into the title V permit (<E T="03">e.g.,</E> because the air pollution control technology is not yet in service), then the permit must describe the event that will determine the expiration date (<E T="03">e.g.,</E> the date the control technology is placed into service). Once the expiration date is determined, the owner or operator must notify the reviewing authority of the exact date. The expiration date must be added to the source's title V permit at the first opportunity, such as a modification, revision, reopening, or renewal of the title V permit for any reason, whichever comes first, but in no case later than the next renewal.<PRTPAGE P="209"/>
            </P>

            <P>(iv) All emission limitations and work practice requirements adopted in conjunction with the LAER, and any physical or operational characteristics that formed the basis for the LAER determination (<E T="03">e.g.,</E> possibly the emissions unit's capacity or throughput).</P>
            <P>(v) Monitoring, recordkeeping, and reporting requirements as necessary to demonstrate that the emissions unit continues to meet the criteria for maintaining the Clean Unit designation. (See paragraph (c)(7) of this section.)</P>
            <P>(vi) Terms reflecting the owner or operator's duties to maintain the Clean Unit designation and the consequences of failing to do so, as presented in paragraph (c)(7) of this section.</P>
            <P>(7) <E T="03">Maintaining the Clean Unit designation.</E> To maintain the Clean Unit designation, the owner or operator must conform to all the restrictions listed in paragraphs (c)(7)(i) through (iii) of this section. This paragraph (c)(7) applies independently to each pollutant for which the emissions unit has the Clean Unit designation. That is, failing to conform to the restrictions for one pollutant affects Clean Unit designation only for that pollutant.</P>
            <P>(i) The Clean Unit must comply with the emission limitation(s) and/or work practice requirements adopted in conjunction with the LAER that is recorded in the major NSR permit, and subsequently reflected in the title V permit.</P>

            <P>(A) The owner or operator may not make a physical change in or change in the method of operation of the Clean Unit that causes the emissions unit to function in a manner that is inconsistent with the physical or operational characteristics that formed the basis for the LAER determination (<E T="03">e.g.,</E> possibly the emissions unit's capacity or throughput).</P>
            <P>(B) The Clean Unit may not emit above a level that has been offset.</P>
            <P>(ii) The Clean Unit must comply with any terms and conditions in the title V permit related to the unit's Clean Unit designation.</P>
            <P>(iii) The Clean Unit must continue to control emissions using the specific air pollution control technology that was the basis for its Clean Unit designation. If the emissions unit or control technology is replaced, then the Clean Unit designation ends.</P>
            <P>(8) <E T="03">Offsets and netting at Clean Units.</E> Emissions changes that occur at a Clean Unit must not be included in calculating a significant net emissions increase (that is, must not be used in a “netting analysis”), or be used for generating offsets unless such use occurs before the effective date of the Clean Unit designation, or after the Clean Unit designation expires; or, unless the emissions unit reduces emissions below the level that qualified the unit as a Clean Unit. However, if the Clean Unit reduces emissions below the level that qualified the unit as a Clean Unit, then, the owner or operator may generate a credit for the difference between the level that qualified the unit as a Clean Unit and the new emission limitation if such reductions are surplus, quantifiable, and permanent. For purposes of generating offsets, the reductions must also be federally enforceable. For purposes of determining creditable net emissions increases and decreases, the reductions must also be enforceable as a practical matter.</P>
            <P>(9) <E T="03">Effect of redesignation on the Clean Unit designation.</E> The Clean Unit designation of an emissions unit is not affected by redesignation of the attainment status of the area in which it is located. That is, if a Clean Unit is located in an attainment area and the area is redesignated to nonattainment, its Clean Unit designation is not affected. Similarly, redesignation from nonattainment to attainment does not affect the Clean Unit designation. However, if an existing Clean Unit designation expires, it must re-qualify under the requirements that are currently applicable in the area.</P>
            <P>(d) <E T="03">Clean Unit provisions for emissions units that achieve an emission limitation comparable to LAER.</E> The plan shall provide an owner or operator of a major stationary source the option of using the Clean Unit Test to determine whether emissions increases at a Clean Unit are part of a project that is a major modification according to the provisions in paragraphs (d)(1) through (11) of this section.</P>
            <P>(1) <E T="03">Applicability.</E> The provisions of this paragraph (d) apply to emissions units which do not qualify as Clean <PRTPAGE P="210"/>Units under paragraph (c) of this section, but which are achieving a level of emissions control comparable to LAER, as determined by the reviewing authority in accordance with this paragraph (d).</P>
            <P>(2) <E T="03">General provisions for Clean Units.</E> The provisions in paragraphs (d)(2)(i) through (iv) of this section apply to a Clean Unit (designated under this paragraph (d)).</P>
            <P>(i) Any project for which the owner or operator begins actual construction after the effective date of the Clean Unit designation (as determined in accordance with paragraph (d)(5) of this section) and before the expiration date (as determined in accordance with paragraph (d)(6) of this section) will be considered to have occurred while the emissions unit was a Clean Unit.</P>
            <P>(ii) If a project at a Clean Unit does not cause the need for a change in the emission limitations or work practice requirements in the permit for the unit that have been determined (pursuant to paragraph (d)(4) of this section) to be comparable to LAER, and the project would not alter any physical or operational characteristics that formed the basis for determining that the emissions unit's control technology achieves a level of emissions control comparable to LAER as specified in paragraph (d)(8)(iv) of this section, the emissions unit remains a Clean Unit.</P>
            <P>(iii) If a project causes the need for a change in the emission limitations or work practice requirements in the permit for the unit that have been determined (pursuant to paragraph (d)(4) of this section) to be comparable to LAER, or the project would alter any physical or operational characteristics that formed the basis for determining that the emissions unit's control technology achieves a level of emissions control comparable to LAER as specified in paragraph (d)(8)(iv) of this section, then the emissions unit loses its designation as a Clean Unit upon issuance of the necessary permit revisions (unless the unit re-qualifies as a Clean Unit pursuant to paragraph (d)(3)(iv) of this section). If the owner or operator begins actual construction on the project without first applying to revise the emissions unit's permit, the Clean Unit designation ends immediately prior to the time when actual construction begins.</P>
            <P>(iv) A project that causes an emissions unit to lose its designation as a Clean Unit is subject to the applicability requirements of paragraphs (a)(2)(ii)(A) through (D) and paragraph (a)(2)(ii)(F) of this section as if the emissions unit were never a Clean Unit.</P>
            <P>(3) <E T="03">Qualifying or re-qualifying to use the Clean Unit applicability test.</E> An emissions unit qualifies as a Clean Unit when the unit meets the criteria in paragraphs (d)(3)(i) through (iii) of this section. After the original Clean Unit designation expires in accordance with paragraph (d)(6) of this section or is lost pursuant to paragraph (d)(2)(iii) of this section, such emissions unit may re-qualify as a Clean Unit under either paragraph (d)(3)(iv) of this section, or under the Clean Unit provisions in paragraph (c) of this section. To re-qualify as a Clean Unit under paragraph (d)(3)(iv) of this section, the emissions unit must obtain a new permit issued pursuant to the requirements in paragraphs (d)(7) and (8) of this section and meet all the criteria in paragraph (d)(3)(iv) of this section. The reviewing authority will make a separate Clean Unit designation for each pollutant emitted by the emissions unit for which the emissions unit qualifies as a Clean Unit.</P>
            <P>(i) <E T="03">Qualifying air pollution control technologies.</E> Air pollutant emissions from the emissions unit must be reduced through the use of air pollution control technology (which includes pollution prevention as defined under paragraph (a)(1)(xxvi) of this section or work practices) that meets both the following requirements in paragraphs (d)(3)(i)(A) and (B) of this section.</P>

            <P>(A) The owner or operator has demonstrated that the emissions unit's control technology is comparable to LAER according to the requirements of paragraph (d)(4) of this section. However, the emissions unit is not eligible for the Clean Unit designation if its emissions are not reduced below the level of a standard, uncontrolled emissions unit of the same type (<E T="03">e.g.,</E> if the LAER determinations to which it is <PRTPAGE P="211"/>compared have resulted in a determination that no control measures are required).</P>
            <P>(B) The owner or operator made an investment to install the control technology. For the purpose of this determination, an investment includes expenses to research the application of a pollution prevention technique to the emissions unit or to retool the unit to apply a pollution prevention technique.</P>
            <P>(ii) <E T="03">Impact of emissions from the unit.</E> The reviewing authority must determine that the allowable emissions from the emissions unit will not cause or contribute to a violation of any national ambient air quality standard or PSD increment, or adversely impact an air quality related value (such as visibility) that has been identified for a Federal Class I area by a Federal Land Manager and for which information is available to the general public.</P>
            <P>(iii) <E T="03">Date of installation.</E> An emissions unit may qualify as a Clean Unit even if the control technology, on which the Clean Unit designation is based, was installed before the effective date of plan requirements to implement the requirements of this paragraph (d)(3)(iii). However, for such emissions units, the owner or operator must apply for the Clean Unit designation within 2 years after the plan requirements become effective. For technologies installed after the plan requirements become effective, the owner or operator must apply for the Clean Unit designation at the time the control technology is installed.</P>
            <P>(iv) <E T="03">Re-qualifying as a Clean Unit.</E> The emissions unit must obtain a new permit (pursuant to requirements in paragraphs (d)(7) and (8) of this section) that demonstrates that the emissions unit's control technology is achieving a level of emission control comparable to current-day LAER, and the emissions unit must meet the requirements in paragraphs (d)(3)(i)(A) and (d)(3)(ii) of this section.</P>
            <P>(4) <E T="03">Demonstrating control effectiveness comparable to LAER.</E> The owner or operator may demonstrate that the emissions unit's control technology is comparable to LAER for purposes of paragraph (d)(3)(i) of this section according to either paragraph (d)(4)(i) or (ii) of this section. Paragraph (d)(4)(iii) of this section specifies the time for making this comparison.</P>
            <P>(i) <E T="03">Comparison to previous LAER determinations.</E> The administrator maintains an on-line data base of previous determinations of RACT, BACT, and LAER in the RACT/BACT/LAER Clearinghouse (RBLC). The emissions unit's control technology is presumed to be comparable to LAER if it achieves an emission limitation that is at least as stringent as any one of the five best-performing similar sources for which a LAER determination has been made within the preceding 5 years, and for which information has been entered into the RBLC. The reviewing authority shall also compare this presumption to any additional LAER determinations of which it is aware, and shall consider any information on achieved-in-practice pollution control technologies provided during the public comment period, to determine whether any presumptive determination that the control technology is comparable to LAER is correct.</P>
            <P>(ii) <E T="03">The substantially-as-effective test.</E> The owner or operator may demonstrate that the emissions unit's control technology is substantially as effective as LAER. In addition, any other person may present evidence related to whether the control technology is substantially as effective as LAER during the public participation process required under paragraph (d)(7) of this section. The reviewing authority shall consider such evidence on a case-by-case basis and determine whether the emissions unit's air pollution control technology is substantially as effective as LAER.</P>
            <P>(iii) <E T="03">Time of comparison</E>—(A) <E T="03">Emissions units with control technologies that are installed before the effective date of plan requirements implementing this paragraph.</E> The owner or operator of an emissions unit whose control technology is installed before the effective date of plan requirements implementing this paragraph (d) may, at its option, either demonstrate that the emission limitation achieved by the emissions unit's control technology is comparable to the LAER requirements that applied at the time the control technology was installed, or demonstrate that the emission limitation <PRTPAGE P="212"/>achieved by the emissions unit's control technology is comparable to current-day LAER requirements. The expiration date of the Clean Unit designation will depend on which option the owner or operator uses, as specified in paragraph (d)(6) of this section.</P>
            <P>(B) <E T="03">Emissions units with control technologies that are installed after the effective date of plan requirements implementing this paragraph.</E> The owner or operator must demonstrate that the emission limitation achieved by the emissions unit's control technology is comparable to current-day LAER requirements.</P>
            <P>(5) <E T="03">Effective date of the Clean Unit designation.</E> The effective date of an emissions unit's Clean Unit designation (that is, the date on which the owner or operator may begin to use the Clean Unit Test to determine whether a project involving the emissions unit is a major modification) is the date that the permit required by paragraph (d)(7) of this section is issued or the date that the emissions unit's air pollution control technology is placed into service, whichever is later.</P>
            <P>(6) <E T="03">Clean Unit expiration.</E> If the owner or operator demonstrates that the emission limitation achieved by the emissions unit's control technology is comparable to the LAER requirements that applied at the time the control technology was installed, then the Clean Unit designation expires 10 years from the date that the control technology was installed. For all other emissions units, the Clean Unit designation expires 10 years from the effective date of the Clean Unit designation, as determined according to paragraph (d)(5) of this section. In addition, for all emissions units, the Clean Unit designation expires any time the owner or operator fails to comply with the provisions for maintaining the Clean Unit designation in paragraph (d)(9) of this section.</P>
            <P>(7) <E T="03">Procedures for designating emissions units as Clean Units.</E> The reviewing authority shall designate an emissions unit a Clean Unit only by issuing a permit through a permitting program that has been approved by the Administrator and that conforms with the requirements of §§ 51.160 through 51.164 of this chapter including requirements for public notice of the proposed Clean Unit designation and opportunity for public comment. Such permit must also meet the requirements in paragraph (d)(8).</P>
            <P>(8) <E T="03">Required permit content.</E> The permit required by paragraph (d)(7) of this section shall include the terms and conditions set forth in paragraphs (d)(8)(i) through (vi) of this section. Such terms and conditions shall be incorporated into the major stationary source's title V permit in accordance with the provisions of the applicable title V permit program under part 70 or part 71 of this chapter, but no later than when the title V permit is renewed.</P>
            <P>(i) A statement indicating that the emissions unit qualifies as a Clean Unit and identifying the pollutant(s) for which this designation applies.</P>
            <P>(ii) <E T="03">The effective date of the Clean Unit designation.</E> If this date is not known when the reviewing authority issues the permit (<E T="03">e.g.,</E> because the air pollution control technology is not yet in service), then the permit must describe the event that will determine the effective date (<E T="03">e.g.,</E> the date the control technology is placed into service). Once the effective date is known, then the owner or operator must notify the reviewing authority of the exact date. This specific effective date must be added to the source's title V permit at the first opportunity, such as a modification, revision, reopening, or renewal of the title V permit for any reason, whichever comes first, but in no case later than the next renewal.</P>
            <P>(iii) <E T="03">The expiration date of the Clean Unit designation.</E> If this date is not known when the reviewing authority issues the permit (<E T="03">e.g.,</E> because the air pollution control technology is not yet in service), then the permit must describe the event that will determine the expiration date (<E T="03">e.g.,</E> the date the control technology is placed into service). Once the expiration date is known, then the owner or operator must notify the reviewing authority of the exact date. The expiration date must be added to the source's title V permit at the first opportunity, such as a modification, revision, reopening, or renewal of the title V permit for any <PRTPAGE P="213"/>reason, whichever comes first, but in no case later than the next renewal.</P>

            <P>(iv) All emission limitations and work practice requirements adopted in conjunction with emission limitations necessary to assure that the control technology continues to achieve an emission limitation comparable to LAER, and any physical or operational characteristics that formed the basis for determining that the emissions unit's control technology achieves a level of emissions control comparable to LAER (<E T="03">e.g.,</E> possibly the emissions unit's capacity or throughput).</P>
            <P>(v) Monitoring, recordkeeping, and reporting requirements as necessary to demonstrate that the emissions unit continues to meet the criteria for maintaining its Clean Unit designation. (See paragraph (d)(9) of this section.)</P>
            <P>(vi) Terms reflecting the owner or operator's duties to maintain the Clean Unit designation and the consequences of failing to do so, as presented in paragraph (d)(9) of this section.</P>
            <P>(9) <E T="03">Maintaining Clean Unit designation.</E> To maintain Clean Unit designation, the owner or operator must conform to all the restrictions listed in paragraphs (d)(9)(i) through (v) of this section. This paragraph (d)(9) applies independently to each pollutant for which the reviewing authority has designated the emissions unit a Clean Unit. That is, failing to conform to the restrictions for one pollutant affects the Clean Unit designation only for that pollutant.</P>
            <P>(i) The Clean Unit must comply with the emission limitation(s) and/or work practice requirements adopted to ensure that the control technology continues to achieve emission control comparable to LAER.</P>

            <P>(ii) The owner or operator may not make a physical change in or change in the method of operation of the Clean Unit that causes the emissions unit to function in a manner that is inconsistent with the physical or operational characteristics that formed the basis for the determination that the control technology is achieving a level of emission control that is comparable to LAER (<E T="03">e.g.,</E> possibly the emissions unit's capacity or throughput).</P>
            <P>(iii) The Clean Unit may not emit above a level that has been offset.</P>
            <P>(iv) The Clean Unit must comply with any terms and conditions in the title V permit related to the unit's Clean Unit designation.</P>
            <P>(v) The Clean Unit must continue to control emissions using the specific air pollution control technology that was the basis for its Clean Unit designation. If the emissions unit or control technology is replaced, then the Clean Unit designation ends.</P>
            <P>(10) <E T="03">Offsets and Netting at Clean Units.</E> Emissions changes that occur at a Clean Unit must not be included in calculating a significant net emissions increase (that is, must not be used in a “netting analysis”), or be used for generating offsets unless such use occurs before the effective date of plan requirements adopted to implement this paragraph (d) or after the Clean Unit designation expires; or, unless the emissions unit reduces emissions below the level that qualified the unit as a Clean Unit. However, if the Clean Unit reduces emissions below the level that qualified the unit as a Clean Unit, then the owner or operator may generate a credit for the difference between the level that qualified the unit as a Clean Unit and the emissions unit's new emission limitation if such reductions are surplus, quantifiable, and permanent. For purposes of generating offsets, the reductions must also be federally enforceable. For purposes of determining creditable net emissions increases and decreases, the reductions must also be enforceable as a practical matter.</P>
            <P>(11) <E T="03">Effect of redesignation on the Clean Unit designation.</E> The Clean Unit designation of an emissions unit is not affected by redesignation of the attainment status of the area in which it is located. That is, if a Clean Unit is located in an attainment area and the area is redesignated to nonattainment, its Clean Unit designation is not affected. Similarly, redesignation from nonattainment to attainment does not affect the Clean Unit designation. However, if a Clean Unit's designation expires or is lost pursuant to paragraphs (c)(2)(iii) and (d)(2)(iii) of this section, it must re-qualify under the requirements that are currently applicable.<PRTPAGE P="214"/>
            </P>
            <P>(e) <E T="03">PCP exclusion procedural requirements.</E> Each plan shall include provisions for PCPs equivalent to those contained in paragraphs (e)(1) through (6) of this section.</P>
            <P>(1) Before an owner or operator begins actual construction of a PCP, the owner or operator must either submit a notice to the reviewing authority if the project is listed in paragraphs (a)(1)(xxv)(A) through (F) of this section, or if the project is not listed in paragraphs (a)(1)(xxv)(A) through (F) of this section, then the owner or operator must submit a permit application and obtain approval to use the PCP exclusion from the reviewing authority consistent with the requirements in paragraph (e)(5) of this section. Regardless of whether the owner or operator submits a notice or a permit application, the project must meet the requirements in paragraph (e)(2) of this section, and the notice or permit application must contain the information required in paragraph (e)(3) of this section.</P>
            <P>(2) Any project that relies on the PCP exclusion must meet the requirements in paragraphs (e)(2)(i) and (ii) of this section.</P>
            <P>(i) <E T="03">Environmentally beneficial analysis.</E> The environmental benefit from the emission reductions of pollutants regulated under the Act must outweigh the environmental detriment of emissions increases in pollutants regulated under the Act. A statement that a technology from paragraphs (a)(1)(xxv)(A) through (F) of this section is being used shall be presumed to satisfy this requirement.</P>
            <P>(ii) <E T="03">Air quality analysis.</E> The emissions increases from the project will not cause or contribute to a violation of any national ambient air quality standard or PSD increment, or adversely impact an air quality related value (such as visibility) that has been identified for a Federal Class I area by a Federal Land Manager and for which information is available to the general public.</P>
            <P>(3) <E T="03">Content of notice or permit application.</E> In the notice or permit application sent to the reviewing authority, the owner or operator must include, at a minimum, the information listed in paragraphs (e)(3)(i) through (v) of this section.</P>
            <P>(i) A description of the project.</P>
            <P>(ii) The potential emissions increases and decreases of any pollutant regulated under the Act and the projected emissions increases and decreases using the methodology in paragraph (a)(2)(ii) of this section, that will result from the project, and a copy of the environmentally beneficial analysis required by paragraph (e)(2)(i) of this section.</P>
            <P>(iii) A description of monitoring and recordkeeping, and all other methods, to be used on an ongoing basis to demonstrate that the project is environmentally beneficial. Methods should be sufficient to meet the requirements in part 70 and part 71.</P>
            <P>(iv) A certification that the project will be designed and operated in a manner that is consistent with proper industry and engineering practices, in a manner that is consistent with the environmentally beneficial analysis and air quality analysis required by paragraphs (e)(2)(i) and (ii) of this section, with information submitted in the notice or permit application, and in such a way as to minimize, within the physical configuration and operational standards usually associated with the emissions control device or strategy, emissions of collateral pollutants.</P>

            <P>(v) Demonstration that the PCP will not have an adverse air quality impact (<E T="03">e.g.,</E> modeling, screening level modeling results, or a statement that the collateral emissions increase is included within the parameters used in the most recent modeling exercise) as required by paragraph (e)(2)(ii) of this section. An air quality impact analysis is not required for any pollutant which will not experience a significant emissions increase as a result of the project.</P>
            <P>(4) <E T="03">Notice process for listed projects.</E> For projects listed in paragraphs (a)(1)(xxv)(A) through (F) of this section, the owner or operator may begin actual construction of the project immediately after notice is sent to the reviewing authority (unless otherwise prohibited under requirements of the applicable plan). The owner or operator shall respond to any requests by its reviewing authority for additional information that the reviewing authority determines is necessary to evaluate the <PRTPAGE P="215"/>suitability of the project for the PCP exclusion.</P>
            <P>(5) <E T="03">Permit process for unlisted projects.</E> Before an owner or operator may begin actual construction of a PCP project that is not listed in paragraphs (a)(1)(xxv)(A) through (F) of this section, the project must be approved by the reviewing authority and recorded in a plan-approved permit or title V permit using procedures that are consistent with §§ 51.160 and 51.161 of this chapter. This includes the requirement that the reviewing authority provide the public with notice of the proposed approval, with access to the environmentally beneficial analysis and the air quality analysis, and provide at least a 30-day period for the public and the Administrator to submit comments. The reviewing authority must address all material comments received by the end of the comment period before taking final action on the permit.</P>
            <P>(6) <E T="03">Operational requirements.</E> Upon installation of the PCP, the owner or operator must comply with the requirements of paragraphs (e)(6)(i) through (iii) of this section.</P>
            <P>(i) <E T="03">General duty.</E> The owner or operator must operate the PCP in a manner consistent with proper industry and engineering practices, in a manner that is consistent with the environmentally beneficial analysis and air quality analysis required by paragraphs (e)(2)(i) and (ii) of this section, with information submitted in the notice or permit application required by paragraph (e)(3) of this section, and in such a way as to minimize, within the physical configuration and operational standards usually associated with the emissions control device or strategy, emissions of collateral pollutants.</P>
            <P>(ii) <E T="03">Recordkeeping.</E> The owner or operator must maintain copies on site of the environmentally beneficial analysis, the air quality impacts analysis, and monitoring and other emission records to prove that the PCP operated consistent with the general duty requirements in paragraph (e)(6)(i) of this section.</P>
            <P>(iii) <E T="03">Permit requirements.</E> The owner or operator must comply with any provisions in the plan-approved permit or title V permit related to use and approval of the PCP exclusion.</P>
            <P>(iv) <E T="03">Generation of emission reduction credits.</E> Emission reductions created by a PCP shall not be included in calculating a significant net emissions increase, or be used for generating offsets, unless the emissions unit further reduces emissions after qualifying for the PCP exclusion (<E T="03">e.g.,</E> taking an operational restriction on the hours of operation). The owner or operator may generate a credit for the difference between the level of reduction which was used to qualify for the PCP exclusion and the new emission limitation if such reductions are surplus, quantifiable, and permanent. For purposes of generating offsets, the reductions must also be federally enforceable. For purposes of determining creditable net emissions increases and decreases, the reductions must also be enforceable as a practical matter.</P>
            <P>(f) <E T="03">Actuals PALs.</E> The plan shall provide for PALs according to the provisions in paragraphs (f)(1) through (15) of this section.</P>
            <P>(1) <E T="03">Applicability.</E> (i) The reviewing authority may approve the use of an actuals PAL for any existing major stationary source (except as provided in paragraph (f)(1)(ii) of this section) if the PAL meets the requirements in paragraphs (f)(1) through (15) of this section. The term “PAL” shall mean “actuals PAL” throughout paragraph (f) of this section.</P>

            <P>(ii) The reviewing authority shall not allow an actuals PAL for VOC or NO<E T="52">X</E> for any major stationary source located in an extreme ozone nonattainment area.</P>
            <P>(iii) Any physical change in or change in the method of operation of a major stationary source that maintains its total source-wide emissions below the PAL level, meets the requirements in paragraphs (f)(1) through (15) of this section, and complies with the PAL permit:</P>
            <P>(A) Is not a major modification for the PAL pollutant;</P>
            <P>(B) Does not have to be approved through the plan's nonattainment major NSR program; and</P>

            <P>(C) Is not subject to the provisions in paragraph (a)(5)(ii) of this section (restrictions on relaxing enforceable <PRTPAGE P="216"/>emission limitations that the major stationary source used to avoid applicability of the nonattainment major NSR program).</P>
            <P>(iv) Except as provided under paragraph (f)(1)(iii)(C) of this section, a major stationary source shall continue to comply with all applicable Federal or State requirements, emission limitations, and work practice requirements that were established prior to the effective date of the PAL.</P>
            <P>(2) <E T="03">Definitions.</E> The plan shall use the definitions in paragraphs (f)(2)(i) through (xi) of this section for the purpose of developing and implementing regulations that authorize the use of actuals PALs consistent with paragraphs (f)(1) through (15) of this section. When a term is not defined in these paragraphs, it shall have the meaning given in paragraph (a)(1) of this section or in the Act.</P>
            <P>(i) <E T="03">Actuals PAL</E> for a major stationary source means a PAL based on the baseline actual emissions (as defined in paragraph (a)(1)(xxxv) of this section) of all emissions units (as defined in paragraph (a)(1)(vii) of this section) at the source, that emit or have the potential to emit the PAL pollutant.</P>
            <P>(ii) <E T="03">Allowable emissions</E> means “allowable emissions” as defined in paragraph (a)(1)(xi) of this section, except as this definition is modified according to paragraphs (f)(2)(ii)(A) through (B) of this section.</P>
            <P>(A) The allowable emissions for any emissions unit shall be calculated considering any emission limitations that are enforceable as a practical matter on the emissions unit's potential to emit.</P>
            <P>(B) An emissions unit's potential to emit shall be determined using the definition in paragraph (a)(1)(iii) of this section, except that the words “or enforceable as a practical matter” should be added after “federally enforceable.”</P>
            <P>(iii) <E T="03">Small emissions unit</E> means an emissions unit that emits or has the potential to emit the PAL pollutant in an amount less than the significant level for that PAL pollutant, as defined in paragraph (a)(1)(x) of this section or in the Act, whichever is lower.</P>
            <P>(iv) <E T="03">Major emissions unit</E> means:</P>
            <P>(A) Any emissions unit that emits or has the potential to emit 100 tons per year or more of the PAL pollutant in an attainment area; or</P>
            <P>(B) Any emissions unit that emits or has the potential to emit the PAL pollutant in an amount that is equal to or greater than the major source threshold for the PAL pollutant as defined by the Act for nonattainment areas. For example, in accordance with the definition of major stationary source in section 182(c) of the Act, an emissions unit would be a major emissions unit for VOC if the emissions unit is located in a serious ozone nonattainment area and it emits or has the potential to emit 50 or more tons of VOC per year.</P>
            <P>(v) <E T="03">Plantwide applicability limitation (PAL)</E> means an emission limitation expressed in tons per year, for a pollutant at a major stationary source, that is enforceable as a practical matter and established source-wide in accordance with paragraphs (f)(1) through (f)(15) of this section.</P>
            <P>(vi) <E T="03">PAL effective date</E> generally means the date of issuance of the PAL permit. However, the PAL effective date for an increased PAL is the date any emissions unit which is part of the PAL major modification becomes operational and begins to emit the PAL pollutant.</P>
            <P>(vii) <E T="03">PAL effective period</E> means the period beginning with the PAL effective date and ending 10 years later.</P>
            <P>(viii) <E T="03">PAL major modification</E> means, notwithstanding paragraphs (a)(1)(v) and (vi) of this section (the definitions for major modification and net emissions increase), any physical change in or change in the method of operation of the PAL source that causes it to emit the PAL pollutant at a level equal to or greater than the PAL.</P>
            <P>(ix) <E T="03">PAL permit</E> means the major NSR permit, the minor NSR permit, or the State operating permit under a program that is approved into the plan, or the title V permit issued by the reviewing authority that establishes a PAL for a major stationary source.</P>
            <P>(x) <E T="03">PAL pollutant</E> means the pollutant for which a PAL is established at a major stationary source.</P>
            <P>(xi) <E T="03">Significant emissions unit</E> means an emissions unit that emits or has the potential to emit a PAL pollutant in an amount that is equal to or greater than the significant level (as defined in <PRTPAGE P="217"/>paragraph (a)(1)(x) of this section or in the Act, whichever is lower) for that PAL pollutant, but less than the amount that would qualify the unit as a major emissions unit as defined in paragraph (f)(2)(iv) of this section.</P>
            <P>(3) <E T="03">Permit application requirements.</E> As part of a permit application requesting a PAL, the owner or operator of a major stationary source shall submit the following information to the reviewing authority for approval:</P>
            <P>(i) A list of all emissions units at the source designated as small, significant or major based on their potential to emit. In addition, the owner or operator of the source shall indicate which, if any, Federal or State applicable requirements, emission limitations or work practices apply to each unit.</P>
            <P>(ii) Calculations of the baseline actual emissions (with supporting documentation). Baseline actual emissions are to include emissions associated not only with operation of the unit, but also emissions associated with startup, shutdown and malfunction.</P>
            <P>(iii) The calculation procedures that the major stationary source owner or operator proposes to use to convert the monitoring system data to monthly emissions and annual emissions based on a 12-month rolling total for each month as required by paragraph (f)(13)(i) of this section.</P>
            <P>(4) <E T="03">General requirements for establishing PALs.</E> (i) The plan allows the reviewing authority to establish a PAL at a major stationary source, provided that at a minimum, the requirements in paragraphs (f)(4)(i)(A) through (G) of this section are met.</P>
            <P>(A) The PAL shall impose an annual emission limitation in tons per year, that is enforceable as a practical matter, for the entire major stationary source. For each month during the PAL effective period after the first 12 months of establishing a PAL, the major stationary source owner or operator shall show that the sum of the monthly emissions from each emissions unit under the PAL for the previous 12 consecutive months is less than the PAL (a 12-month average, rolled monthly). For each month during the first 11 months from the PAL effective date, the major stationary source owner or operator shall show that the sum of the preceding monthly emissions from the PAL effective date for each emissions unit under the PAL is less than the PAL.</P>
            <P>(B) The PAL shall be established in a PAL permit that meets the public participation requirements in paragraph (f)(5) of this section.</P>
            <P>(C) The PAL permit shall contain all the requirements of paragraph (f)(7) of this section.</P>
            <P>(D) The PAL shall include fugitive emissions, to the extent quantifiable, from all emissions units that emit or have the potential to emit the PAL pollutant at the major stationary source.</P>
            <P>(E) Each PAL shall regulate emissions of only one pollutant.</P>
            <P>(F) Each PAL shall have a PAL effective period of 10 years.</P>
            <P>(G) The owner or operator of the major stationary source with a PAL shall comply with the monitoring, recordkeeping, and reporting requirements provided in paragraphs (f)(12) through (14) of this section for each emissions unit under the PAL through the PAL effective period.</P>
            <P>(ii) At no time (during or after the PAL effective period) are emissions reductions of a PAL pollutant, which occur during the PAL effective period, creditable as decreases for purposes of offsets under paragraph (a)(3)(ii) of this section unless the level of the PAL is reduced by the amount of such emissions reductions and such reductions would be creditable in the absence of the PAL.</P>
            <P>(5) <E T="03">Public participation requirement for PALs.</E> PALs for existing major stationary sources shall be established, renewed, or increased through a procedure that is consistent with §§ 51.160 and 51.161 of this chapter. This includes the requirement that the reviewing authority provide the public with notice of the proposed approval of a PAL permit and at least a 30-day period for submittal of public comment. The reviewing authority must address all material comments before taking final action on the permit.</P>
            <P>(6) <E T="03">Setting the 10-year actuals PAL level.</E> (i) Except as provided in paragraph (f)(6)(ii) of this section, the plan shall provide that the actuals PAL level for a major stationary source <PRTPAGE P="218"/>shall be established as the sum of the baseline actual emissions (as defined in paragraph (a)(1)(xxxv) of this section) of the PAL pollutant for each emissions unit at the source; plus an amount equal to the applicable significant level for the PAL pollutant under paragraph (a)(1)(x) of this section or under the Act, whichever is lower. When establishing the actuals PAL level, for a PAL pollutant, only one consecutive 24-month period must be used to determine the baseline actual emissions for all existing emissions units. However, a different consecutive 24-month period may be used for each different PAL pollutant. Emissions associated with units that were permanently shut down after this 24-month period must be subtracted from the PAL level. The reviewing authority shall specify a reduced PAL level(s) (in tons/yr) in the PAL permit to become effective on the future compliance date(s) of any applicable Federal or State regulatory requirement(s) that the reviewing authority is aware of prior to issuance of the PAL permit. For instance, if the source owner or operator will be required to reduce emissions from industrial boilers in half from baseline emissions of 60 ppm NO<E T="52">X</E> to a new rule limit of 30 ppm, then the permit shall contain a future effective PAL level that is equal to the current PAL level reduced by half of the original baseline emissions of such unit(s).</P>
            <P>(ii) For newly constructed units (which do not include modifications to existing units) on which actual construction began after the 24-month period, in lieu of adding the baseline actual emissions as specified in paragraph (f)(6)(i) of this section, the emissions must be added to the PAL level in an amount equal to the potential to emit of the units.</P>
            <P>(7) <E T="03">Contents of the PAL permit.</E> The plan shall require that the PAL permit contain, at a minimum, the information in paragraphs (f)(7)(i) through (x) of this section.</P>
            <P>(i) The PAL pollutant and the applicable source-wide emission limitation in tons per year.</P>
            <P>(ii) The PAL permit effective date and the expiration date of the PAL (PAL effective period).</P>
            <P>(iii) Specification in the PAL permit that if a major stationary source owner or operator applies to renew a PAL in accordance with paragraph (f)(10) of this section before the end of the PAL effective period, then the PAL shall not expire at the end of the PAL effective period. It shall remain in effect until a revised PAL permit is issued by the reviewing authority.</P>
            <P>(iv) A requirement that emission calculations for compliance purposes include emissions from startups, shutdowns and malfunctions.</P>
            <P>(v) A requirement that, once the PAL expires, the major stationary source is subject to the requirements of paragraph (f)(9) of this section.</P>
            <P>(vi) The calculation procedures that the major stationary source owner or operator shall use to convert the monitoring system data to monthly emissions and annual emissions based on a 12-month rolling total for each month as required by paragraph (f)(13)(i) of this section.</P>
            <P>(vii) A requirement that the major stationary source owner or operator monitor all emissions units in accordance with the provisions under paragraph (f)(12) of this section.</P>
            <P>(viii) A requirement to retain the records required under paragraph (f)(13) of this section on site. Such records may be retained in an electronic format.</P>
            <P>(ix) A requirement to submit the reports required under paragraph (f)(14) of this section by the required deadlines.</P>
            <P>(x) Any other requirements that the reviewing authority deems necessary to implement and enforce the PAL.</P>
            <P>(8) <E T="03">PAL effective period and reopening of the PAL permit.</E> The plan shall require the information in paragraphs (f)(8)(i) and (ii) of this section.</P>
            <P>(i) <E T="03">PAL effective period.</E> The reviewing authority shall specify a PAL effective period of 10 years.</P>
            <P>(ii) <E T="03">Reopening of the PAL permit.</E> (A) During the PAL effective period, the plan shall require the reviewing authority to reopen the PAL permit to:</P>
            <P>(<E T="03">1</E>) Correct typographical/calculation errors made in setting the PAL or reflect a more accurate determination of emissions used to establish the PAL.<PRTPAGE P="219"/>
            </P>
            <P>(<E T="03">2</E>) Reduce the PAL if the owner or operator of the major stationary source creates creditable emissions reductions for use as offsets under paragraph (a)(3)(ii) of this section.</P>
            <P>(<E T="03">3</E>) Revise the PAL to reflect an increase in the PAL as provided under paragraph (f)(11) of this section.</P>
            <P>(B) The plan shall provide the reviewing authority discretion to reopen the PAL permit for the following:</P>
            <P>(<E T="03">1</E>) Reduce the PAL to reflect newly applicable Federal requirements (for example, NSPS) with compliance dates after the PAL effective date.</P>
            <P>(<E T="03">2</E>) Reduce the PAL consistent with any other requirement, that is enforceable as a practical matter, and that the State may impose on the major stationary source under the plan.</P>
            <P>(<E T="03">3</E>) Reduce the PAL if the reviewing authority determines that a reduction is necessary to avoid causing or contributing to a NAAQS or PSD increment violation, or to an adverse impact on an air quality related value that has been identified for a Federal Class I area by a Federal Land Manager and for which information is available to the general public.</P>

            <P>(C) Except for the permit reopening in paragraph (f)(8)(ii)(A)(<E T="03">1</E>) of this section for the correction of typographical/calculation errors that do not increase the PAL level, all other reopenings shall be carried out in accordance with the public participation requirements of paragraph (f)(5) of this section.</P>
            <P>(9) <E T="03">Expiration of a PAL.</E> Any PAL which is not renewed in accordance with the procedures in paragraph (f)(10) of this section shall expire at the end of the PAL effective period, and the requirements in paragraphs (f)(9)(i) through (v) of this section shall apply.</P>
            <P>(i) Each emissions unit (or each group of emissions units) that existed under the PAL shall comply with an allowable emission limitation under a revised permit established according to the procedures in paragraphs (f)(9)(i)(A) through (B) of this section.</P>
            <P>(A) Within the time frame specified for PAL renewals in paragraph (f)(10)(ii) of this section, the major stationary source shall submit a proposed allowable emission limitation for each emissions unit (or each group of emissions units, if such a distribution is more appropriate as decided by the reviewing authority) by distributing the PAL allowable emissions for the major stationary source among each of the emissions units that existed under the PAL. If the PAL had not yet been adjusted for an applicable requirement that became effective during the PAL effective period, as required under paragraph (f)(10)(v) of this section, such distribution shall be made as if the PAL had been adjusted.</P>
            <P>(B) The reviewing authority shall decide whether and how the PAL allowable emissions will be distributed and issue a revised permit incorporating allowable limits for each emissions unit, or each group of emissions units, as the reviewing authority determines is appropriate.</P>
            <P>(ii) Each emissions unit(s) shall comply with the allowable emission limitation on a 12-month rolling basis. The reviewing authority may approve the use of monitoring systems (source testing, emission factors, etc.) other than CEMS, CERMS, PEMS or CPMS to demonstrate compliance with the allowable emission limitation.</P>
            <P>(iii) Until the reviewing authority issues the revised permit incorporating allowable limits for each emissions unit, or each group of emissions units, as required under paragraph (f)(9)(i)(A) of this section, the source shall continue to comply with a source-wide, multi-unit emissions cap equivalent to the level of the PAL emission limitation.</P>
            <P>(iv) Any physical change or change in the method of operation at the major stationary source will be subject to the nonattainment major NSR requirements if such change meets the definition of major modification in paragraph (a)(1)(v) of this section.</P>

            <P>(v) The major stationary source owner or operator shall continue to comply with any State or Federal applicable requirements (BACT, RACT, NSPS, etc.) that may have applied either during the PAL effective period or prior to the PAL effective period except for those emission limitations that had been established pursuant to paragraph (a)(5)(ii) of this section, but <PRTPAGE P="220"/>were eliminated by the PAL in accordance with the provisions in paragraph (f)(1)(iii)(C) of this section.</P>
            <P>(10) <E T="03">Renewal of a PAL.</E> (i) The reviewing authority shall follow the procedures specified in paragraph (f)(5) of this section in approving any request to renew a PAL for a major stationary source, and shall provide both the proposed PAL level and a written rationale for the proposed PAL level to the public for review and comment. During such public review, any person may propose a PAL level for the source for consideration by the reviewing authority.</P>
            <P>(ii) <E T="03">Application deadline.</E> The plan shall require that a major stationary source owner or operator shall submit a timely application to the reviewing authority to request renewal of a PAL. A timely application is one that is submitted at least 6 months prior to, but not earlier than 18 months from, the date of permit expiration. This deadline for application submittal is to ensure that the permit will not expire before the permit is renewed. If the owner or operator of a major stationary source submits a complete application to renew the PAL within this time period, then the PAL shall continue to be effective until the revised permit with the renewed PAL is issued.</P>
            <P>(iii) <E T="03">Application requirements.</E> The application to renew a PAL permit shall contain the information required in paragraphs (f)(10)(iii)(A) through (D) of this section.</P>
            <P>(A) The information required in paragraphs (f)(3)(i) through (iii) of this section.</P>
            <P>(B) A proposed PAL level.</P>
            <P>(C) The sum of the potential to emit of all emissions units under the PAL (with supporting documentation).</P>
            <P>(D) Any other information the owner or operator wishes the reviewing authority to consider in determining the appropriate level for renewing the PAL.</P>
            <P>(iv) <E T="03">PAL adjustment.</E> In determining whether and how to adjust the PAL, the reviewing authority shall consider the options outlined in paragraphs (f)(10)(iv)(A) and (B) of this section. However, in no case may any such adjustment fail to comply with paragraph (f)(10)(iv)(C) of this section.</P>
            <P>(A) If the emissions level calculated in accordance with paragraph (f)(6) of this section is equal to or greater than 80 percent of the PAL level, the reviewing authority may renew the PAL at the same level without considering the factors set forth in paragraph (f)(10)(iv)(B) of this section; or</P>
            <P>(B) The reviewing authority may set the PAL at a level that it determines to be more representative of the source's baseline actual emissions, or that it determines to be appropriate considering air quality needs, advances in control technology, anticipated economic growth in the area, desire to reward or encourage the source's voluntary emissions reductions, or other factors as specifically identified by the reviewing authority in its written rationale.</P>
            <P>(C) Notwithstanding paragraphs (f)(10)(iv)(A) and (B) of this section,</P>
            <P>(<E T="03">1</E>) If the potential to emit of the major stationary source is less than the PAL, the reviewing authority shall adjust the PAL to a level no greater than the potential to emit of the source; and</P>
            <P>(<E T="03">2</E>) The reviewing authority shall not approve a renewed PAL level higher than the current PAL, unless the major stationary source has complied with the provisions of paragraph (f)(11) of this section (increasing a PAL).</P>
            <P>(v) If the compliance date for a State or Federal requirement that applies to the PAL source occurs during the PAL effective period, and if the reviewing authority has not already adjusted for such requirement, the PAL shall be adjusted at the time of PAL permit renewal or title V permit renewal, whichever occurs first.</P>
            <P>(11) <E T="03">Increasing a PAL during the PAL effective period.</E> (i) The plan shall require that the reviewing authority may increase a PAL emission limitation only if the major stationary source complies with the provisions in paragraphs (f)(11)(i)(A) through (D) of this section.</P>

            <P>(A) The owner or operator of the major stationary source shall submit a complete application to request an increase in the PAL limit for a PAL major modification. Such application shall identify the emissions unit(s) <PRTPAGE P="221"/>contributing to the increase in emissions so as to cause the major stationary source's emissions to equal or exceed its PAL.</P>
            <P>(B) As part of this application, the major stationary source owner or operator shall demonstrate that the sum of the baseline actual emissions of the small emissions units, plus the sum of the baseline actual emissions of the significant and major emissions units assuming application of BACT equivalent controls, plus the sum of the allowable emissions of the new or modified emissions unit(s) exceeds the PAL. The level of control that would result from BACT equivalent controls on each significant or major emissions unit shall be determined by conducting a new BACT analysis at the time the application is submitted, unless the emissions unit is currently required to comply with a BACT or LAER requirement that was established within the preceding 10 years. In such a case, the assumed control level for that emissions unit shall be equal to the level of BACT or LAER with which that emissions unit must currently comply.</P>
            <P>(C) The owner or operator obtains a major NSR permit for all emissions unit(s) identified in paragraph (f)(11)(i)(A) of this section, regardless of the magnitude of the emissions increase resulting from them (that is, no significant levels apply). These emissions unit(s) shall comply with any emissions requirements resulting from the nonattainment major NSR program process (for example, LAER), even though they have also become subject to the PAL or continue to be subject to the PAL.</P>
            <P>(D) The PAL permit shall require that the increased PAL level shall be effective on the day any emissions unit that is part of the PAL major modification becomes operational and begins to emit the PAL pollutant.</P>
            <P>(ii) The reviewing authority shall calculate the new PAL as the sum of the allowable emissions for each modified or new emissions unit, plus the sum of the baseline actual emissions of the significant and major emissions units (assuming application of BACT equivalent controls as determined in accordance with paragraph (f)(11)(i)(B)), plus the sum of the baseline actual emissions of the small emissions units.</P>
            <P>(iii) The PAL permit shall be revised to reflect the increased PAL level pursuant to the public notice requirements of paragraph (f)(5) of this section.</P>
            <P>(12) <E T="03">Monitoring requirements for PALs</E>—(i) <E T="03">General requirements.</E> (A) Each PAL permit must contain enforceable requirements for the monitoring system that accurately determines plantwide emissions of the PAL pollutant in terms of mass per unit of time. Any monitoring system authorized for use in the PAL permit must be based on sound science and meet generally acceptable scientific procedures for data quality and manipulation. Additionally, the information generated by such system must meet minimum legal requirements for admissibility in a judicial proceeding to enforce the PAL permit.</P>
            <P>(B) The PAL monitoring system must employ one or more of the four general monitoring approaches meeting the minimum requirements set forth in paragraphs (f)(12)(ii)(A) through (D) of this section and must be approved by the reviewing authority.</P>
            <P>(C) Notwithstanding paragraph (f)(12)(i)(B) of this section, you may also employ an alternative monitoring approach that meets paragraph (f)(12)(i)(A) of this section if approved by the reviewing authority.</P>
            <P>(D) Failure to use a monitoring system that meets the requirements of this section renders the PAL invalid.</P>
            <P>(ii) Minimum Performance Requirements for Approved Monitoring Approaches. The following are acceptable general monitoring approaches when conducted in accordance with the minimum requirements in paragraphs (f)(12)(iii) through (ix) of this section:</P>
            <P>(A) Mass balance calculations for activities using coatings or solvents;</P>
            <P>(B) CEMS;</P>
            <P>(C) CPMS or PEMS; and</P>
            <P>(D) Emission Factors.</P>

            <P>(iii) Mass Balance Calculations. An owner or operator using mass balance calculations to monitor PAL pollutant emissions from activities using coating or solvents shall meet the following requirements:<PRTPAGE P="222"/>
            </P>
            <P>(A) Provide a demonstrated means of validating the published content of the PAL pollutant that is contained in or created by all materials used in or at the emissions unit;</P>
            <P>(B) Assume that the emissions unit emits all of the PAL pollutant that is contained in or created by any raw material or fuel used in or at the emissions unit, if it cannot otherwise be accounted for in the process; and</P>
            <P>(C) Where the vendor of a material or fuel, which is used in or at the emissions unit, publishes a range of pollutant content from such material, the owner or operator must use the highest value of the range to calculate the PAL pollutant emissions unless the reviewing authority determines there is site-specific data or a site-specific monitoring program to support another content within the range.</P>
            <P>(iv) CEMS. An owner or operator using CEMS to monitor PAL pollutant emissions shall meet the following requirements:</P>
            <P>(A) CEMS must comply with applicable Performance Specifications found in 40 CFR part 60, appendix B; and</P>
            <P>(B) CEMS must sample, analyze and record data at least every 15 minutes while the emissions unit is operating.</P>
            <P>(v) CPMS or PEMS. An owner or operator using CPMS or PEMS to monitor PAL pollutant emissions shall meet the following requirements:</P>
            <P>(A) The CPMS or the PEMS must be based on current site-specific data demonstrating a correlation between the monitored parameter(s) and the PAL pollutant emissions across the range of operation of the emissions unit; and</P>
            <P>(B) Each CPMS or PEMS must sample, analyze, and record data at least every 15 minutes, or at another less frequent interval approved by the reviewing authority, while the emissions unit is operating.</P>
            <P>(vi) Emission factors. An owner or operator using emission factors to monitor PAL pollutant emissions shall meet the following requirements:</P>
            <P>(A) All emission factors shall be adjusted, if appropriate, to account for the degree of uncertainty or limitations in the factors' development;</P>
            <P>(B) The emissions unit shall operate within the designated range of use for the emission factor, if applicable; and</P>
            <P>(C) If technically practicable, the owner or operator of a significant emissions unit that relies on an emission factor to calculate PAL pollutant emissions shall conduct validation testing to determine a site-specific emission factor within 6 months of PAL permit issuance, unless the reviewing authority determines that testing is not required.</P>
            <P>(vii) A source owner or operator must record and report maximum potential emissions without considering enforceable emission limitations or operational restrictions for an emissions unit during any period of time that there is no monitoring data, unless another method for determining emissions during such periods is specified in the PAL permit.</P>
            <P>(viii) Notwithstanding the requirements in paragraphs (f)(12)(iii) through (vii) of this section, where an owner or operator of an emissions unit cannot demonstrate a correlation between the monitored parameter(s) and the PAL pollutant emissions rate at all operating points of the emissions unit, the reviewing authority shall, at the time of permit issuance:</P>
            <P>(A) Establish default value(s) for determining compliance with the PAL based on the highest potential emissions reasonably estimated at such operating point(s); or</P>
            <P>(B) Determine that operation of the emissions unit during operating conditions when there is no correlation between monitored parameter(s) and the PAL pollutant emissions is a violation of the PAL.</P>
            <P>(ix) Re-validation. All data used to establish the PAL pollutant must be re-validated through performance testing or other scientifically valid means approved by the reviewing authority. Such testing must occur at least once every 5 years after issuance of the PAL.</P>
            <P>(13) <E T="03">Recordkeeping requirements.</E> (i) The PAL permit shall require an owner or operator to retain a copy of all records necessary to determine compliance with any requirement of paragraph (f) of this section and of the PAL, including a determination of each <PRTPAGE P="223"/>emissions unit's 12-month rolling total emissions, for 5 years from the date of such record.</P>
            <P>(ii) The PAL permit shall require an owner or operator to retain a copy of the following records for the duration of the PAL effective period plus 5 years:</P>
            <P>(A) A copy of the PAL permit application and any applications for revisions to the PAL; and</P>
            <P>(B) Each annual certification of compliance pursuant to title V and the data relied on in certifying the compliance.</P>
            <P>(14) <E T="03">Reporting and notification requirements.</E> The owner or operator shall submit semi-annual monitoring reports and prompt deviation reports to the reviewing authority in accordance with the applicable title V operating permit program. The reports shall meet the requirements in paragraphs (f)(14)(i) through (iii).</P>
            <P>(i) Semi-Annual Report. The semi-annual report shall be submitted to the reviewing authority within 30 days of the end of each reporting period. This report shall contain the information required in paragraphs (f)(14)(i)(A) through (G) of this section.</P>
            <P>(A) The identification of owner and operator and the permit number.</P>
            <P>(B) Total annual emissions (tons/year) based on a 12-month rolling total for each month in the reporting period recorded pursuant to paragraph (f)(13)(i) of this section.</P>
            <P>(C) All data relied upon, including, but not limited to, any Quality Assurance or Quality Control data, in calculating the monthly and annual PAL pollutant emissions.</P>
            <P>(D) A list of any emissions units modified or added to the major stationary source during the preceding 6-month period.</P>
            <P>(E) The number, duration, and cause of any deviations or monitoring malfunctions (other than the time associated with zero and span calibration checks), and any corrective action taken.</P>
            <P>(F) A notification of a shutdown of any monitoring system, whether the shutdown was permanent or temporary, the reason for the shutdown, the anticipated date that the monitoring system will be fully operational or replaced with another monitoring system, and whether the emissions unit monitored by the monitoring system continued to operate, and the calculation of the emissions of the pollutant or the number determined by method included in the permit, as provided by paragraph (f)(12)(vii) of this section.</P>
            <P>(G) A signed statement by the responsible official (as defined by the applicable title V operating permit program) certifying the truth, accuracy, and completeness of the information provided in the report.</P>
            <P>(ii) Deviation report. The major stationary source owner or operator shall promptly submit reports of any deviations or exceedance of the PAL requirements, including periods where no monitoring is available. A report submitted pursuant to § 70.6(a)(3)(iii)(B) of this chapter shall satisfy this reporting requirement. The deviation reports shall be submitted within the time limits prescribed by the applicable program implementing § 70.6(a)(3)(iii)(B) of this chapter. The reports shall contain the following information:</P>
            <P>(A) The identification of owner and operator and the permit number;</P>
            <P>(B) The PAL requirement that experienced the deviation or that was exceeded;</P>
            <P>(C) Emissions resulting from the deviation or the exceedance; and</P>
            <P>(D) A signed statement by the responsible official (as defined by the applicable title V operating permit program) certifying the truth, accuracy, and completeness of the information provided in the report.</P>
            <P>(iii) Re-validation results. The owner or operator shall submit to the reviewing authority the results of any re-validation test or method within 3 months after completion of such test or method.</P>
            <P>(15) <E T="03">Transition requirements.</E> (i) No reviewing authority may issue a PAL that does not comply with the requirements in paragraphs (f)(1) through (15) of this section after the Administrator has approved regulations incorporating these requirements into a plan.</P>

            <P>(ii) The reviewing authority may supersede any PAL which was established prior to the date of approval of the plan by the Administrator with a PAL <PRTPAGE P="224"/>that complies with the requirements of paragraphs (f)(1) through (15) of this section.</P>
            <P>(g) If any provision of this section, or the application of such provision to any person or circumstance, is held invalid, the remainder of this section, or the application of such provision to persons or circumstances other than those as to which it is held invalid, shall not be affected thereby.</P>
            <P>(h) <E T="03">Equipment replacement provision.</E> Without regard to other considerations, routine maintenance, repair and replacement includes, but is not limited to, the replacement of any component of a process unit with an identical or functionally equivalent component(s), and maintenance and repair activities that are part of the replacement activity, provided that all of the requirements in paragraphs (h)(1) through (3) of this section are met.</P>
            <P>(1) <E T="03">Capital Cost threshold for Equipment Replacement.</E> (i) For an <E T="03">electric utility steam generating unit,</E> as defined in § 51.165(a)(1)(xx), the fixed capital cost of the replacement component(s) plus the cost of any associated maintenance and repair activities that are part of the replacement shall not exceed 20 percent of the replacement value of the process unit, at the time the equipment is replaced. For a process unit that is not an electric utility steam generating unit the fixed capital cost of the replacement component(s) plus the cost of any associated maintenance and repair activities that are part of the replacement shall not exceed 20 percent of the replacement value of the process unit, at the time the equipment is replaced.</P>
            <P>(ii) In determining the replacement value of the process unit; and, except as otherwise allowed under paragraph (h)(1)(iii) of this section, the owner or operator shall determine the replacement value of the process unit on an estimate of the fixed capital cost of constructing a new process unit, or on the current appraised value of the process unit.</P>
            <P>(iii) As an alternative to paragraph (h)(1)(ii) of this section for determining the replacement value of a process unit, an owner or operator may choose to use insurance value (where the insurance value covers only complete replacement), investment value adjusted for inflation, or another accounting procedure if such procedure is based on Generally Accepted Accounting Principles, provided that the owner or operator sends a notice to the reviewing authority. The first time that an owner or operator submits such a notice for a particular process unit, the notice may be submitted at any time, but any subsequent notice for that process unit may be submitted only at the beginning of the process unit's fiscal year. Unless the owner or operator submits a notice to the reviewing authority, then paragraph (h)(1)(ii) of this section will be used to establish the replacement value of the process unit. Once the owner or operator submits a notice to use an alternative accounting procedure, the owner or operator must continue to use that procedure for the entire fiscal year for that process unit. In subsequent fiscal years, the owner or operator must continue to use this selected procedure unless and until the owner or operator sends another notice to the reviewing authority selecting another procedure consistent with this paragraph or paragraph (h)(1)(ii) of this section at the beginning of such fiscal year.</P>
            <P>(2) <E T="03">Basic design parameters.</E> The replacement does not change the basic design parameter(s) of the process unit to which the activity pertains.</P>
            <NOTE>
              <HD SOURCE="HED">Note to paragraph (h):</HD>

              <P>By a court order on December 24, 2003, this paragraph (h) is stayed indefinitely. The stayed provisions will become effective immediately if the court terminates the stay. At that time, EPA will publish a document in the <E T="04">Federal Register</E> advising the public of the termination of the stay.</P>
            </NOTE>

            <P>(i) Except as provided in paragraph (h)(2)(iii) of this section, for a process unit at a steam electric generating facility, the owner or operator may select as its basic design parameters either maximum hourly heat input and maximum hourly fuel consumption rate or maximum hourly electric output rate and maximum steam flow rate. When establishing fuel consumption specifications in terms of weight or volume, the minimum fuel quality based on British Thermal Units content shall be used for determining the basic design parameter(s) for a coal-<PRTPAGE P="225"/>fired electric utility steam generating unit.</P>
            <P>(ii) Except as provided in paragraph (h)(2)(iii) of this section, the basic design parameter(s) for any process unit that is not at a steam electric generating facility are maximum rate of fuel or heat input, maximum rate of material input, or maximum rate of product output. Combustion process units will typically use maximum rate of fuel input. For sources having multiple end products and raw materials, the owner or operator should consider the primary product or primary raw material when selecting a basic design parameter.</P>
            <P>(iii) If the owner or operator believes the basic design parameter(s) in paragraphs (h)(2)(i) and (ii) of this section is not appropriate for a specific industry or type of process unit, the owner or operator may propose to the reviewing authority an alternative basic design parameter(s) for the source's process unit(s). If the reviewing authority approves of the use of an alternative basic design parameter(s), the reviewing authority shall issue a permit that is legally enforceable that records such basic design parameter(s) and requires the owner or operator to comply with such parameter(s).</P>
            <P>(iv) The owner or operator shall use credible information, such as results of historic maximum capability tests, design information from the manufacturer, or engineering calculations, in establishing the magnitude of the basic design parameter(s) specified in paragraphs (h)(2)(i) and (ii) of this section.</P>
            <P>(v) If design information is not available for a process unit, then the owner or operator shall determine the process unit's basic design parameter(s) using the maximum value achieved by the process unit in the five-year period immediately preceding the planned activity.</P>
            <P>(vi) Efficiency of a process unit is not a basic design parameter.</P>
            <P>(3) The replacement activity shall not cause the process unit to exceed any emission limitation, or operational limitation that has the effect of constraining emissions, that applies to the process unit and that is legally enforceable.</P>
            <CITA>[51 FR 40669, Nov. 7, 1986, as amended at 52 FR 24713, July 1, 1987; 52 FR 29386, Aug 7, 1987; 54 FR 27285, 27299 June 28, 1989; 57 FR 3946, Feb. 3, 1992; 57 FR 32334, July 21, 1992; 67 FR 80244, Dec. 31, 2002; 68 FR 61276, Oct. 27, 2003; 68 FR 63027, Nov. 7, 2003; 69 FR 40275, July 1, 2004; 70 FR 71698, Nov. 29, 2005]</CITA>
          </SECTION>
          <SECTION>
            <SECTNO>§ 51.166</SECTNO>
            <SUBJECT>Prevention of significant deterioration of air quality.</SUBJECT>
            <P>(a)(1) <E T="03">Plan requirements.</E> In accordance with the policy of section 101(b)(1) of the Act and the purposes of section 160 of the Act, each applicable State Implementation Plan and each applicable Tribal Implementation Plan shall contain emission limitations and such other measures as may be necessary to prevent significant deterioration of air quality.</P>
            <P>(2) <E T="03">Plan revisions.</E> If a State Implementation Plan revision would result in increased air quality deterioration over any baseline concentration, the plan revision shall include a demonstration that it will not cause or contribute to a violation of the applicable increment(s). If a plan revision proposing less restrictive requirements was submitted after August 7, 1977 but on or before any applicable baseline date and was pending action by the Administrator on that date, no such demonstration is necessary with respect to the area for which a baseline date would be established before final action is taken on the plan revision. Instead, the assessment described in paragraph (a)(4) of this section, shall review the expected impact to the applicable increment(s).</P>
            <P>(3) <E T="03">Required plan revision.</E> If the State or the Administrator determines that a plan is substantially inadequate to prevent significant deterioration or that an applicable increment is being violated, the plan shall be revised to correct the inadequacy or the violation. The plan shall be revised within 60 days of such a finding by a State or within 60 days following notification by the Administrator, or by such later date as prescribed by the Administrator after consultation with the State.</P>
            <P>(4) <E T="03">Plan assessment.</E> The State shall review the adequacy of a plan on a periodic basis and within 60 days of <PRTPAGE P="226"/>such time as information becomes available that an applicable increment is being violated.</P>
            <P>(5) <E T="03">Public participation.</E> Any State action taken under this paragraph shall be subject to the opportunity for public hearing in accordance with procedures equivalent to those established in § 51.102.</P>
            <P>(6) <E T="03">Amendments.</E> (i) Any State required to revise its implementation plan by reason of an amendment to this section, including any amendment adopted simultaneously with this paragraph (a)(6)(i), shall adopt and submit such plan revision to the Administrator for approval no later than three years after such amendment is published in the <E T="04">Federal Register</E>.</P>
            <P>(ii) Any revision to an implementation plan that would amend the provisions for the prevention of significant air quality deterioration in the plan shall specify when and as to what sources and modifications the revision is to take effect.</P>
            <P>(iii) Any revision to an implementation plan that an amendment to this section required shall take effect no later than the date of its approval and may operate prospectively.</P>
            <P>(7) <E T="03">Applicability.</E> Each plan shall contain procedures that incorporate the requirements in paragraphs (a)(7)(i) through (vi) of this section.</P>
            <P>(i) The requirements of this section apply to the construction of any new major stationary source (as defined in paragraph (b)(1) of this section) or any project at an existing major stationary source in an area designated as attainment or unclassifiable under sections 107(d)(1)(A)(ii) or (iii) of the Act.</P>
            <P>(ii) The requirements of paragraphs (j) through (r) of this section apply to the construction of any new major stationary source or the major modification of any existing major stationary source, except as this section otherwise provides.</P>
            <P>(iii) No new major stationary source or major modification to which the requirements of paragraphs (j) through (r)(5) of this section apply shall begin actual construction without a permit that states that the major stationary source or major modification will meet those requirements.</P>

            <P>(iv) Each plan shall use the specific provisions of paragraphs (a)(7)(iv)(<E T="03">a</E>) through (<E T="03">f</E>) of this section. Deviations from these provisions will be approved only if the State specifically demonstrates that the submitted provisions are more stringent than or at least as stringent in all respects as the corresponding provisions in paragraphs (a)(7)(iv)(<E T="03">a</E>) through (<E T="03">f</E>) of this section.</P>
            <P>(<E T="03">a</E>) Except as otherwise provided in paragraphs (a)(7)(v) and (vi) of this section, and consistent with the definition of major modification contained in paragraph (b)(2) of this section, a project is a major modification for a regulated NSR pollutant if it causes two types of emissions increases—a significant emissions increase (as defined in paragraph (b)(39) of this section), and a significant net emissions increase (as defined in paragraphs (b)(3) and (b)(23) of this section). The project is not a major modification if it does not cause a significant emissions increase. If the project causes a significant emissions increase, then the project is a major modification only if it also results in a significant net emissions increase.</P>
            <P>(<E T="03">b</E>) The procedure for calculating (before beginning actual construction) whether a significant emissions increase (<E T="03">i.e.,</E> the first step of the process) will occur depends upon the type of emissions units being modified, according to paragraphs (a)(7)(iv)(<E T="03">c</E>) through (<E T="03">f</E>) of this section. The procedure for calculating (before beginning actual construction) whether a significant net emissions increase will occur at the major stationary source (<E T="03">i.e.,</E> the second step of the process) is contained in the definition in paragraph (b)(3) of this section. Regardless of any such preconstruction projections, a major modification results if the project causes a significant emissions increase and a significant net emissions increase.</P>
            <P>(<E T="03">c</E>) <E T="03">Actual-to-projected-actual applicability test for projects that only involve existing emissions units.</E> A significant emissions increase of a regulated NSR pollutant is projected to occur if the sum of the difference between the projected actual emissions (as defined in paragraph (b)(40) of this section) and <PRTPAGE P="227"/>the baseline actual emissions (as defined in paragraphs (b)(47)(i) and (ii) of this section) for each existing emissions unit, equals or exceeds the significant amount for that pollutant (as defined in paragraph (b)(23) of this section).</P>
            <P>(<E T="03">d</E>) <E T="03">Actual-to-potential test for projects that only involve construction of a new emissions unit(s).</E> A significant emissions increase of a regulated NSR pollutant is projected to occur if the sum of the difference between the potential to emit (as defined in paragraph (b)(4) of this section) from each new emissions unit following completion of the project and the baseline actual emissions (as defined in paragraph (b)(47)(iii) of this section) of these units before the project equals or exceeds the significant amount for that pollutant (as defined in paragraph (b)(23) of this section).</P>
            <P>(<E T="03">e</E>) <E T="03">Emission test for projects that involve Clean Units.</E> For a project that will be constructed and operated at a Clean Unit without causing the emissions unit to lose its Clean Unit designation, no emissions increase is deemed to occur.</P>
            <P>(<E T="03">f</E>) <E T="03">Hybrid test for projects that involve multiple types of emissions units.</E> A significant emissions increase of a regulated NSR pollutant is projected to occur if the sum of the emissions increases for each emissions unit, using the method specified in paragraphs (a)(7)(iv)(<E T="03">c</E>) through (<E T="03">e</E>) of this section as applicable with respect to each emissions unit, for each type of emissions unit equals or exceeds the significant amount for that pollutant (as defined in paragraph (b)(23) of this section). For example, if a project involves both an existing emissions unit and a Clean Unit, the projected increase is determined by summing the values determined using the method specified in paragraph (a)(7)(iv)(<E T="03">c</E>) of this section for the existing unit and determined using the method specified in paragraph (a)(7)(iv)(<E T="03">e</E>) of this section for the Clean Unit.</P>
            <P>(v) The plan shall require that for any major stationary source for a PAL for a regulated NSR pollutant, the major stationary source shall comply with requirements under paragraph (w) of this section.</P>
            <P>(vi) The plan shall require that an owner or operator undertaking a PCP (as defined in paragraph (b)(31) of this section) shall comply with the requirements under paragraph (v) of this section.</P>
            <P>(b) <E T="03">Definitions.</E> All State plans shall use the following definitions for the purposes of this section. Deviations from the following wording will be approved only if the State specifically demonstrates that the submitted definition is more stringent, or at least as stringent, in all respects as the corresponding definitions below:</P>
            <P>(1)(i) <E T="03">Major stationary source</E> means:</P>
            <P>(<E T="03">a</E>) Any of the following stationary sources of air pollutants which emits, or has the potential to emit, 100 tons per year or more of any a regulated NSR pollutant: Fossil fuel-fired steam electric plants of more than 250 million British thermal units per hour heat input, coal cleaning plants (with thermal dryers), kraft pulp mills, portland cement plants, primary zinc smelters, iron and steel mill plants, primary aluminum ore reduction plants, primary copper smelters, municipal incinerators capable of charging more than 250 tons of refuse per day, hydrofluoric, sulfuric, and nitric acid plants, petroleum refineries, lime plants, phosphate rock processing plants, coke oven batteries, sulfur recovery plants, carbon black plants (furnace process), primary lead smelters, fuel conversion plants, sintering plants, secondary metal production plants, chemical process plants, fossil fuel boilers (or combinations thereof) totaling more than 250 million British thermal units per hour heat input, petroleum storage and transfer units with a total storage capacity exceeding 300,000 barrels, taconite ore processing plants, glass fiber processing plants, and charcoal production plants;</P>
            <P>(<E T="03">b</E>) Notwithstanding the stationary source size specified in paragraph (b)(1)(i)(<E T="03">a</E>) of this section, any stationary source which emits, or has the potential to emit, 250 tons per year or more of a regulated NSR pollutant; or</P>
            <P>(<E T="03">c</E>) Any physical change that would occur at a stationary source not otherwise qualifying under paragraph (b)(1) of this section, as a major stationary <PRTPAGE P="228"/>source if the change would constitute a major stationary source by itself.</P>

            <P>(ii) A major source that is major for volatile organic compounds or NO<E T="52">X</E> shall be considered major for ozone.</P>
            <P>(iii) The fugitive emissions of a stationary source shall not be included in determining for any of the purposes of this section whether it is a major stationary source, unless the source belongs to one of the following categories of stationary sources:</P>
            <P>(<E T="03">a</E>) Coal cleaning plants (with thermal dryers);</P>
            <P>(<E T="03">b</E>) Kraft pulp mills;</P>
            <P>(<E T="03">c</E>) Portland cement plants;</P>
            <P>(<E T="03">d</E>) Primary zinc smelters;</P>
            <P>(<E T="03">e</E>) Iron and steel mills;</P>
            <P>(<E T="03">f</E>) Primary aluminum ore reduction plants;</P>
            <P>(<E T="03">g</E>) Primary copper smelters;</P>
            <P>(<E T="03">h</E>) Municipal incinerators capable of charging more than 250 tons of refuse per day;</P>
            <P>(<E T="03">i</E>) Hydrofluoric, sulfuric, or nitric acid plants;</P>
            <P>(<E T="03">j</E>) Petroleum refineries;</P>
            <P>(<E T="03">k</E>) Lime plants;</P>
            <P>(<E T="03">l</E>) Phosphate rock processing plants;</P>
            <P>(<E T="03">m</E>) Coke oven batteries;</P>
            <P>(<E T="03">n</E>) Sulfur recovery plants;</P>
            <P>(<E T="03">o</E>) Carbon black plants (furnace process);</P>
            <P>(<E T="03">p</E>) Primary lead smelters;</P>
            <P>(<E T="03">q</E>) Fuel conversion plants;</P>
            <P>(<E T="03">r</E>) Sintering plants;</P>
            <P>(<E T="03">s</E>) Secondary metal production plants;</P>
            <P>(<E T="03">t</E>) Chemical process plants;</P>
            <P>(<E T="03">u</E>) Fossil-fuel boilers (or combination thereof) totaling more than 250 million British thermal units per hour heat input;</P>
            <P>(<E T="03">v</E>) Petroleum storage and transfer units with a total storage capacity exceeding 300,000 barrels;</P>
            <P>(<E T="03">w</E>) Taconite ore processing plants;</P>
            <P>(<E T="03">x</E>) Glass fiber processing plants;</P>
            <P>(<E T="03">y</E>) Charcoal production plants;</P>
            <P>(<E T="03">z</E>) Fossil fuel-fired steam electric plants of more that 250 million British thermal units per hour heat input;</P>
            <P>(<E T="03">aa</E>) Any other stationary source category which, as of August 7, 1980, is being regulated under section 111 or 112 of the Act.</P>
            <P>(2)(i) <E T="03">Major modification</E> means any physical change in or change in the method of operation of a major stationary source that would result in: a significant emissions increase (as defined in paragraph (b)(39) of this section) of a regulated NSR pollutant (as defined in paragraph (b)(49) of this section); and a significant net emissions increase of that pollutant from the major stationary source.</P>

            <P>(ii) Any significant emissions increase (as defined at paragraph (b)(39) of this section) from any emissions units or net emissions increase (as defined in paragraph (b)(3) of this section) at a major stationary source that is significant for volatile organic compounds or NO<E T="52">X</E> shall be considered significant for ozone.</P>
            <P>(iii) A physical change or change in the method of operation shall not include:</P>
            <P>(<E T="03">a</E>) Routine maintenance, repair and replacement. Routine maintenance, repair and replacement shall include, but not be limited to, any activity(s) that meets the requirements of the equipment replacement provisions contained in paragraph (y) of this section;</P>
            <NOTE>
              <HD SOURCE="HED">Note to paragraph (b)(2)(iii)(<E T="03">a</E>):</HD>

              <P>On December 24, 2003, the second sentence of this paragraph (b)(2)(iii)(<E T="03">a</E>) is stayed indefinitely by court order. The stayed provisions will become effective immediately if the court terminates the stay. At that time, EPA will publish a document in the <E T="04">Federal Register</E> advising the public of the termination of the stay.</P>
            </NOTE>
            <P>(<E T="03">b</E>) Use of an alternative fuel or raw material by reason of any order under section 2 (a) and (b) of the Energy Supply and Environmental Coordination Act of 1974 (or any superseding legislation) or by reason of a natural gas curtailment plan pursuant to the Federal Power Act;</P>
            <P>(<E T="03">c</E>) Use of an alternative fuel by reason of an order or rule under section 125 of the Act;</P>
            <P>(<E T="03">d</E>) Use of an alternative fuel at a steam generating unit to the extent that the fuel is generated from municipal solid waste;</P>
            <P>(<E T="03">e</E>) Use of an alternative fuel or raw material by a stationary source which:</P>
            <P>(<E T="03">1</E>) The source was capable of accommodating before January 6, 1975, unless such change would be prohibited under any federally enforceable permit condition which was established after January 6, 1975 pursuant to 40 CFR 52.21 or <PRTPAGE P="229"/>under regulations approved pursuant to 40 CFR subpart I or § 51.166; or</P>
            <P>(<E T="03">2</E>) The source is approved to use under any permit issued under 40 CFR 52.21 or under regulations approved pursuant to 40 CFR 51.166;</P>
            <P>(<E T="03">f</E>) An increase in the hours of operation or in the production rate, unless such change would be prohibited under any federally enforceable permit condition which was established after January 6, 1975, pursuant to 40 CFR 52.21 or under regulations approved pursuant to 40 CFR subpart I or § 51.166.</P>
            <P>(<E T="03">g</E>) Any change in ownership at a stationary source.</P>
            <P>(<E T="03">h</E>) The addition, replacement, or use of a PCP, as defined in paragraph (b)(31) of this section, at an existing emissions unit meeting the requirements of paragraph (v) of this section. A replacement control technology must provide more effective emission control than that of the replaced control technology to qualify for this exclusion.</P>
            <P>(<E T="03">i</E>) The installation, operation, cessation, or removal of a temporary clean coal technology demonstration project, provided that the project complies with:</P>
            <P>(<E T="03">1</E>) The State implementation plan for the State in which the project is located; and</P>
            <P>(<E T="03">2</E>) Other requirements necessary to attain and maintain the national ambient air quality standards during the project and after it is terminated.</P>
            <P>(<E T="03">j</E>) The installation or operation of a permanent clean coal technology demonstration project that constitutes repowering, provided that the project does not result in an increase in the potential to emit of any regulated pollutant emitted by the unit. This exemption shall apply on a pollutant-by-pollutant basis.</P>
            <P>(<E T="03">k</E>) The reactivation of a very clean coal-fired electric utility steam generating unit.</P>
            <P>(iv) This definition shall not apply with respect to a particular regulated NSR pollutant when the major stationary source is complying with the requirements under paragraph (w) of this section for a PAL for that pollutant. Instead, the definition at paragraph (w)(2)(viii) of this section shall apply.</P>
            <P>(3)(i) <E T="03">Net emissions increase</E> means, with respect to any regulated NSR pollutant emitted by a major stationary source, the amount by which the sum of the following exceeds zero:</P>
            <P>(<E T="03">a</E>) The increase in emissions from a particular physical change or change in the method of operation at a stationary source as calculated pursuant to paragraph (a)(7)(iv) of this section; and</P>
            <P>(<E T="03">b</E>) Any other increases and decreases in actual emissions at the major stationary source that are contemporaneous with the particular change and are otherwise creditable. Baseline actual emissions for calculating increases and decreases under this paragraph (b)(3)(i)(<E T="03">b</E>) shall be determined as provided in paragraph (b)(47), except that paragraphs (b)(47)(i)(<E T="03">c</E>) and (b)(47)(ii)(<E T="03">d</E>) of this section shall not apply.</P>
            <P>(ii) An increase or decrease in actual emissions is contemporaneous with the increase from the particular change only if it occurs within a reasonable period (to be specified by the State) before the date that the increase from the particular change occurs.</P>
            <P>(iii) An increase or decrease in actual emissions is creditable only if:</P>
            <P>(<E T="03">a</E>) It occurs within a reasonable period (to be specified by the reviewing authority); and</P>
            <P>(<E T="03">b</E>) The reviewing authority has not relied on it in issuing a permit for the source under regulations approved pursuant to this section, which permit is in effect when the increase in actual emissions from the particular change occurs; and</P>
            <P>(<E T="03">c</E>) The increase or decrease in emissions did not occur at a Clean Unit, except as provided in paragraphs (t)(8) and (u)(10) of this section.</P>
            <P>(iv) An increase or decrease in actual emissions of sulfur dioxide, particulate matter, or nitrogen oxides that occurs before the applicable minor source baseline date is creditable only if it is required to be considered in calculating the amount of maximum allowable increases remaining available.</P>

            <P>(v) An increase in actual emissions is creditable only to the extent that the new level of actual emissions exceeds the old level.<PRTPAGE P="230"/>
            </P>
            <P>(vi) A decrease in actual emissions is creditable only to the extent that:</P>
            <P>(<E T="03">a</E>) The old level of actual emissions or the old level of allowable emissions, whichever is lower, exceeds the new level of actual emissions;</P>
            <P>(<E T="03">b</E>) It is enforceable as a practical matter at and after the time that actual construction on the particular change begins;</P>
            <P>(<E T="03">c</E>) It has approximately the same qualitative significance for public health and welfare as that attributed to the increase from the particular change; and</P>
            <P>(<E T="03">d</E>) The decrease in actual emissions did not result from the installation of add-on control technology or application of pollution prevention practices that were relied on in designating an emissions unit as a Clean Unit under § 52.21(y) or under regulations approved pursuant to paragraph (u) of this section or § 51.165(d). That is, once an emissions unit has been designated as a Clean Unit, the owner or operator cannot later use the emissions reduction from the air pollution control measures that the Clean Unit designation is based on in calculating the net emissions increase for another emissions unit (<E T="03">i.e.,</E> must not use that reduction in a “netting analysis” for another emissions unit). However, any new emissions reductions that were not relied upon in a PCP excluded pursuant to paragraph (v) of this section or for the Clean Unit designation are creditable to the extent they meet the requirements in paragraph (v)(6)(iv) of this section for the PCP and paragraph (t)(8) or (u)(10) of this section for a Clean Unit.</P>
            <P>(vii) An increase that results from a physical change at a source occurs when the emissions unit on which construction occurred becomes operational and begins to emit a particular pollutant. Any replacement unit that requires shakedown becomes operational only after a reasonable shakedown period, not to exceed 180 days.</P>
            <P>(viii) Paragraph (b)(21)(ii) of this section shall not apply for determining creditable increases and decreases.</P>
            <P>(4) <E T="03">Potential to emit</E> means the maximum capacity of a stationary source to emit a pollutant under its physical and operational design. Any physical or operational limitation on the capacity of the source to emit a pollutant, including air pollution control equipment and restrictions on hours of operation or on the type or amount of material combusted, stored, or processed, shall be treated as part of its design if the limitation or the effect it would have on emissions is federally enforceable. Secondary emissions do not count in determining the potential to emit of a stationary source.</P>
            <P>(5) <E T="03">Stationary source</E> means any building, structure, facility, or installation which emits or may emit a regulated NSR pollutant.</P>
            <P>(6) <E T="03">Building, structure, facility, or installation</E> means all of the pollutant-emitting activities which belong to the same industrial grouping, are located on one or more contiguous or adjacent properties, and are under the control of the same person (or persons under common control) except the activities of any vessel. Pollutant-emitting activities shall be considered as part of the same industrial grouping if they belong to the same <E T="03">Major Group</E> (i.e., which have the same two-digit code) as described in the <E T="03">Standard Industrial Classification Manual, 1972,</E> as amended by the 1977 Supplement (U.S. Government Printing Office stock numbers 4101-0066 and 003-005-00176-0, respectively).</P>
            <P>(7) <E T="03">Emissions unit</E> means any part of a stationary source that emits or would have the potential to emit any regulated NSR pollutant and includes an electric utility steam generating unit as defined in paragraph (b)(30) of this section. For purposes of this section, there are two types of emissions units as described in paragraphs (b)(7)(i) and (ii) of this section.</P>
            <P>(i) A new emissions unit is any emissions unit that is (or will be) newly constructed and that has existed for less than 2 years from the date such emissions unit first operated.</P>

            <P>(ii) An existing emissions unit is any emissions unit that does not meet the requirements in paragraph (b)(7)(i) of this section. A replacement unit, as defined in paragraph (b)(32) of this section, is an existing emissions unit.<PRTPAGE P="231"/>
            </P>
            <P>(8) <E T="03">Construction</E> means any physical change or change in the method of operation (including fabrication, erection, installation, demolition, or modification of an emissions unit) that would result in a change in emissions.</P>
            <P>(9) <E T="03">Commence</E> as applied to construction of a major stationary source or major modification means that the owner or operator has all necessary preconstruction approvals or permits and either has:</P>
            <P>(i) Begun, or caused to begin, a continuous program of actual on-site construction of the source, to be completed within a reasonable time; or</P>
            <P>(ii) Entered into binding agreements or contractual obligations, which cannot be cancelled or modified without substantial loss to the owner or operator, to undertake a program of actual construction of the source to be completed within a reasonable time.</P>
            <P>(10) <E T="03">Necessary preconstruction approvals or permits</E> means those permits or approvals required under Federal air quality control laws and regulations and those air quality control laws and regulations which are part of the applicable State Implementation Plan.</P>
            <P>(11) <E T="03">Begin actual construction</E> means, in general, initiation of physical on-site construction activities on an emissions unit which are of a permanent nature. Such activities include, but are not limited to, installation of building supports and foundations, laying of underground pipework, and construction of permanent storage structures. With respect to a change in method of operation this term refers to those on-site activities, other than preparatory activities, which mark the initiation of the change.</P>
            <P>(12) <E T="03">Best available control technology</E> means an emissions limitation (including a visible emissions standard) based on the maximum degree of reduction for each a regulated NSR pollutant which would be emitted from any proposed major stationary source or major modification which the reviewing authority, on a case-by-case basis, taking into account energy, environmental, and economic impacts and other costs, determines is achievable for such source or modification through application of production processes or available methods, systems, and techniques, including fuel cleaning or treatment or innovative fuel combination techniques for control of such pollutant. In no event shall application of best available control technology result in emissions of any pollutant which would exceed the emissions allowed by any applicable standard under 40 CFR parts 60 and 61. If the reviewing authority determines that technological or economic limitations on the application of measurement methodology to a particular emissions unit would make the imposition of an emissions standard infeasible, a design, equipment, work practice, operational standard or combination thereof, may be prescribed instead to satisfy the requirement for the application of best available control technology. Such standard shall, to the degree possible, set forth the emissions reduction achievable by implementation of such design, equipment, work practice or operation, and shall provide for compliance by means which achieve equivalent results.</P>
            <P>(13)(i) <E T="03">Baseline concentration</E> means that ambient concentration level that exists in the baseline area at the time of the applicable minor source baseline date. A baseline concentration is determined for each pollutant for which a minor source baseline date is established and shall include:</P>
            <P>(<E T="03">a</E>) The actual emissions, as defined in paragraph (b)(21) of this section, representative of sources in existence on the applicable minor source baseline date, except as provided in paragraph (b)(13)(ii) of this section;</P>
            <P>(<E T="03">b</E>) The allowable emissions of major stationary sources that commenced construction before the major source baseline date, but were not in operation by the applicable minor source baseline date.</P>
            <P>(ii) The following will not be included in the baseline concentration and will affect the applicable maximum allowable increase(s):</P>
            <P>(<E T="03">a</E>) Actual emissions, as defined in paragraph (b)(21) of this section, from any major stationary source on which construction commenced after the major source baseline date; and</P>
            <P>(<E T="03">b</E>) Actual emissions increases and decreases, as defined in paragraph <PRTPAGE P="232"/>(b)(21) of this section, at any stationary source occurring after the minor source baseline date.</P>
            <P>(14)(i) <E T="03">Major source baseline date</E> means:</P>
            <P>(<E T="03">a</E>) In the case of particulate matter and sulfur dioxide, January 6, 1975, and</P>
            <P>(<E T="03">b</E>) In the case of nitrogen dioxide, February 8, 1988.</P>
            <P>(ii) <E T="03">Minor source baseline date</E> means the earliest date after the trigger date on which a major stationary source or a major modification subject to 40 CFR 52.21 or to regulations approved pursuant to 40 CFR 51.166 submits a complete application under the relevant regulations. The trigger date is:</P>
            <P>(<E T="03">a</E>) In the case of particulate matter and sulfur dioxide, August 7, 1977, and</P>
            <P>(<E T="03">b</E>) In the case of nitrogen dioxide, February 8, 1988.</P>
            <P>(iii) The baseline date is established for each pollutant for which increments or other equivalent measures have been established if:</P>
            <P>(<E T="03">a</E>) The area in which the proposed source or modification would construct is designated as attainment or unclassifiable under section 107(d)(i) (D) or (E) of the Act for the pollutant on the date of its complete application under 40 CFR 52.21 or under regulations approved pursuant to 40 CFR 51.166; and</P>
            <P>(<E T="03">b</E>) In the case of a major stationary source, the pollutant would be emitted in significant amounts, or, in the case of a major modification, there would be a significant net emissions increase of the pollutant.</P>
            <P>(iv) Any minor source baseline date established originally for the TSP increments shall remain in effect and shall apply for purposes of determining the amount of available PM-10 increments, except that the reviewing authority may rescind any such minor source baseline date where it can be shown, to the satisfaction of the reviewing authority, that the emissions increase from the major stationary source, or the net emissions increase from the major modification, responsible for triggering that date did not result in a significant amount of PM-10 emissions.</P>
            <P>(15)(i) <E T="03">Baseline area</E> means any intrastate area (and every part thereof) designated as attainment or unclassifiable under section 107(d)(1) (D) or (E) of the Act in which the major source or major modification establishing the minor source baseline date would construct or would have an air quality impact equal to or greater than 1 µg/m<SU>3</SU> (annual average) of the pollutant for which the minor source baseline date is established.</P>
            <P>(ii) Area redesignations under section 107(d)(1) (D) or (E) of the Act cannot intersect or be smaller than the area of impact of any major stationary source or major modification which:</P>
            <P>(<E T="03">a</E>) Establishes a minor source baseline date; or</P>
            <P>(<E T="03">b</E>) Is subject to 40 CFR 52.21 or under regulations approved pursuant to 40 CFR 51.166, and would be constructed in the same State as the State proposing the redesignation.</P>
            <P>(iii) Any baseline area established originally for the TSP increments shall remain in effect and shall apply for purposes of determining the amount of available PM-10 increments, except that such baseline area shall not remain in effect if the permit authority rescinds the corresponding minor source baseline date in accordance with paragraph (b)(14)(iv) of this section.</P>
            <P>(16) <E T="03">Allowable emissions</E> means the emissions rate of a stationary source calculated using the maximum rated capacity of the source (unless the source is subject to federally enforceable limits which restrict the operating rate, or hours of operation, or both) and the most stringent of the following:</P>
            <P>(i) The applicable standards as set forth in 40 CFR parts 60 and 61;</P>
            <P>(ii) The applicable State Implementation Plan emissions limitation, including those with a future compliance date; or</P>
            <P>(iii) The emissions rate specified as a federally enforceable permit condition.</P>
            <P>(17) <E T="03">Federally enforceable</E> means all limitations and conditions which are enforceable by the Administrator, including those requirements developed pursuant to 40 CFR parts 60 and 61, requirements within any applicable State implementation plan, any permit requirements established pursuant to 40 CFR 52.21 or under regulations approved pursuant to 40 CFR part 51, subpart I, including operating permits issued under an EPA-approved program <PRTPAGE P="233"/>that is incorporated into the State implementation plan and expressly requires adherence to any permit issued under such program.</P>
            <P>(18) <E T="03">Secondary emissions</E> means emissions which occur as a result of the construction or operation of a major stationary source or major modification, but do not come from the major stationary source or major modification itself. For the purposes of this section, secondary emissions must be specific, well defined, quantifiable, and impact the same general areas the stationary source modification which causes the secondary emissions. Secondary emissions include emissions from any offsite support facility which would not be constructed or increase its emissions except as a result of the construction or operation of the major stationary source or major modification. Secondary emissions do not include any emissions which come directly from a mobile source, such as emissions from the tailpipe of a motor vehicle, from a train, or from a vessel.</P>
            <P>(19) <E T="03">Innovative control technology</E> means any system of air pollution control that has not been adequately demonstrated in practice, but would have a substantial likelihood of achieving greater continuous emissions reduction than any control system in current practice or of achieving at least comparable reductions at lower cost in terms of energy, economics, or nonair quality environmental impacts.</P>
            <P>(20) <E T="03">Fugitive emissions</E> means those emissions which could not reasonably pass through a stack, chimney, vent, or other functionally equivalent opening.</P>
            <P>(21)(i) <E T="03">Actual emissions</E> means the actual rate of emissions of a regulated NSR pollutant from an emissions unit, as determined in accordance with paragraphs (b)(21)(ii) through (iv) of this section, except that this definition shall not apply for calculating whether a significant emissions increase has occurred, or for establishing a PAL under paragraph (w) of this section. Instead, paragraphs (b)(40) and (b)(47) of this section shall apply for those purposes.</P>
            <P>(ii) In general, actual emissions as of a particular date shall equal the average rate, in tons per year, at which the unit actually emitted the pollutant during a consecutive 24-month period which precedes the particular date and which is representative of normal source operation. The reviewing authority shall allow the use of a different time period upon a determination that it is more representative of normal source operation. Actual emissions shall be calculated using the unit's actual operating hours, production rates, and types of materials processed, stored, or combusted during the selected time period.</P>
            <P>(iii) The reviewing authority may presume that source-specific allowable emissions for the unit are equivalent to the actual emissions of the unit.</P>
            <P>(iv) For any emissions unit that has not begun normal operations on the particular date, actual emissions shall equal the potential to emit of the unit on that date.</P>
            <P>(22) <E T="03">Complete</E> means, in reference to an application for a permit, that the application contains all the information necessary for processing the application. Designating an application complete for purposes of permit processing does not preclude the reviewing authority from requesting or accepting any additional information.</P>
            <P>(23)(i) <E T="03">Significant</E> means, in reference to a net emissions increase or the potential of a source to emit any of the following pollutants, a rate of emissions that would equal or exceed any of the following rates:</P>
            <EXTRACT>
              <HD SOURCE="HD1">Pollutant and Emissions Rate</HD>
              <FP SOURCE="FP-1">Carbon monoxide: 100 tons per year (tpy)</FP>
              <FP SOURCE="FP-1">Nitrogen oxides: 40 tpy</FP>
              <FP SOURCE="FP-1">Sulfur dioxide: 40 tpy</FP>

              <FP SOURCE="FP-1">Particulate matter: 25 tpy of particulate matter emissions. 15 tpy of PM<E T="52">10</E> emissions.</FP>
              <FP SOURCE="FP-1">Ozone: 40 tpy of volatile organic compounds or NO<E T="52">X</E>
              </FP>
              <FP SOURCE="FP-1">Lead: 0.6 tpy</FP>
              <FP SOURCE="FP-1">Fluorides: 3 tpy</FP>
              <FP SOURCE="FP-1">Sulfuric acid mist: 7 tpy</FP>
              <FP SOURCE="FP-1">Hydrogen sulfide (H<E T="52">2</E> S): 10 tpy</FP>
              <FP SOURCE="FP-1">Total reduced sulfur (including H<E T="52">2</E> S): 10 tpy</FP>
              <FP SOURCE="FP-1">Reduced sulfur compounds (including H<E T="52">2</E> S): 10 tpy</FP>

              <FP SOURCE="FP-1">Municipal waste combustor organics (measured as total tetra- through octa-chlorinated dibenzo-p-dioxins and dibenzofurans): 3.2 × 10<E T="51">−6</E> megagrams per year (3.5 × 10<E T="51">−6</E> tons per year)</FP>

              <FP SOURCE="FP-1">Municipal waste combustor metals (measured as articulate matter): 14 megagrams per year (15 tons per year) Municipal waste combustor acid gases (measured as sulfur <PRTPAGE P="234"/>dioxide and hydrogen chloride): 36 megagrams per year (40 tons per year)</FP>
              <FP SOURCE="FP-1">Municipal solid waste landfill emissions (measured as nonmethane organic compounds): 45 megagrams per year (50 tons per year)</FP>
            </EXTRACT>
            
            <P>(ii) <E T="03">Significant</E> means, in reference to a net emissions increase or the potential of a source to emit a regulated NSR pollutant that paragraph (b)(23)(i) of this section, does not list, any emissions rate.</P>

            <P>(iii) Notwithstanding paragraph (b)(23)(i) of this section, <E T="03">significant</E> means any emissions rate or any net emissions increase associated with a major stationary source or major modification, which would construct within 10 kilometers of a Class I area, and have an impact on such area equal to or greater than 1 µg/m<SU>3</SU> (24-hour average).</P>
            <P>(24) <E T="03">Federal Land Manager</E> means, with respect to any lands in the United States, the Secretary of the department with authority over such lands.</P>
            <P>(25) <E T="03">High terrain</E> means any area having an elevation 900 feet or more above the base of the stack of a source.</P>
            <P>(26) <E T="03">Low terrain</E> means any area other than high terrain.</P>
            <P>(27) <E T="03">Indian Reservation</E> means any federally recognized reservation established by Treaty, Agreement, Executive Order, or Act of Congress.</P>
            <P>(28) <E T="03">Indian Governing Body</E> means the governing body of any tribe, band, or group of Indians subject to the jurisdiction of the United States and recognized by the United States as possessing power of self-government.</P>
            <P>(29) <E T="03">Volatile organic compounds (VOC)</E> is as defined in § 51.100(s) of this part.</P>
            <P>(30) <E T="03">Electric utility steam generating unit</E> means any steam electric generating unit that is constructed for the purpose of supplying more than one-third of its potential electric output capacity and more than 25 MW electrical output to any utility power distribution system for sale. Any steam supplied to a steam distribution system for the purpose of providing steam to a steam-electric generator that would produce electrical energy for sale is also considered in determining the electrical energy output capacity of the affected facility.</P>
            <P>(31) <E T="03">Pollution control project (PCP)</E> means any activity, set of work practices or project (including pollution prevention as defined under paragraph (b)(38) of this section) undertaken at an existing emissions unit that reduces emissions of air pollutants from such unit. Such qualifying activities or projects can include the replacement or upgrade of an existing emissions control technology with a more effective unit. Other changes that may occur at the source are not considered part of the PCP if they are not necessary to reduce emissions through the PCP. Projects listed in paragraphs (b)(31)(i) through (vi) of this section are presumed to be environmentally beneficial pursuant to paragraph (v)(2)(i) of this section. Projects not listed in these paragraphs may qualify for a case-specific PCP exclusion pursuant to the requirements of paragraphs (v)(2) and (v)(5) of this section.</P>

            <P>(i) Conventional or advanced flue gas desulfurization or sorbent injection for control of SO<E T="52">2</E>.</P>
            <P>(ii) Electrostatic precipitators, baghouses, high efficiency multiclones, or scrubbers for control of particulate matter or other pollutants.</P>
            <P>(iii) Flue gas recirculation, low-NO<E T="52">X</E> burners or combustors, selective non-catalytic reduction, selective catalytic reduction, low emission combustion (for IC engines), and oxidation/absorption catalyst for control of NO<E T="52">X</E>.</P>
            <P>(iv) Regenerative thermal oxidizers, catalytic oxidizers, condensers, thermal incinerators, hydrocarbon combustion flares, biofiltration, absorbers and adsorbers, and floating roofs for storage vessels for control of volatile organic compounds or hazardous air pollutants. For the purpose of this section, “hydrocarbon combustion flare” means either a flare used to comply with an applicable NSPS or MACT standard (including uses of flares during startup, shutdown, or malfunction permitted under such a standard), or a flare that serves to control emissions of waste streams comprised predominately of hydrocarbons and containing no more than 230 mg/dscm hydrogen sulfide.</P>

            <P>(v) Activities or projects undertaken to accommodate switching (or partially switching) to an inherently less polluting fuel, to be limited to the following fuel switches:<PRTPAGE P="235"/>
            </P>
            <P>(<E T="03">a</E>) Switching from a heavier grade of fuel oil to a lighter fuel oil, or any grade of oil to 0.05 percent sulfur diesel (<E T="03">i.e.,</E> from a higher sulfur content #2 fuel or from #6 fuel, to CA 0.05 percent sulfur #2 diesel);</P>
            <P>(<E T="03">b</E>) Switching from coal, oil, or any solid fuel to natural gas, propane, or gasified coal;</P>
            <P>(<E T="03">c</E>) Switching from coal to wood, excluding construction or demolition waste, chemical or pesticide treated wood, and other forms of “unclean” wood;</P>
            <P>(<E T="03">d</E>) Switching from coal to #2 fuel oil (0.5 percent maximum sulfur content); and</P>
            <P>(<E T="03">e</E>) Switching from high sulfur coal to low sulfur coal (maximum 1.2 percent sulfur content).</P>
            <P>(vi) Activities or projects undertaken to accommodate switching from the use of one ozone depleting substance (ODS) to the use of a substance with a lower or zero ozone depletion potential (ODP), including changes to equipment needed to accommodate the activity or project, that meet the requirements of paragraphs (b)(31)(vi)(a) and (b) of this section.</P>
            <P>(<E T="03">a</E>) The productive capacity of the equipment is not increased as a result of the activity or project.</P>
            <P>(<E T="03">b</E>) The projected usage of the new substance is lower, on an ODP-weighted basis, than the baseline usage of the replaced ODS. To make this determination, follow the procedure in paragraphs (b)(31)(vi)(b)(1) through (4) of this section.</P>
            <P>(<E T="03">1</E>) Determine the ODP of the substances by consulting 40 CFR part 82, subpart A, appendices A and B.</P>
            <P>(<E T="03">2</E>) Calculate the replaced ODP-weighted amount by multiplying the baseline actual usage (using the annualized average of any 24 consecutive months of usage within the past 10 years) by the ODP of the replaced ODS.</P>
            <P>(<E T="03">3</E>) Calculate the projected ODP-weighted amount by multiplying the projected annual usage of the new substance by its ODP.</P>
            <P>(<E T="03">4</E>) If the value calculated in paragraph (b)(31)(vi)(b)(2) of this section is more than the value calculated in paragraph (b)(31)(vi)(b)(3) of this section, then the projected use of the new substance is lower, on an ODP-weighted basis, than the baseline usage of the replaced ODS.</P>
            <P>(32) <E T="03">Replacement unit</E> means an emissions unit for which all the criteria listed in paragraphs (b)(32)(i) through (iv) of this section are met. No creditable emission reductions shall be generated from shutting down the existing emissions unit that is replaced.</P>
            <P>(i) The emissions unit is a reconstructed unit within the meaning of § 60.15(b)(1) of this chapter, or the emissions unit completely takes the place of an existing emissions unit.</P>
            <P>(ii) The emissions unit is identical to or functionally equivalent to the replaced emissions unit.</P>
            <P>(iii) The replacement does not change the basic design parameter(s) (as discussed in paragraph (y)(2) of this section) of the process unit.</P>
            <P>(iv) The replaced emissions unit is permanently removed from the major stationary source, otherwise permanently disabled, or permanently barred from operation by a permit that is enforceable as a practical matter. If the replaced emissions unit is brought back into operation, it shall constitute a new emissions unit.</P>
            <P>(33) <E T="03">Clean coal technology</E> means any technology, including technologies applied at the precombustion, combustion, or post combustion stage, at a new or existing facility which will achieve significant reductions in air emissions of sulfur dioxide or oxides of nitrogen associated with the utilization of coal in the generation of electricity, or process steam which was not in widespread use as of November 15, 1990.</P>
            <P>(34) <E T="03">Clean coal technology demonstration project</E> means a project using funds appropriated under the heading “Department of Energy—Clean Coal Technology”, up to a total amount of $2,500,000,000 for commercial demonstration of clean coal technology, or similar projects funded through appropriations for the Environmental Protection Agency. The Federal contribution for a qualifying project shall be at least 20 percent of the total cost of the demonstration project.</P>
            <P>(35) <E T="03">Temporary clean coal technology demonstration project</E> means a clean coal technology demonstration project that is operated for a period of 5 years <PRTPAGE P="236"/>or less, and which complies with the State implementation plan for the State in which the project is located and other requirements necessary to attain and maintain the national ambient air quality standards during and after the project is terminated.</P>
            <P>(36)(i) <E T="03">Repowering</E> means replacement of an existing coal-fired boiler with one of the following clean coal technologies: atmospheric or pressurized fluidized bed combustion, integrated gasification combined cycle, magnetohydrodynamics, direct and indirect coal-fired turbines, integrated gasification fuel cells, or as determined by the Administrator, in consultation with the Secretary of Energy, a derivative of one or more of these technologies, and any other technology capable of controlling multiple combustion emissions simultaneously with improved boiler or generation efficiency and with significantly greater waste reduction relative to the performance of technology in widespread commercial use as of November 15, 1990.</P>
            <P>(ii) Repowering shall also include any oil and/or gas-fired unit which has been awarded clean coal technology demonstration funding as of January 1, 1991, by the Department of Energy.</P>
            <P>(iii) The reviewing authority shall give expedited consideration to permit applications for any source that satisfies the requirements of this subsection and is granted an extension under section 409 of the Clean Air Act.</P>
            <P>(37) <E T="03">Reactivation of a very clean coal-fired electric utility steam generating unit</E> means any physical change or change in the method of operation associated with the commencement of commercial operations by a coal-fired utility unit after a period of discontinued operation where the unit:</P>
            <P>(i) Has not been in operation for the two-year period prior to the enactment of the Clean Air Act Amendments of 1990, and the emissions from such unit continue to be carried in the permitting authority's emissions inventory at the time of enactment;</P>
            <P>(ii) Was equipped prior to shutdown with a continuous system of emissions control that achieves a removal efficiency for sulfur dioxide of no less than 85 percent and a removal efficiency for particulates of no less than 98 percent;</P>
            <P>(iii) Is equipped with low-NO<E T="52">X</E> burners prior to the time of commencement of operations following reactivation; and</P>
            <P>(iv) Is otherwise in compliance with the requirements of the Clean Air Act.</P>
            <P>(38) <E T="03">Pollution prevention</E> means any activity that through process changes, product reformulation or redesign, or substitution of less polluting raw materials, eliminates or reduces the release of air pollutants (including fugitive emissions) and other pollutants to the environment prior to recycling, treatment, or disposal; it does not mean recycling (other than certain “in-process recycling” practices), energy recovery, treatment, or disposal.</P>
            <P>(39) <E T="03">Significant emissions increase</E> means, for a regulated NSR pollutant, an increase in emissions that is significant (as defined in paragraph (b)(23) of this section) for that pollutant.</P>
            <P>(40)(i) <E T="03">Projected actual emissions</E> means the maximum annual rate, in tons per year, at which an existing emissions unit is projected to emit a regulated NSR pollutant in any one of the 5 years (12-month period) following the date the unit resumes regular operation after the project, or in any one of the 10 years following that date, if the project involves increasing the emissions unit's design capacity or its potential to emit that regulated NSR pollutant, and full utilization of the unit would result in a significant emissions increase, or a significant net emissions increase at the major stationary source.</P>
            <P>(ii) In determining the projected actual emissions under paragraph (b)(40)(i) of this section (before beginning actual construction), the owner or operator of the major stationary source:</P>
            <P>(<E T="03">a</E>) Shall consider all relevant information, including but not limited to, historical operational data, the company's own representations, the company's expected business activity and the company's highest projections of business activity, the company's filings with the State or Federal regulatory authorities, and compliance plans under the approved plan; and<PRTPAGE P="237"/>
            </P>
            <P>(<E T="03">b</E>) Shall include fugitive emissions to the extent quantifiable and emissions associated with startups, shutdowns, and malfunctions; and</P>
            <P>(<E T="03">c</E>) Shall exclude, in calculating any increase in emissions that results from the particular project, that portion of the unit's emissions following the project that an existing unit could have accommodated during the consecutive 24-month period used to establish the baseline actual emissions under paragraph (b)(47) of this section and that are also unrelated to the particular project, including any increased utilization due to product demand growth; or,</P>
            <P>(<E T="03">d</E>) In lieu of using the method set out in paragraphs (b)(40)(ii)(<E T="03">a</E>) through (<E T="03">c</E>) of this section, may elect to use the emissions unit's potential to emit, in tons per year, as defined under paragraph (b)(4) of this section.</P>
            <P>(41) <E T="03">Clean Unit</E> means any emissions unit that has been issued a major NSR permit that requires compliance with BACT or LAER, is complying with such BACT/LAER requirements, and qualifies as a Clean Unit pursuant to regulations approved by the Administrator in accordance with paragraph (t) of this section; or any emissions unit that has been designated by a reviewing authority as a Clean Unit, based on the criteria in paragraphs (u)(3)(i) through (iv) of this section, using a plan-approved permitting process; or any emissions unit that has been designated as a Clean Unit by the Administrator in accordance with 52.21 (y)(3)(i) through (iv) of this chapter.</P>
            <P>(42) <E T="03">Prevention of Significant Deterioration Program (PSD) program</E> means a major source preconstruction permit program that has been approved by the Administrator and incorporated into the plan to implement the requirements of this section, or the program in § 52.21 of this chapter. Any permit issued under such a program is a major NSR permit.</P>
            <P>(43) <E T="03">Continuous emissions monitoring system (CEMS)</E> means all of the equipment that may be required to meet the data acquisition and availability requirements of this section, to sample, condition (if applicable), analyze, and provide a record of emissions on a continuous basis.</P>
            <P>(44) <E T="03">Predictive emissions monitoring system (PEMS)</E> means all of the equipment necessary to monitor process and control device operational parameters (for example, control device secondary voltages and electric currents) and other information (for example, gas flow rate, O<SU>2</SU> or CO<SU>2</SU> concentrations), and calculate and record the mass emissions rate (for example, lb/hr) on a continuous basis.</P>
            <P>(45) <E T="03">Continuous parameter monitoring system (CPMS)</E> means all of the equipment necessary to meet the data acquisition and availability requirements of this section, to monitor process and control device operational parameters (for example, control device secondary voltages and electric currents) and other information (for example, gas flow rate, O<SU>2</SU> or CO<SU>2</SU> concentrations), and to record average operational parameter value(s) on a continuous basis.</P>
            <P>(46) <E T="03">Continuous emissions rate monitoring system (CERMS)</E> means the total equipment required for the determination and recording of the pollutant mass emissions rate (in terms of mass per unit of time).</P>
            <P>(47) <E T="03">Baseline actual emissions</E> means the rate of emissions, in tons per year, of a regulated NSR pollutant, as determined in accordance with paragraphs (b)(47)(i) through (iv) of this section.</P>
            <P>(i) For any existing electric utility steam generating unit, baseline actual emissions means the average rate, in tons per year, at which the unit actually emitted the pollutant during any consecutive 24-month period selected by the owner or operator within the 5-year period immediately preceding when the owner or operator begins actual construction of the project. The reviewing authority shall allow the use of a different time period upon a determination that it is more representative of normal source operation.</P>
            <P>(<E T="03">a</E>) The average rate shall include fugitive emissions to the extent quantifiable, and emissions associated with startups, shutdowns, and malfunctions.</P>
            <P>(<E T="03">b</E>) The average rate shall be adjusted downward to exclude any non-compliant emissions that occurred while the source was operating above an emission limitation that was legally enforceable during the consecutive 24-month period.<PRTPAGE P="238"/>
            </P>
            <P>(<E T="03">c</E>) For a regulated NSR pollutant, when a project involves multiple emissions units, only one consecutive 24-month period must be used to determine the baseline actual emissions for the emissions units being changed. A different consecutive 24-month period can be used For each regulated NSR pollutant.</P>
            <P>(<E T="03">d</E>) The average rate shall not be based on any consecutive 24-month period for which there is inadequate information for determining annual emissions, in tons per year, and for adjusting this amount if required by paragraph (b)(47)(i)(<E T="03">b</E>) of this section.</P>
            <P>(ii) For an existing emissions unit (other than an electric utility steam generating unit), baseline actual emissions means the average rate, in tons per year, at which the emissions unit actually emitted the pollutant during any consecutive 24-month period selected by the owner or operator within the 10-year period immediately preceding either the date the owner or operator begins actual construction of the project, or the date a complete permit application is received by the reviewing authority for a permit required either under this section or under a plan approved by the Administrator, whichever is earlier, except that the 10-year period shall not include any period earlier than November 15, 1990.</P>
            <P>(<E T="03">a</E>) The average rate shall include fugitive emissions to the extent quantifiable, and emissions associated with startups, shutdowns, and malfunctions.</P>
            <P>(<E T="03">b</E>) The average rate shall be adjusted downward to exclude any non-compliant emissions that occurred while the source was operating above an emission limitation that was legally enforceable during the consecutive 24-month period.</P>
            <P>(<E T="03">c</E>) The average rate shall be adjusted downward to exclude any emissions that would have exceeded an emission limitation with which the major stationary source must currently comply, had such major stationary source been required to comply with such limitations during the consecutive 24-month period. However, if an emission limitation is part of a maximum achievable control technology standard that the Administrator proposed or promulgated under part 63 of this chapter, the baseline actual emissions need only be adjusted if the State has taken credit for such emissions reductions in an attainment demonstration or maintenance plan consistent with the requirements of § 51.165(a)(3)(ii)(G).</P>
            <P>(<E T="03">d</E>) For a regulated NSR pollutant, when a project involves multiple emissions units, only one consecutive 24-month period must be used to determine the baseline actual emissions for the emissions units being changed. A different consecutive 24-month period can be used For each regulated NSR pollutant.</P>
            <P>(<E T="03">e</E>) The average rate shall not be based on any consecutive 24-month period for which there is inadequate information for determining annual emissions, in tons per year, and for adjusting this amount if required by paragraphs (b)(47)(ii)(b) and (c) of this section.</P>
            <P>(iii) For a new emissions unit, the baseline actual emissions for purposes of determining the emissions increase that will result from the initial construction and operation of such unit shall equal zero; and thereafter, for all other purposes, shall equal the unit's potential to emit.</P>
            <P>(iv) For a PAL for a stationary source, the baseline actual emissions shall be calculated for existing electric utility steam generating units in accordance with the procedures contained in paragraph (b)(47)(i) of this section, for other existing emissions units in accordance with the procedures contained in paragraph (b)(47)(ii) of this section, and for a new emissions unit in accordance with the procedures contained in paragraph (b)(47)(iii) of this section.</P>
            <P>(48) [Reserved]</P>
            <P>(49) <E T="03">Regulated NSR pollutant,</E> for purposes of this section, means the following:</P>

            <P>(i) Any pollutant for which a national ambient air quality standard has been promulgated and any constituents or precursors for such pollutants identified by the Administrator (<E T="03">e.g.</E>, volatile organic compounds and NO<E T="52">X</E> are precursors for ozone);</P>

            <P>(ii) Any pollutant that is subject to any standard promulgated under section 111 of the Act;<PRTPAGE P="239"/>
            </P>
            <P>(iii) Any Class I or II substance subject to a standard promulgated under or established by title VI of the Act; or</P>
            <P>(iv) Any pollutant that otherwise is subject to regulation under the Act; except that any or all hazardous air pollutants either listed in section 112 of the Act or added to the list pursuant to section 112(b)(2) of the Act, which have not been delisted pursuant to section 112(b)(3) of the Act, are not regulated NSR pollutants unless the listed hazardous air pollutant is also regulated as a constituent or precursor of a general pollutant listed under section 108 of the Act.</P>
            <P>(50) <E T="03">Reviewing authority</E> means the State air pollution control agency, local agency, other State agency, Indian tribe, or other agency authorized by the Administrator to carry out a permit program under § 51.165 and this section, or the Administrator in the case of EPA-implemented permit programs under § 52.21 of this chapter.</P>
            <P>(51) <E T="03">Project</E> means a physical change in, or change in method of operation of, an existing major stationary source.</P>
            <P>(52) <E T="03">Lowest achievable emission rate (LAER)</E> is as defined in § 51.165(a)(1)(xiii).</P>
            <P>(53)(i) In general, <E T="03">process unit</E> means any collection of structures and/or equipment that processes, assembles, applies, blends, or otherwise uses material inputs to produce or store an intermediate or a completed product. A single stationary source may contain more than one process unit, and a process unit may contain more than one emissions unit.</P>
            <P>(ii) Pollution control equipment is not part of the process unit, unless it serves a dual function as both process and control equipment. Administrative and warehousing facilities are not part of the process unit.</P>
            <P>(iii) For replacement cost purposes, components shared between two or more process units are proportionately allocated based on capacity.</P>
            <P>(iv) The following list identifies the process units at specific categories of stationary sources.</P>
            <P>(<E T="03">a</E>) For a steam electric generating facility, the process unit consists of those portions of the plant that contribute directly to the production of electricity. For example, at a pulverized coal-fired facility, the process unit would generally be the combination of those systems from the coal receiving equipment through the emission stack (excluding post-combustion pollution controls), including the coal handling equipment, pulverizers or coal crushers, feedwater heaters, ash handling, boiler, burners, turbine-generator set, condenser, cooling tower, water treatment system, air preheaters, and operating control systems. Each separate generating unit is a separate process unit.</P>
            <P>(<E T="03">b</E>) For a petroleum refinery, there are several categories of process units: those that separate and/or distill petroleum feedstocks; those that change molecular structures; petroleum treating processes; auxiliary facilities, such as steam generators and hydrogen production units; and those that load, unload, blend or store intermediate or completed products.</P>
            <P>(<E T="03">c</E>) For an incinerator, the process unit would consist of components from the feed pit or refuse pit to the stack, including conveyors, combustion devices, heat exchangers and steam generators, quench tanks, and fans.</P>
            <NOTE>
              <HD SOURCE="HED">Note to paragraph (b)(53):</HD>

              <P>By a court order on December 24, 2003, this paragraph (b)(53) is stayed indefinitely. The stayed provisions will become effective immediately if the court terminates the stay. At that time, EPA will publish a document in the <E T="04">Federal Register</E> advising the public of the termination of the stay.</P>
            </NOTE>
            <P>(54) <E T="03">Functionally equivalent component</E> means a component that serves the same purpose as the replaced component.</P>
            <NOTE>
              <HD SOURCE="HED">Note to paragraph (b)(54):</HD>

              <P>By a court order on December 24, 2003, this paragraph (b)(54) is stayed indefinitely. The stayed provisions will become effective immediately if the court terminates the stay. At that time, EPA will publish a document in the <E T="04">Federal Register</E> advising the public of the termination of the stay.</P>
            </NOTE>
            <P>(55) <E T="03">Fixed capital cost</E> means the capital needed to provide all the depreciable components. “Depreciable components” refers to all components of fixed capital cost and is calculated by subtracting land and working capital from the total capital investment, as defined in paragraph (b)(56) of this section.</P>
            <NOTE>
              <HD SOURCE="HED">Note to paragraph (b)(55):</HD>

              <P>By a court order on December 24, 2003, this paragraph <PRTPAGE P="240"/>(b)(55) is stayed indefinitely. The stayed provisions will become effective immediately if the court terminates the stay. At that time, EPA will publish a document in the <E T="04">Federal Register</E> advising the public of the termination of the stay.</P>
            </NOTE>
            <P>(56) <E T="03">Total capital investment</E> means the sum of the following: all costs required to purchase needed process equipment (purchased equipment costs); the costs of labor and materials for installing that equipment (direct installation costs); the costs of site preparation and buildings; other costs such as engineering, construction and field expenses, fees to contractors, startup and performance tests, and contingencies (indirect installation costs); land for the process equipment; and working capital for the process equipment.</P>
            <NOTE>
              <HD SOURCE="HED">Note to paragraph (b)(56):</HD>

              <P>By a court order on December 24, 2003, this paragraph (b)(56) is stayed indefinitely. The stayed provisions will become effective immediately if the court terminates the stay. At that time, EPA will publish a document in the <E T="04">Federal Register</E> advising the public of the termination of the stay.</P>
            </NOTE>
            <P>(c) <E T="03">Ambient air increments and other measures.</E> (1) The plan shall contain emission limitations and such other measures as may be necessary to assure that in areas designated as Class I, II, or III, increases in pollutant concentrations over the baseline concentration shall be limited to the following:</P>
            <GPOTABLE CDEF="s100,12" COLS="2" OPTS="L2">
              <BOXHD>
                <CHED H="1">Pollutant</CHED>
                <CHED H="1">Maximum<LI>allowable</LI>
                  <LI>increase (micrograms per cubic meter)</LI>
                </CHED>
              </BOXHD>
              <ROW EXPSTB="01" RUL="s">
                <ENT I="21">
                  <E T="02">Class I</E>
                </ENT>
              </ROW>
              <ROW EXPSTB="00">
                <ENT I="22">Particulate matter:</ENT>
              </ROW>
              <ROW>
                <ENT I="03">PM<E T="52">10</E>, annual arithmetic mean</ENT>
                <ENT>4</ENT>
              </ROW>
              <ROW>
                <ENT I="03">PM<E T="52">10</E>, 24-hr maximum</ENT>
                <ENT>8</ENT>
              </ROW>
              <ROW>
                <ENT I="22">Sulfur dioxide:</ENT>
              </ROW>
              <ROW>
                <ENT I="03">Annual arithmetic mean</ENT>
                <ENT>2</ENT>
              </ROW>
              <ROW>
                <ENT I="03">24-hr maximum</ENT>
                <ENT>5</ENT>
              </ROW>
              <ROW>
                <ENT I="03">3-hr maximum</ENT>
                <ENT>25</ENT>
              </ROW>
              <ROW>
                <ENT I="22">Nitrogen dioxide:</ENT>
              </ROW>
              <ROW RUL="s">
                <ENT I="03">Annual arithmetic mean</ENT>
                <ENT>2.5</ENT>
              </ROW>
              <ROW EXPSTB="01" RUL="s">
                <ENT I="21">
                  <E T="02">Class II</E>
                </ENT>
              </ROW>
              <ROW EXPSTB="00">
                <ENT I="22">Particulate matter:</ENT>
              </ROW>
              <ROW>
                <ENT I="03">PM<E T="52">10</E>, annual arithmetic mean</ENT>
                <ENT>17</ENT>
              </ROW>
              <ROW>
                <ENT I="03">PM<E T="52">10</E>, 24-hr maximum</ENT>
                <ENT>30</ENT>
              </ROW>
              <ROW>
                <ENT I="22">Sulfur dioxide:</ENT>
              </ROW>
              <ROW>
                <ENT I="03">Annual arithmetic mean</ENT>
                <ENT>20</ENT>
              </ROW>
              <ROW>
                <ENT I="03">24-hr maximum</ENT>
                <ENT>91</ENT>
              </ROW>
              <ROW>
                <ENT I="03">3-hr maximum</ENT>
                <ENT>512</ENT>
              </ROW>
              <ROW>
                <ENT I="22">Nitrogen dioxide:</ENT>
              </ROW>
              <ROW RUL="s">
                <ENT I="03">Annual arithmetic mean</ENT>
                <ENT>25</ENT>
              </ROW>
              <ROW EXPSTB="01" RUL="s">
                <ENT I="21">
                  <E T="02">Class III</E>
                </ENT>
              </ROW>
              <ROW EXPSTB="00">
                <ENT I="22">Particulate matter:</ENT>
              </ROW>
              <ROW>
                <ENT I="03">PM<E T="52">10</E>, annual arithmetic mean</ENT>
                <ENT>34</ENT>
              </ROW>
              <ROW>
                <ENT I="03">PM<E T="52">10</E>, 24-hr maximum</ENT>
                <ENT>60</ENT>
              </ROW>
              <ROW>
                <ENT I="22">Sulfur dioxide:</ENT>
              </ROW>
              <ROW>
                <ENT I="03">Annual arithmetic mean</ENT>
                <ENT>40</ENT>
              </ROW>
              <ROW>
                <ENT I="03">24-hr maximum</ENT>
                <ENT>182</ENT>
              </ROW>
              <ROW>
                <ENT I="03">3-hr maximum</ENT>
                <ENT>700</ENT>
              </ROW>
              <ROW>
                <ENT I="22">Nitrogen dioxide:</ENT>
              </ROW>
              <ROW>
                <ENT I="03">Annual arithmetic mean</ENT>
                <ENT>50</ENT>
              </ROW>
            </GPOTABLE>
            <P>For any period other than an annual period, the applicable maximum allowable increase may be exceeded during one such period per year at any one location.</P>
            <P>(2) Where the State can demonstrate that it has alternative measures in its plan other than maximum allowable increases that satisfy the requirements in sections 166(c) and 166(d) of the Clean Air Act for nitrogen oxides, the requirements for maximum allowable increases for nitrogen dioxide under paragraph (c)(1) of this section shall not apply upon approval of the plan by the Administrator.</P>
            <P>(d) <E T="03">Ambient air ceilings.</E> The plan shall provide that no concentration of a pollutant shall exceed:</P>
            <P>(1) The concentration permitted under the national secondary ambient air quality standard, or</P>
            <P>(2) The concentration permitted under the national primary ambient air quality standard, whichever concentration is lowest for the pollutant for a period of exposure.</P>
            <P>(e) <E T="03">Restrictions on area classifications.</E> The plan shall provide that—</P>
            <P>(1) All of the following areas which were in existence on August 7, 1977, shall be Class I areas and may not be redesignated:</P>
            <P>(i) International parks,</P>
            <P>(ii) National wilderness areas which exceed 5,000 acres in size,</P>
            <P>(iii) National memorial parks which exceed 5,000 acres in size, and</P>
            <P>(iv) National parks which exceed 6,000 acres in size.</P>

            <P>(2) Areas which were redesignated as Class I under regulations promulgated before August 7, 1977, shall remain Class I, but may be redesignated as provided in this section.<PRTPAGE P="241"/>
            </P>
            <P>(3) Any other area, unless otherwise specified in the legislation creating such an area, is initially designated Class II, but may be redesignated as provided in this section.</P>
            <P>(4) The following areas may be redesignated only as Class I or II:</P>
            <P>(i) An area which as of August 7, 1977, exceeded 10,000 acres in size and was a national monument, a national primitive area, a national preserve, a national recreational area, a national wild and scenic river, a national wildlife refuge, a national lakeshore or seashore; and</P>
            <P>(ii) A national park or national wilderness area established after August 7, 1977, which exceeds 10,000 acres in size.</P>
            <P>(f) <E T="03">Exclusions from increment consumption.</E> (1) The plan may provide that the following concentrations shall be excluded in determining compliance with a maximum allowable increase:</P>
            <P>(i) Concentrations attributable to the increase in emissions from stationary sources which have converted from the use of petroleum products, natural gas, or both by reason of an order in effect under section 2 (a) and (b) of the Energy Supply and Environmental Coordination Act of 1974 (or any superseding legislation) over the emissions from such sources before the effective date of such an order;</P>
            <P>(ii) Concentrations attributable to the increase in emissions from sources which have converted from using natural gas by reason of natural gas curtailment plan in effect pursuant to the Federal Power Act over the emissions from such sources before the effective date of such plan;</P>
            <P>(iii) Concentrations of particulate matter attributable to the increase in emissions from construction or other temporary emission-related activities of new or modified sources;</P>
            <P>(iv) The increase in concentrations attributable to new sources outside the United States over the concentrations attributable to existing sources which are included in the baseline concentration; and</P>
            <P>(v) Concentrations attributable to the temporary increase in emissions of sulfur dioxide, particulate matter, or nitrogen oxides from stationary sources which are affected by plan revisions approved by the Administrator as meeting the criteria specified in paragraph (f)(4) of this section.</P>
            <P>(2) If the plan provides that the concentrations to which paragraph (f)(1) (i) or (ii) of this section, refers shall be excluded, it shall also provide that no exclusion of such concentrations shall apply more than five years after the effective date of the order to which paragraph (f)(1)(i) of this section, refers or the plan to which paragraph (f)(1)(ii) of this section, refers, whichever is applicable. If both such order and plan are applicable, no such exclusion shall apply more than five years after the later of such effective dates.</P>
            <P>(3) [Reserved]</P>
            <P>(4) For purposes of excluding concentrations pursuant to paragraph (f)(1)(v) of this section, the Administrator may approve a plan revision that:</P>
            <P>(i) Specifies the time over which the temporary emissions increase of sulfur dioxide, particulate matter, or nitrogen oxides would occur. Such time is not to exceed 2 years in duration unless a longer time is approved by the Administrator.</P>
            <P>(ii) Specifies that the time period for excluding certain contributions in accordance with paragraph (f)(4)(i) of this section, is not renewable;</P>
            <P>(iii) Allows no emissions increase from a stationary source which would:</P>
            <P>(<E T="03">a</E>) Impact a Class I area or an area where an applicable increment is known to be violated; or</P>
            <P>(<E T="03">b</E>) Cause or contribute to the violation of a national ambient air quality standard;</P>
            <P>(iv) Requires limitations to be in effect the end of the time period specified in accordance with paragraph (f)(4)(i) of this section, which would ensure that the emissions levels from stationary sources affected by the plan revision would not exceed those levels occurring from such sources before the plan revision was approved.</P>
            <P>(g) <E T="03">Redesignation.</E> (1) The plan shall provide that all areas of the State (except as otherwise provided under paragraph (e) of this section) shall be designated either Class I, Class II, or Class III. Any designation other than Class II shall be subject to the redesignation procedures of this paragraph. Redesignation (except as otherwise precluded <PRTPAGE P="242"/>by paragraph (e) of this section) may be proposed by the respective States or Indian Governing Bodies, as provided below, subject to approval by the Administrator as a revision to the applicable State implementation plan.</P>

            <P>(2) The plan may provide that the State may submit to the Administrator a proposal to redesignate areas of the State Class I or Class II: <E T="03">Provided,</E> That:</P>
            <P>(i) At least one public hearing has been held in accordance with procedures established in § 51.102.</P>
            <P>(ii) Other States, Indian Governing Bodies, and Federal Land Managers whose lands may be affected by the proposed redesignation were notified at least 30 days prior to the public hearing;</P>
            <P>(iii) A discussion of the reasons for the proposed redesignation, including a satisfactory description and analysis of the health, environmental, economic, social, and energy effects of the proposed redesignation, was prepared and made available for public inspection at least 30 days prior to the hearing and the notice announcing the hearing contained appropriate notification of the availability of such discussion;</P>
            <P>(iv) Prior to the issuance of notice respecting the redesignation of an area that includes any Federal lands, the State has provided written notice to the appropriate Federal Land Manager and afforded adequate opportunity (not in excess of 60 days) to confer with the State respecting the redesignation and to submit written comments and recommendations. In redesignating any area with respect to which any Federal Land Manager had submitted written comments and recommendations, the State shall have published a list of any inconsistency between such redesignation and such comments and recommendations (together with the reasons for making such redesignation against the recommendation of the Federal Land Manager); and</P>
            <P>(v) The State has proposed the redesignation after consultation with the elected leadership of local and other substate general purpose governments in the area covered by the proposed redesignation.</P>
            <P>(3) The plan may provide that any area other than an area to which paragraph (e) of this section refers may be redesignated as Class III if—</P>
            <P>(i) The redesignation would meet the requirements of provisions established in accordance with paragraph (g)(2) of this section;</P>
            <P>(ii) The redesignation, except any established by an Indian Governing Body, has been specifically approved by the Governor of the State, after consultation with the appropriate committees of the legislature, if it is in session, or with the leadership of the legislature, if it is not in session (unless State law provides that such redesignation must be specifically approved by State legislation) and if general purpose units of local government representing a majority of the residents of the area to be redesignated enact legislation (including resolutions where appropriate) concurring in the redesignation;</P>
            <P>(iii) The redesignation would not cause, or contribute to, a concentration of any air pollutant which would exceed any maximum allowable increase permitted under the classification of any other area or any national ambient air quality standard; and</P>
            <P>(iv) Any permit application for any major stationary source or major modification subject to provisions established in accordance with paragraph (l) of this section which could receive a permit only if the area in question were redesignated as Class III, and any material submitted as part of that application, were available, insofar as was practicable, for public inspection prior to any public hearing on redesignation of any area as Class III.</P>

            <P>(4) The plan shall provide that lands within the exterior boundaries of Indian Reservations may be redesignated only by the appropriate Indian Governing Body. The appropriate Indian Governing Body may submit to the Administrator a proposal to redesignate areas Class I, Class II, or Class III: <E T="03">Provided,</E> That:</P>
            <P>(i) The Indian Governing Body has followed procedures equivalent to those required of a State under paragraphs (g) (2), (3)(iii), and (3)(iv) of this section; and</P>

            <P>(ii) Such redesignation is proposed after consultation with the State(s) in <PRTPAGE P="243"/>which the Indian Reservation is located and which border the Indian Reservation.</P>
            <P>(5) The Administrator shall disapprove, within 90 days of submission, a proposed redesignation of any area only if he finds, after notice and opportunity for public hearing, that such redesignation does not meet the procedural requirements of this section or is inconsistent with paragraph (e) of this section. If any such disapproval occurs, the classification of the area shall be that which was in effect prior to the redesignation which was disapproved.</P>
            <P>(6) If the Administrator disapproves any proposed area designation, the State or Indian Governing Body, as appropriate, may resubmit the proposal after correcting the deficiencies noted by the Administrator.</P>
            <P>(h) <E T="03">Stack heights.</E> The plan shall provide, as a minimum, that the degree of emission limitation required for control of any air pollutant under the plan shall not be affected in any manner by—</P>
            <P>(1) So much of a stack height, not in existence before December 31, 1970, as exceeds good engineering practice, or</P>
            <P>(2) Any other dispersion technique not implemented before then.</P>
            <P>(i) <E T="03">Exemptions.</E> (1) The plan may provide that requirements equivalent to those contained in paragraphs (j) through (r) of this section do not apply to a particular major stationary source or major modification if:</P>
            <P>(i) The major stationary source would be a nonprofit health or nonprofit educational institution or a major modification that would occur at such an institution; or</P>
            <P>(ii) The source or modification would be a major stationary source or major modification only if fugitive emissions, to the extent quantifiable, are considered in calculating the potential to emit of the stationary source or modification and such source does not belong to any following categories:</P>
            <P>(<E T="03">a</E>) Coal cleaning plants (with thermal dryers);</P>
            <P>(<E T="03">b</E>) Kraft pulp mills;</P>
            <P>(<E T="03">c</E>) Portland cement plants;</P>
            <P>(<E T="03">d</E>) Primary zinc smelters;</P>
            <P>(<E T="03">e</E>) Iron and steel mills;</P>
            <P>(<E T="03">f</E>) Primary aluminum ore reduction plants;</P>
            <P>(<E T="03">g</E>) Primary copper smelters;</P>
            <P>(<E T="03">h</E>) Municipal incinerators capable of charging more than 250 tons of refuse per day;</P>
            <P>(<E T="03">i</E>) Hydrofluoric, sulfuric, or nitric acid plants;</P>
            <P>(<E T="03">j</E>) Petroleum refineries;</P>
            <P>(<E T="03">k</E>) Lime plants;</P>
            <P>(<E T="03">l</E>) Phosphate rock processing plants;</P>
            <P>(<E T="03">m</E>) Coke oven batteries;</P>
            <P>(<E T="03">n</E>) Sulfur recovery plants;</P>
            <P>(<E T="03">o</E>) Carbon black plants (furnace process);</P>
            <P>(<E T="03">p</E>) Primary lead smelters;</P>
            <P>(<E T="03">q</E>) Fuel conversion plants;</P>
            <P>(<E T="03">r</E>) Sintering plants;</P>
            <P>(<E T="03">s</E>) Secondary metal production plants;</P>
            <P>(<E T="03">t</E>) Chemical process plants;</P>
            <P>(<E T="03">u</E>) Fossil-fuel boilers (or combination thereof) totaling more than 250 million British thermal units per hour heat input;</P>
            <P>(<E T="03">v</E>) Petroleum storage and transfer units with a total storage capacity exceeding 300,000 barrels;</P>
            <P>(<E T="03">w</E>) Taconite ore processing plants;</P>
            <P>(<E T="03">x</E>) Glass fiber processing plants;</P>
            <P>(<E T="03">y</E>) Charcoal production plants;</P>
            <P>(<E T="03">z</E>) Fossil fuel-fired steam electric plants of more than 250 million British thermal units per hour heat input;</P>
            <P>(<E T="03">aa</E>) Any other stationary source category which, as of August 7, 1980, is being regulated under section 111 or 112 of the Act; or</P>
            <P>(iii) The source or modification is a portable stationary source which has previously received a permit under requirements equivalent to those contained in paragraphs (j) through (r) of this section, if:</P>
            <P>(<E T="03">a</E>) The source proposes to relocate and emissions of the source at the new location would be temporary; and</P>
            <P>(<E T="03">b</E>) The emissions from the source would not exceed its allowable emissions; and</P>
            <P>(<E T="03">c</E>) The emissions from the source would impact no Class I area and no area where an applicable increment is known to be violated; and<PRTPAGE P="244"/>
            </P>
            <P>(<E T="03">d</E>) Reasonable notice is given to the reviewing authority prior to the relocation identifying the proposed new location and the probable duration of operation at the new location. Such notice shall be given to the reviewing authority not less than 10 days in advance of the proposed relocation unless a different time duration is previously approved by the reviewing authority.</P>
            <P>(2) The plan may provide that requirements equivalent to those contained in paragraphs (j) through (r) of this section do not apply to a major stationary source or major modification with respect to a particular pollutant if the owner or operator demonstrates that, as to that pollutant, the source or modification is located in an area designated as nonattainment under section 107 of the Act.</P>
            <P>(3) The plan may provide that requirements equivalent to those contained in paragraphs (k), (m), and (o) of this section do not apply to a proposed major stationary source or major modification with respect to a particular pollutant, if the allowable emissions of that pollutant from a new source, or the net emissions increase of that pollutant from a modification, would be temporary and impact no Class I area and no area where an applicable increment is known to be violated.</P>
            <P>(4) The plan may provide that requirements equivalent to those contained in paragraphs (k), (m), and (o) of this section as they relate to any maximum allowable increase for a Class II area do not apply to a modification of a major stationary source that was in existence on March 1, 1978, if the net increase in allowable emissions of each a regulated NSR pollutant from the modification after the application of best available control technology would be less than 50 tons per year.</P>
            <P>(5) The plan may provide that the reviewing authority may exempt a proposed major stationary source or major modification from the requirements of paragraph (m) of this section, with respect to monitoring for a particular pollutant, if:</P>
            <P>(i) The emissions increase of the pollutant from a new stationary source or the net emissions increase of the pollutant from a modification would cause, in any area, air quality impacts less than the following amounts:</P>
            <P>(<E T="03">a</E>) Carbon monoxide—575 ug/m<SU>3</SU>, 8-hour average;</P>
            <P>(<E T="03">b</E>) Nitrogen dioxide—14 ug/m<SU>3</SU>, annual average;</P>
            <P>(c) Particulate matter—10 µg/m<SU>3</SU> of PM-10, 24-hour average.</P>
            <P>(<E T="03">d</E>) Sulfur dioxide—13 ug/m<SU>3</SU>, 24-hour average;</P>
            <P>(<E T="03">e</E>) Ozone; <SU>1</SU>
              <FTREF/>
            </P>
            <FTNT>
              <P>
                <SU>1</SU> No <E T="03">de minimis</E> air quality level is provided for ozone. However, any net emissions increase of 100 tons per year or more of volatile organic compounds or nitrogen oxides subject to PSD would be required to perform an ambient impact analysis, including the gathering of air quality data.</P>
            </FTNT>
            <P>(<E T="03">f</E>) Lead—0.1 µg/m<SU>3</SU>, 3-month average.</P>
            <P>(<E T="03">g</E>) Fluorides—0.25 µg/m<SU>3</SU>, 24-hour average;</P>
            <P>(<E T="03">h</E>) Total reduced sulfur—10 µg/m<SU>3</SU>, 1-hour average</P>
            <P>(<E T="03">i</E>) Hydrogen sulfide—0.2 µg/m<SU>3</SU>, 1-hour average;</P>
            <P>(<E T="03">j</E>) Reduced sulfur compounds—10 µg/m<SU>3</SU>, 1-hour average; or</P>
            <P>(ii) The concentrations of the pollutant in the area that the source or modification would affect are less than the concentrations listed in (i)(8)(i) of this section; or</P>
            <P>(iii) The pollutants is not listed in paragraph (i)(8)(i) of this section.</P>
            <P>(6) If EPA approves a plan revision under 40 CFR 51.166 as in effect before August 7, 1980, any subsequent revision which meets the requirements of this section may contain transition provisions which parallel the transition provisions of 40 CFR 52.21(i)(9), (i)(10) and (m)(1)(v) as in effect on that date, which provisions relate to requirements for best available control technology and air quality analyses. Any such subsequent revision may not contain any transition provision which in the context of the revision would operate any less stringently than would its counterpart in 40 CFR 52.21.</P>

            <P>(7) If EPA approves a plan revision under § 51.166 as in effect [before July 31, 1987], any subsequent revision which meets the requirements of this section may contain transition provisions which parallel the transition provisions of § 52.21 (i)(11), and (m)(1) (vii) and (viii) of this chapter as in effect on <PRTPAGE P="245"/>that date, these provisions being related to monitoring requirements for particulate matter. Any such subsequent revision may not contain any transition provision which in the context of the revision would operate any less stringently than would its counterpart in § 52.21 of this chapter.</P>
            <P>(8) The plan may provide that the permitting requirements equivalent to those co