## Attachment 6 Requirements for a SIP Approved PSD Program in 40 CFR 51.166 and How those Requirements are met by South Coast AQMD Rule 1714 Page 1of 53

51.166 Requirements of 40 CFR 51.166 for a SIP approved PSD program Where included in Rule 1714 or in 40 CFR 52.21 as IBR in Rule 1714(c) (a)(1) Plan requirements (1) Plan requirements. 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. With this action the District would adopt a PSD program into the CA SIP (a)(2) Plan revisions (2) Plan revisions. 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). Not applicable to this action.

(a)(3) Required plan

revision (3) Required plan revision. 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. Not applicable to this action.

(a)(4) Plan assessment (4) Plan assessment. The State shall review the adequacy of a plan on a periodic basis and within 60 days of such time as information becomes available that an applicable increment is being violated. Not applicable to this action.
(a)(5) Public

participation (5) Public participation. 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. Public notice (10/15/2010) and public hearing (11/5/2010) were held.
(a)(6) Amendments (6) Amendments. (i) Any State required to revise its implementation plan by reason of an amendment to this section, with the exception of amendments to add new maximum allowable increases or other measures pursuant to section 166(a) of the Act, shall adopt and submit such plan revision to the Administrator for approval no later than 3 years after such amendment is published in theFederal Register.With regard to a revision to an implementation plan by reason of an amendment to paragraph (c) of this section to add maximum allowable increases or other measures, the State shall submit such plan revision to the Administrator for approval within 21 months after such amendment is published in the Federal Register. Not applicable to this action

(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. Not applicable to this action.
(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. Not applicable to this action. (a)(7) Applicability (7) Applicability. Each plan shall contain procedures that incorporate the requirements in paragraphs (a)(7)(i) through (vi) of this section. 40 CFR 52.21(a)(2)

## Attachment 6 Requirements for a SIP Approved PSD Program in 40 CFR 51.166 and How those Requirements are met by South Coast AQMD Rule 1714 Page 2of 53

(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. 40 CFR 52.21(a)(2)(i)

(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. 40 CFR 52.21(a)(2)(ii)

(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. 40 CFR 52.21(a)(2)(iii)

(iv) Each plan shall use the specific provisions of paragraphs (a)(7)(iv)( 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)(7)(iv)( a ) through ( f ) of this section. 40 CFR 52.21(a)(2)(iv)

( a ) 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. 40 CFR 52.21(a)(2)(iv)(a )

( b ) The procedure for calculating (before beginning actual construction) whether a significant emissions increase ( i.e. , the first step of the process) will occur depends upon the type of emissions units being modified, according to paragraphs (a)(7)(iv)( 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 ( i.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. 40 CFR 52.21(a)(2)(iv)(b )

( c ) Actual-to-projected-actual applicability test for projects that only involve existing emissions units. 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 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). 40 CFR 52.21(a)(2)(iv)(c )

( d ) Actual-to-potential test for projects that only involve construction of a new emissions unit(s). 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). 40 CFR 52.21(a)(2)(iv)(d )

## Attachment 6 Requirements for a SIP Approved PSD Program in 40 CFR 51.166 and How those Requirements are met by South Coast AQMD Rule 1714 Page 3of 53

( e ) [Reserved] 40 CFR 52.21(a)(2)(iv)(e ) ( f ) Hybrid test for projects that involve multiple types of emissions units. 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)( c ) through ( d ) 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). 40 CFR 52.21(a)(2)(iv)(f)

(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. 40 CFR 52.21(a)(2)(v)

(b) Definitions (b) Definitions. 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: 40 CFR 52.21(b)

(b)(1) Major stationary

source (1)(i) Major stationary source means: 40 CFR 52.21(b)(1)(i)

( a ) 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 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 (with thermal dryers), 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 (which does not include ethanol production facilities that produce ethanol by natural fermentation included in NAICS codes 325193 or 312140), 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 40 CFR 52.21(b)(1)(i)(a )

( b ) Notwithstanding the stationary source size specified in paragraph (b)(1)(i)( a ) 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 40 CFR 52.21(b)(1)(i)(b )

( c ) Any physical change that would occur at a stationary source not otherwise qualifying under paragraph (b)(1) of this section, as a major stationary source if the change would constitute a major stationary source by itself. 40 CFR 52.21(b)(1)(i)(c )

(ii) A major source that is major for volatile organic compounds or NOXshall be considered major for

ozone. 40 CFR 52.21(b)(1)(ii)

(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: ( a ) Coal cleaning plants (with thermal dryers); ( b ) Kraft pulp mills; ( c ) Portland cement plants; ( d ) Primary zinc smelters; ( e ) Iron and steel mills; 40 CFR 52.21(b)(1)(ii)

## Attachment 6 Requirements for a SIP Approved PSD Program in 40 CFR 51.166 and How those Requirements are met by South Coast AQMD Rule 1714 Page 4of 53

( f ) Primary aluminum ore reduction plants; ( g ) Primary copper smelters; ( h ) Municipal incinerators capable of charging more than 250 tons of refuse per day; ( i ) Hydrofluoric, sulfuric, or nitric acid plants; ( j ) Petroleum refineries; ( k ) Lime plants; ( l ) Phosphate rock processing plants; ( m ) Coke oven batteries; ( n ) Sulfur recovery plants; ( o ) Carbon black plants (furnace process); ( p ) Primary lead smelters; ( q ) Fuel conversion plants; ( r ) Sintering plants; ( s ) Secondary metal production plants; ( t ) Chemical process plants—The term chemical processing plant shall not include ethanol production facilities that produce ethanol by natural fermentation included in NAICS codes 325193 or 312140; ( u ) Fossil-fuel boilers (or combination thereof) totaling more than 250 million British thermal units per hour heat input; ( v ) Petroleum storage and transfer units with a total storage capacity exceeding 300,000 barrels;

( w ) Taconite ore processing plants; ( x ) Glass fiber processing plants; ( y ) Charcoal production plants; ( z ) Fossil fuel-fired steam electric plants of more that 250 million British thermal units per hour heat input; ( aa ) Any other stationary source category which, as of August 7, 1980, is being regulated under section 111 or 112 of the Act. (b)(2) Major modification (2)(i) Major modification 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. 40 CFR 52.21(b)(2)(i)

(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 NOXshall be considered significant for ozone. 40 CFR 52.21(b)(2)(ii)

(iii) A physical change or change in the method of operation shall not include: 40 CFR 52.21(b)(2)(iii) 40 CFR 52.21(b)(1)(ii)

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( a ) 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;
Note to paragraph (b)(2)(iii)( a ): On December 24, 2003, the second sentence of this paragraph (b)(2)(iii)( a ) 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 Federal Register advising the public of the termination of the stay.
( b ) 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; 40 CFR 52.21(b)(2)(iii)(b )

( c ) Use of an alternative fuel by reason of an order or rule under section 125 of the Act; 40 CFR 52.21(b)(2)(iii)(c ) ( d ) Use of an alternative fuel at a steam generating unit to the extent that the fuel is generated from municipal solid waste; 40 CFR 52.21(b)(2)(iii)(d ) ( e ) Use of an alternative fuel or raw material by a stationary source which: 40 CFR 52.21(b)(2)(iii)(e ) ( 1 ) 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 under regulations approved pursuant to 40 CFR subpart I or §51.166; or 40 CFR 52.21(b)(2)(iii)(e )(1 )

( 2 ) 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; 40 CFR 52.21(b)(2)(iii)(e )(2 ) ( f ) 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. 40 CFR 52.21(b)(2)(iii)(f)

( g ) Any change in ownership at a stationary source. 40 CFR 52.21(b)(2)(iii)(g ) ( h ) [Reserved] 40 CFR 52.21(b)(2)(iii)(h ) ( i ) The installation, operation, cessation, or removal of a temporary clean coal technology demonstration project, provided that the project complies with: 40 CFR 52.21(b)(2)(iii)(i )

( 1 ) The State implementation plan for the State in which the project is located; and 40 CFR 52.21(b)(2)(iii)(i )(1 ) ( 2 ) Other requirements necessary to attain and maintain the national ambient air quality standards during the project and after it is terminated. 40 CFR 52.21(b)(2)(iii)(i )(2 ) ( j ) 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 toemit of any regulated pollutant emitted by the unit. This exemption shall apply on a pollutant-bypollutant basis. 40 CFR 52.21(b)(2)(iii)( j )

( k ) The reactivation of a very clean coal-fired electric utility steam generating unit. 40 CFR 52.21(b)(2)(iii)(k ) (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. 40 CFR 52.21(b)(2)(iv) 40 CFR 52.21(b)(2)(iii)(a )

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(v) Fugitive emissions shall not be included in determining for any of the purposes of this section whether a physical change in or change in the method of operation of a major stationary source is a major modification, unless the source belongs to one of the source categories listed in paragraph (b)(1)(iii) of this section. 40 CFR 52.21(b)(2)(v) -

(b)(3) Net emissions

increase (3)(i) Net emissions increase 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: 40 CFR 52.21(b)(3)(i)

( a ) 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 40 CFR 52.21(b)(3)(i)(a )

( b ) 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)( b ) shall be determined as provided in paragraph (b)(47), except that paragraphs (b)(47)(i)( c ) and (b)(47)(ii)( d ) of this section shall not apply. 40 CFR 52.21(b)(3)(i)(b )

(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. 40 CFR 52.21(b)(3)(ii)

(iii) An increase or decrease in actual emissions is creditable only if: 40 CFR 52.21(b)(3)(iii)

( a ) It occurs within a reasonable period (to be specified by the reviewing authority); and 40 CFR 52.21(b)(3)(iii)(a ) ( b ) 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 40 CFR 52.21(b)(3)(iii)(b )
( c ) 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. 40 CFR 52.21(b)(3)(iii)(c ) ( d ) As it pertains to an increase or decrease in fugitive emissions (to the extent quantifiable), it occurs at an emissions unit that is part of one of the source categories listed in paragraph (b)(1)(iii) of this section or it occurs at an emission unit that is located at a major stationary source that belongs to one of the listed source categories. Fugitive emission increases or decreases are not included for those emissions units located at a facility whose primary activity is not represented by one of the source categories listed in paragraph (b)(1)(iii) of this section and that are not, by themselves, part of a listed source category. 40 CFR 52.21(b)(3)(iii)(d )

(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. 40 CFR 52.21(b)(3)(iv)

(v) An increase in actual emissions is creditable only to the extent that the new level of actual emissions exceeds the old level. 40 CFR 52.21(b)(3)(v)

(vi) A decrease in actual emissions is creditable only to the extent that: 40 CFR 52.21(b)(3)(vi)

( a ) The old level of actual emissions or the old level of allowable emissions, whichever is lower, exceeds the new level of actual emissions; 40 CFR 52.21(b)(3)(vi)(a )

## Attachment 6 Requirements for a SIP Approved PSD Program in 40 CFR 51.166 and How those Requirements are met by South Coast AQMD Rule 1714 Page 7of 53

( b ) It is enforceable as a practical matter at and after the time that actual construction on the particular change begins; 40 CFR 52.21(b)(3)(vi)(b ) ( c ) It has approximately the same qualitative significance for public health and welfare as that attributed to the increase from the particular change; and 40 CFR 52.21(b)(3)(vi)(c ) (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. 40 CFR 52.21(b)(3)(vii)

(viii) Paragraph (b)(21)(ii) of this section shall not apply for determining creditable increases and decreases. 40 CFR 52.21(b)(3)(viii)

(b)(4) Potential to emit (4) Potential to emit 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. 40 CFR 52.21(b)(4)

(b)(5) Stationary source (5) Stationary source means any building, structure, facility, or installation which emits or may emit a regulated NSR pollutant. 40 CFR 52.21(b)(5)

(b)(6) Building,

structure, facility, or installation (6) Building, structure, facility, or installation 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 Major Group ( i.e. , which have the same two-digit code) as described in the Standard Industrial Classification Manual, 1972, as amended by the 1977 Supplement (U.S. Government Printing Office stock numbers 4101–0066 and 003–005–00176–0, respectively). 40 CFR 52.21(b)(6)

(b)(7) Emissions unit (7) Emissions unit 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. 40 CFR 52.21(b)(7)

(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. 40 CFR 52.21(b)(7)(i)

(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. 40 CFR 52.21(b)(7)(ii)

(b)(8) Construction (8) Construction 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. 40 CFR 52.21(b)(8)

(b)(9) Commence (9) Commence 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: 40 CFR 52.21(b)(9)

(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 40 CFR 52.21(b)(9)(i)
(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. 40 CFR 52.21(b)(9)(ii)

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(b)(10) Necessary

preconstruction approvals or permits (10) Necessary preconstruction approvals or permits 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. 40 CFR 52.21(b)(10)

(b)(11) Begin actual

construction (11) Begin actual construction 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. 40 CFR 52.21(b)(11)

(b)(12) Best available

control technology (12) Best available control technology 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 40 CFR 52.21(b)(12)

(b)(13) Baseline

concentration (13)(i) Baseline concentration 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:
( a ) 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; ( b ) 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.
(ii) The following will not be included in the baseline concentration and will affect the applicable maximum allowable increase(s): ( a ) 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
( b ) Actual emissions increases and decreases, as defined in paragraph (b)(21) of this section, at any stationary source occurring after the minor source baseline date. (b)(14) Major source

baseline date (14)(i) Major source baseline date means:
( a ) In the case of PM 10and sulfur dioxide, January 6, 1975; ( b ) In the case of nitrogen dioxide, February 8, 1988; and ( c ) In the case of PM 2.5,October 20, 2010. Paragraph (c)(1) of Rule 1714 excludes this definition, which found in 40 CFR 52.21(b)(13)(i). This definition does not pertain to GHGs.

Paragraph (c)(1) of Rule 1714 excludes this definition, which found in 40 CFR 52.21(b)(14). This definition does not pertain to GHGs.

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(ii) Minor source baseline date 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:
( a ) In the case of PM 10and sulfur dioxide, August 7, 1977; ( b ) In the case of nitrogen dioxide, February 8, 1988; and ( c ) In the case of PM 2.5,October 20, 2011. (iii) The baseline date is established for each pollutant for which increments or other equivalent measures have been established if: ( a ) The area in which the proposed source or modification would construct is designated as attainment or unclassifiable under section 107(d)(1)(A)(ii) or (iii) 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 ( b ) 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. (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.
(b)(15) Baseline area (15)(i) Baseline area means any intrastate area (and every part thereof) designated as attainment or unclassifiable under section 107(d)(1)(A)(ii) or (iii) 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 for the pollutant for which the baseline date is established, as follows: Equal to or greater than 1 μg/m 3(annual average) for SO2,NO2, or PM 10; or equal or greater than 0.3 μg/m 3(annual average) for PM 2.5. (ii) Area redesignations under section 107(d)(1)(A)(ii) or (iii) of the Act cannot intersect or be smaller than the area of impact of any major stationary source or major modification which:
( a ) Establishes a minor source baseline date; or ( b ) 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.
(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.
(b)(16) Allowable

emissions (16) Allowable emissions 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: 40 CFR 52.21(b)(16)

(i) The applicable standards as set forth in 40 CFR parts 60 and 61; 40 CFR 52.21(b)(16)(i) Paragraph (c)(1) of Rule 1714 excludes this definition, which found in 40 CFR 52.21(b)(15). This definition does not pertain to GHGs. Paragraph (c)(1) of Rule 1714 excludes this definition, which found in 40 CFR 52.21(b)(14). This definition does not pertain to GHGs.

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(ii) The applicable State Implementation Plan emissions limitation, including those with a future compliance date; or 40 CFR 52.21(b)(16)(ii)
(iii) The emissions rate specified as a federally enforceable permit condition. 40 CFR 52.21(b)(16)(iii) - also adds the phrase "including those with a future compliance date". The resulting definition is at least as stringent than the definition in 51.166.

(b)(17) Federally

enforceable (17) Federally enforceable 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. 40 CFR 52.21(b)(17) - Rule 1714(c)(2), revises the term "Administrator" in 40 CFR 52.21(b)(37)(i) to mean the "Federal Administator" consistent with 51.166.

(b)(18) Secondary

emissions (18) Secondary emissions 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. 40 CFR 52.21(b)(18) - Wording is slightly different, but is at least as stringent as the definition in 51.166.

(b)(19) Innovative control

technology (19) Innovative control technology 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. 40 CFR 52.21(b)(19)

(b)(20) Fugitive emissions (20) Fugitive emissions means those emissions which could not reasonably pass through a stack, chimney, vent, or other functionally equivalent opening. 40 CFR 52.21(b)(20)

(b)(21) Actual emissions (21)(i) Actual emissions 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. 40 CFR 52.21(b)(21)(i)

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(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. 40 CFR 52.21(b)(21)(ii)

(iii) The reviewing authority may presume that source-specific allowable emissions for the unit are equivalent to the actual emissions of the unit. 40 CFR 52.21(b)(21)(iii)

(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. 40 CFR 52.21(b)(21)(iv)

(b)(22) Complete (22) Complete 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. 40 CFR 52.21(b)(22) - does not include the second sentence. However, District Rule 210(b) allows the District to request additional information while processing the application. This is an existing SIP-approved rule applicable to all permitting actions. (b)(23) Significant (23)(i) Significant 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:

Pollutant and Emissions Rate Carbon monoxide: 100 tons per year (tpy) Nitrogen oxides: 40 tpy Sulfur dioxide: 40 tpy Particulate matter: 25 tpy of particulate matter emissions. 15 tpy of PM 10emissions
PM 2.5 : 10 tpy of direct PM 2.5emissions; 40 tpy of sulfur dioxide emissions; 40 tpy of nitrogen oxide emissions unless demonstrated not to be a PM 2.5precursor under paragraph (b)(49) of this section

Ozone: 40 tpy of volatile organic compounds or nitrogen oxides Lead: 0.6 tpy Fluorides: 3 tpy Sulfuric acid mist: 7 tpy Hydrogen sulfide (H 2S): 10 tpy Total reduced sulfur (including H 2S): 10 tpy Reduced sulfur compounds (including H 2S): 10 tpy 40 CFR 52.21(b)(23)(i)

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Municipal waste combustor organics (measured as total tetra-through octa-chlorinated dibenzo-pdioxins and dibenzofurans): 3.2 × 10– −6megagrams per year (3.5 × 10 −6tons per year)
Municipal waste combustor metals (measured as particulate matter): 14 megagrams per year (15 tons per year) Municipal waste combustor acid gases (measured as sulfur dioxide and hydrogen chloride): 36 megagrams per year (40 tons per year) Municipal solid waste landfill emissions (measured as nonmethane organic compounds): 45 megagrams per year (50 tons per year) (ii) Significant 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. 40 CFR 52.21(b)(23)(ii)

(iii) Notwithstanding paragraph (b)(23)(i) of this section, significant 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 3(24-hour average). 40 CFR 52.21(b)(23)(iii)

(b)(24) Federal Land

Manager (24) Federal Land Manager means, with respect to any lands in the United States, the Secretary of the department with authority over such lands. 40 CFR 52.21(b)(24)

(b)(25) High terrrain (25) High terrain means any area having an elevation 900 feet or more above the base of the stack of a

source. 40 CFR 52.21(b)(25)

(b)(26) Low terrain (26) Low terrain means any area other than high terrain. 40 CFR 52.21(b)(26) (b)(27) Indian

Reservation (27) Indian Reservation means any federally recognized reservation established by Treaty, Agreement, Executive Order, or Act of Congress. 40 CFR 52.21(b)(27)

(b)(28) Indian Governing

Body (28) Indian Governing Body means the governing body of any tribe, band, or group of Indians subject tothe jurisdiction of the United States and recognized by the United States as possessing power of selfgovernment. 40 CFR 52.21(b)(28)

(b)(29) VOC (29) Volatile organic compounds (VOC) is as defined in §51.100(s) of this part. 40 CFR 52.21(b)(30) (b)(30) Electric utility

steam generating unit (30) Electric utility steam generating unit 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. 40 CFR 52.21(b)(31)

(b)(31) (31) [Reserved] (b)(32) Replacement unit (32) Replacement unit 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. 40 CFR 52.21(b)(33)

(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. 40 CFR 52.21(b)(33)(i)
(ii) The emissions unit is identical to or functionally equivalent to the replaced emissions unit. 40 CFR 52.21(b)(33)(ii)

(iii) The replacement does not change the basic design parameter(s) (as discussed in paragraph (y)(2) of this section) of the process unit. 40 CFR 52.21(b)(33)(iii) 40 CFR 52.21(b)(23)(i)

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(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. 40 CFR 52.21(b)(33)(iv)

(b)(33) Clean coal

technology (33) Clean coal technology 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. 40 CFR 52.21(b)(34)

(b)(34) Clean coal

technology demonstration project (34) Clean coal technology demonstration project 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. 40 CFR 52.21(b)(35)

(b)(35) Temporary clean

coal technology demonstration project (35) Temporary clean coal technology demonstration project 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 and after the project is terminated. 40 CFR 52.21(b)(36)

(b)(36) Repowering (36)(i) Repowering 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. 40 CFR 52.21(b)(37)(i) - Rule 1714(c)(2), revises the term "Administrator" in 40 CFR 52.21(b)(37)(i) to mean the "Federal Administator" consistent with 51.166.

(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. 40 CFR 52.21(b)(37)(ii)

(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. 40 CFR 52.21(b)(37)(ii)

(b)(37) Reactivation (37) Reactivation of a very clean coal-fired electric utility steam generating unit 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: 40 CFR 52.21(b)(38)

(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; 40 CFR 52.21(b)(38)(i)

(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; 40 CFR 52.21(b)(38)(ii)

(iii) Is equipped with low-NOXburners prior to the time of commencement of operations following reactivation; and 40 CFR 52.21(b)(38)(iii)

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(iv) Is otherwise in compliance with the requirements of the Clean Air Act. 40 CFR 52.21(b)(38)(iv)

(b)(38) Pollution

prevention (38) Pollution prevention 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. 40 CFR 52.21(b)(39)

(b)(39) Significant

emissions (39) Significant emissions increase 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. 40 CFR 52.21(b)(4)

(b)(40) Projected actual

emissions (40)(i) Projected actual emissions 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. 40 CFR 52.21(b)(41)(i)

(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: 40 CFR 52.21(b)(41)(ii)

( a ) 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 40 CFR 52.21(b)(41)(i)(a )

( b ) Shall include fugitive emissions to the extent quantifiable, and emissions associated with startups, shutdowns, and malfunctions; and 40 CFR 52.21(b)(41)(i)(b ) ( c ) 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, 40 CFR 52.21(b)(41)(i)(c )

( d ) In lieu of using the method set out in paragraphs (b)(40)(ii)( a ) through ( c ) 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. 40 CFR 52.21(b)(41)(i)(d )
(b)(41) (41) [Reserved]

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(b)(42) PSD Program (42) Prevention of Significant Deterioration Program (PSD) program 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. 40 CFR 52.21(b)(43) - slightly different wording but still at least as stringent as 51.166 defintion - In addition, Rule 1714(c)(2) revises the term "Administrator" in 40 CFR 52.21(b)(43) to mean the "Federal Administator" consistent with 51.166.

(b)(43) CEMS (43) Continuous emissions monitoring system (CEMS) 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. 40 CFR 52.21(b)(44) -

(b)(44) PEMS (44) Predictive emissions monitoring system (PEMS) 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 2or CO2concentrations), and calculate and record the mass emissions rate (for example, lb/hr) on a continuous basis. 40 CFR 52.21(b)(45)

(b)(45) CPMS (45) Continuous parameter monitoring system (CPMS) 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, O2or CO2concentrations), and to record average operational parameter value(s) on a continuous basis. 40 CFR 52.21(b)(46)

(b)(46) CERMS (46) Continuous emissions rate monitoring system (CERMS) means the total equipment required for the determination and recording of the pollutant mass emissions rate (in terms of mass per unit of time). 40 CFR 52.21(b)(47)

(b)(47) Baseline actual

emissions (47) Baseline actual emissions 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. 40 CFR 52.21(b)(48)

(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. 40 CFR 52.21(b)(48)(i)

( a ) The average rate shall include fugitive emissions to the extent quantifiable, and emissions associated with startups, shutdowns, and malfunctions. 40 CFR 52.21(b)(48)(i)(a ) ( b ) 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. 40 CFR 52.21(b)(48)(i)(b )

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( c ) 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. 40 CFR 52.21(b)(48)(i)(c )

( d ) 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)( b ) of this section. 40 CFR 52.21(b)(48)(i)(d )

(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. 40 CFR 52.21(b)(48)(ii)

( a ) The average rate shall include fugitive emissions to the extent quantifiable, and emissions associated with startups, shutdowns, and malfunctions. 40 CFR 52.21(b)(48)(ii)(a ) ( b ) 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. 40 CFR 52.21(b)(48)(ii)(b )
( c ) 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). 40 CFR 52.21(b)(48)(ii)(c ) - Rule 1714(c)(2) revises the term "Administrator" in 40 CFR 52.21(b)(48)(ii)(c ) to mean the "Federal Administator" consistent with 51.166.

( d ) 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. 40 CFR 52.21(b)(48)(ii)(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 paragraphs (b)(47)(ii)(b) and (c) of this section. 40 CFR 52.21(b)(48)(ii)(e )

(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. 40 CFR 52.21(b)(48)(iii)

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(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. 40 CFR 52.21(b)(48)(iv)

(b)(48) Subject to

regulation (48) Subject to regulation means, for any air pollutant, that the pollutant is subject to either a provision in the Clean Air Act, or a nationally-applicable regulation codified by the Administrator in subchapter C of this chapter, that requires actual control of the quantity of emissions of that pollutant, and that such a control requirement has taken effect and is operative to control, limit or restrict the quantity of emissions of that pollutant released from the regulated activity. Except that: 40 CFR 52.21(b)(49)

(i) Greenhouse gases (GHGs), the air pollutant defined in §86.1818–12(a) of this chapter as the aggregate group of six greenhouse gases: Carbon dioxide, nitrous oxide, methane, hydrofluorocarbons, perfluorocarbons, and sulfur hexafluoride, shall not be subject to regulation except as provided in paragraphs (b)(48)(iv) through (v) of this section. 40 CFR 52.21(b)(49)(i)

(ii) For purposes of paragraphs (b)(48)(iii) through (v) of this section, the term tpy CO 2 equivalent emissions (CO 2 e) shall represent an amount of GHGs emitted, and shall be computed as follows: 40 CFR 52.21(b)(49)(ii)

(a) Multiplying the mass amount of emissions (tpy), for each of the six greenhouse gases in the pollutant GHGs, by the gas's associated global warming potential published at Table A–1 to subpart A of part 98 of this chapter—Global Warming Potentials. For purposes of this paragraph (b)(48)(ii)(a), prior to July 21, 2014, the mass of the greenhouse gas carbon dioxide shall not include carbon dioxide emissions resulting from the combustion or decomposition of non-fossilized and biodegradable 40 CFR 52.21(b)(49)(ii)(a )

( b ) Sum the resultant value from paragraph (b)(48)(ii)( a ) of this section for each gas to compute a tpy CO2e. 40 CFR 52.21(b)(49)(ii)(b ) (iii) The term emissions increase as used in paragraphs (b)(48)(iv) through (v) of this section shall mean that both a significant emissions increase (as calculated using the procedures in (a)(7)(iv) of this section) and a significant net emissions increase (as defined in paragraphs (b)(3) and (b)(23) of this section) occur. For the pollutant GHGs, an emissions increase shall be based on tpy CO 2e, and shall be calculated assuming the pollutant GHGs is a regulated NSR pollutant, and ―significant‖ is defined as 75,000 tpy CO2e instead of applying the value in paragraph (b)(23)(ii) of this section. 40 CFR 52.21(b)(49)(iii)

(iv) Beginning January 2, 2011, the pollutant GHGs is subject to regulation if: 40 CFR 52.21(b)(49)(iv)

( a ) The stationary source is a new major stationary source for a regulated NSR pollutant that is not GHGs, and also will emit or will have the potential to emit 75,000 tpy CO 2e or more; or 40 CFR 52.21(b)(49)(iv)(a )

( b ) The stationary source is an existing major stationary source for a regulated NSR pollutant that is not GHGs, and also will have an emissions increase of a regulated NSR pollutant, and an emissions increase of 75,000 tpy CO2e or more; and, 40 CFR 52.21(b)(49)(iv)(b )

(v) Beginning July 1, 2011, in addition to the provisions in paragraph (b)(48)(iv) of this section, the pollutant GHGs shall also be subject to regulation: 40 CFR 52.21(b)(49)(v)

( a ) At a new stationary source that will emit or have the potential to emit 100,000 tpy CO 2e; or 40 CFR 52.21(b)(49)(v)(a )

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( b ) At an existing stationary source that emits or has the potential to emit 100,000 tpy CO 2e, when such stationary source undertakes a physical change or change in the method of operation that will result in an emissions increase of 75,000 tpy CO2e or more. 40 CFR 52.21(b)(49)(v)(b )
(b)(49) Regulated NSR

pollutant (49) Regulated NSR pollutant, for purposes of this section, means the following: 40 CFR 52.21(b)(50)
(i) Any pollutant for which a national ambient air quality standard has been promulgated and any pollutant identified under this paragraph (b)(49)(i) as a constituent or precursor to such pollutant. Precursors identified by the Administrator for purposes of NSR are the following: 40 CFR 52.21(b)(50)(i) - Rule 1714(c)(2) revises the term "Administrator" in 40 CFR 52.21(b)(50)(i) ( a ) Volatile organic compounds and nitrogen oxides are precursors to ozone in all attainment and unclassifiable areas. 40 CFR 52.21(b)(50)(i)(a ) ( b ) Sulfur dioxide is a precursor to PM 2.5in all attainment and unclassifiable areas. 40 CFR 52.21(b)(50)(i)(b )

( c ) Nitrogen oxides are presumed to be precursors to PM 2.5in all attainment and unclassifiable areas, unless the State demonstrates to the Administrator's satisfaction or EPA demonstrates that emissions of nitrogen oxides from sources in a specific area are not a significant contributor to that area's ambient PM 2.5concentrations. 40 CFR 52.21(b)(50)(i)(c )

( d ) Volatile organic compounds are presumed not to be precursors to PM 2.5in any attainment or unclassifiable area, unless the State demonstrates to the Administrator's satisfaction or EPA demonstrates that emissions of volatile organic compounds from sources in a specific area are a 40 CFR 52.21(b)(50)(i)(d )
(ii) Any pollutant that is subject to any standard promulgated under section 111 of the Act; 40 CFR 52.21(b)(50)(ii)
(iii) Any Class I or II substance subject to a standard promulgated under or established by title VI of the Act; 40 CFR 52.21(b)(50)(iii)
(iv) Any pollutant that otherwise is subject to regulation under the Act as defined in paragraph (b)(48) of this section. 40 CFR 52.21(b)(50)(iv)
(v) Notwithstanding paragraphs (b)(49)(i) through (iv) of this section, the term regulated NSR pollutant shall not include 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, and which have not been delisted pursuant to section 112(b)(3) of the Act, 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. 40 CFR 52.21(b)(50)(v)

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(vi) Particulate matter (PM) emissions, PM 2.5emissions, and PM 10emissions shall include gaseous emissions from a source or activity which condense to form particulate matter at ambient temperatures. On or after January 1, 2011 (or any earlier date established in the upcoming rulemaking codifying test methods), such condensable particulate matter shall be accounted for in applicability determinations and in establishing emissions limitations for PM, PM 2.5and PM 10in PSD permits. Compliance with emissions limitations for PM, PM 2.5and PM 10issued prior to this date shall not be based on condensable particular matter unless required by the terms and conditions of the permit or the applicable implementation plan. Applicability determinations made prior to this date without accounting for condensable particular matter shall not be considered in violation of this section unless the applicable implementation plan required condensable particular matter to be included. 40 CFR 52.21(b)(50)(vi)

(b)(50) Reviewing

authority (50) Reviewing authority 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. 40 CFR 52.21(b)(51) - Rule 1714(c)(2) revises the term "Administrator" in 40 CFR 52.21(b)(51) to mean the "Federal Administator" as consistent with 51.166.

(b)(51) Project (51) Project means a physical change in, or change in method of operation of, an existing major stationary source. 40 CFR 52.21(b)(52)

(b)(52) LAER (52) Lowest achievable emission rate (LAER) is as defined in §51.165(a)(1)(xiii). 40 CFR 52.21(b)(53) (b)(53) Process unit (53)(i) In general, process unit 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.
(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. (iii) For replacement cost purposes, components shared between two or more process units are proportionately allocated based on capacity. (iv) The following list identifies the process units at specific categories of stationary sources.

( a ) 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. 40 CFR 52.21(b)(55) - But excluded from Rule 1714(c)(1). These provisions were stayed indefinitely by the DC Circuit Court on December 24, 2003 and are not needed for a PSD program.

## Attachment 6 Requirements for a SIP Approved PSD Program in 40 CFR 51.166 and How those Requirements are met by South Coast AQMD Rule 1714 Page 20of 53

( b ) 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.
( c ) 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. Note to paragraph (b)(53): 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 Federal Register advising the public of the termination of the stay. (b)(54) Functionally

equivalent component (54) Functionally equivalent component means a component that serves the same purpose as the replaced component.
Note to paragraph (b)(54): 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 Federal Register advising the public of the termination of the stay.

(b)(55) Fixed capital cost (55) Fixed capital cost 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.
Note to paragraph (b)(55): By a court order on December 24, 2003, this paragraph (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 Federal Register advising the public of the termination of the stay.

(b)(56) Total capital

investment (56) Total capital investment 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 Note to paragraph (b)(56): 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 Federal Register advising the public of the termination of the stay. (c ) Ambient air

increments and other measures (c) Ambient air increments and other measures.

(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: See Table in 40 CFR 51.166(c)(1) 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. Paragraph (c)(1) of Rule 1714 excludes this definition, which found in 40 CFR 52.21(c ). This requirement does not apply to GHGs, only pollutants with a NAAQS 40 CFR 52.21(b)(58) - But excluded from Rule 1714(c)(1). These provisions were stayed indefinitely by the DC Circuit Court on December 24, 2003 and 40 CFR 52.21(b)(57) - But excluded from Rule 1714(c)(1). These provisions were stayed indefinitely by the DC Circuit Court on December 24, 2003 and are not needed for a PSD program 40 CFR 52.21(b)(56) - But excluded from Rule 1714(c)(1). These provisions were stayed indefinitely by the DC Circuit Court on December 24, 2003 and are not needed for a PSD program 40 CFR 52.21(b)(55) - But excluded from Rule 1714(c)(1). These provisions were stayed indefinitely by the DC Circuit Court on December 24, 2003 and are not needed for a PSD program.

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(2) Where the State can demonstrate that it has alternative measures in its plan other than maximum allowable increases as defined under paragraph (c)(1) of this section, that satisfy the requirements in sections 166(c) and 166(d) of the Clean Air Act for a regulated NSR pollutant for which the Administrator has established maximum allowable increases pursuant to section 166(a) of the Act, the requirements for maximum allowable increases for that pollutant under paragraph (c)(1) of this section shall not apply upon approval of the plan by the Administrator. The following regulated NSR pollutants are eligible for such treatment:
(i) Nitrogen dioxide. (ii) PM 2.5. (d) Ambient air

ceilings (d) Ambient air ceilings. The plan shall provide that no concentration of a pollutant shall exceed:

(1) The concentration permitted under the national secondary ambient air quality standard, or

(2) The concentration permitted under the national primary ambient air quality standard, whichever concentration is lowest for the pollutant for a period of exposure.

(e) Restrictions on

area classifications (e) Restrictions on area classifications. The plan shall provide that—

(1) All of the following areas which were in existence on August 7, 1977, shall be Class I areas and may not be redesignated: (i) International parks, (ii) National wilderness areas which exceed 5,000 acres in size, (iii) National memorial parks which exceed 5,000 acres in size, and (iv) National parks which exceed 6,000 acres in size. (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. (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. (4) The following areas may be redesignated only as Class I or II: (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
(ii) A national park or national wilderness area established after August 7, 1977, which exceeds 10,000 acres in size. (f) Exclusions from

increment consumption (f) Exclusions from increment consumption.

(1) The plan may provide that the following concentrations shall be excluded in determining compliance with a maximum allowable increase: Not included in 40 CFR 52.21 or Rule 1714. These provisions are not required for a PSD program because 40 CFR 51.166(f)(1) states that the plan "may" provide these exclusions. Paragraphs (2)-(4) only apply if the plan provides for the exclusions in paragraph (1). Paragraph (c)(1) of Rule 1714 excludes this definition, which found in 40 CFR 52.21(e). This requirement does not apply to GHGs, since area classifications are used for pollutants subject to a NAAQS Paragraph (c)(1) of Rule 1714 excludes this definition, which found in 40 CFR 52.21(d). This requirement does apply to GHGs, only pollutants with a NAAQS Paragraph (c)(1) of Rule 1714 excludes this definition, which found in 40 CFR 52.21(c ). This requirement does not apply to GHGs, only pollutants with a NAAQS

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(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; (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;
(iii) Concentrations of particulate matter attributable to the increase in emissions from construction or other temporary emission-related activities of new or modified sources; (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
(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.
(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.
(3) [Reserved] (4) For purposes of excluding concentrations pursuant to paragraph (f)(1)(v) of this section, the Administrator may approve a plan revision that: (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. (ii) Specifies that the time period for excluding certain contributions in accordance with paragraph (f)(4)(i) of this section, is not renewable;
(iii) Allows no emissions increase from a stationary source which would: ( a ) Impact a Class I area or an area where an applicable increment is known to be violated; or

( b ) Cause or contribute to the violation of a national ambient air quality standard; (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. (g) Redesignation (g) Redesignation. 40 CFR 52.21(g) - But, District Rule 1714(c)(1) excludes these provisions regarding redesignations. This requirement does not apply to GHGs, since area classifications are used for pollutants subject to a NAAQS. Not included in 40 CFR 52.21 or Rule 1714. These provisions are not required for a PSD program because 40 CFR 51.166(f)(1) states that the plan "may" provide these exclusions. Paragraphs (2)-(4) only apply if the plan provides for the exclusions in paragraph (1).

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(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 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.
(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: Provided, That: (i) At least one public hearing has been held in accordance with procedures established in §51.102.
(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;
(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; (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
(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.
(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— (i) The redesignation would meet the requirements of provisions established in accordance with paragraph (g)(2) of this section; (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;

(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 40 CFR 52.21(g) - But, District Rule 1714(c)(1) excludes these provisions regarding redesignations. This requirement does not apply to GHGs, since area classifications are used for pollutants subject to a NAAQS.

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(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.
(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: Provided, That: (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 (ii) Such redesignation is proposed after consultation with the State(s) in which the Indian Reservation is located and which border the Indian Reservation. (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.
(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.
(h) Stack heights (h) Stack heights. 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—
(1) So much of a stack height, not in existence before December 31, 1970, as exceeds good engineering practice, or (2) Any other dispersion technique not implemented before then.

(i) Exemptions (i) Exemptions. 40 CFR 52.21(i) (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: 40 CFR 52.21(i)(1)

(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 40 CFR 52.21(i)(1)(vi)
(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 of the following categories:
( a ) Coal cleaning plants (with thermal dryers); ( b ) Kraft pulp mills; ( c ) Portland cement plants; ( d ) Primary zinc smelters; 40 CFR 52.21(g) - But, District Rule 1714(c)(1) excludes these provisions regarding redesignations. This requirement does not apply to GHGs, since area classifications are used for pollutants subject to a NAAQS.

40 CFR 52.21(i)(1)(vii) Paragraph (c)(1) of Rule 1714 excludes this definition, which found in 40 CFR 52.21(h). These requirements on stack heights do not pertain to GHGs since GHG emissions are not modeled.

## Attachment 6 Requirements for a SIP Approved PSD Program in 40 CFR 51.166 and How those Requirements are met by South Coast AQMD Rule 1714 Page 25of 53

( e ) Iron and steel mills; ( f ) Primary aluminum ore reduction plants; ( g ) Primary copper smelters; ( h ) Municipal incinerators capable of charging more than 250 tons of refuse per day; ( i ) Hydrofluoric, sulfuric, or nitric acid plants; ( j ) Petroleum refineries; ( k ) Lime plants; ( l ) Phosphate rock processing plants; ( m ) Coke oven batteries; ( n ) Sulfur recovery plants; ( o ) Carbon black plants (furnace process); ( p ) Primary lead smelters; ( q ) Fuel conversion plants; ( r ) Sintering plants; ( s ) Secondary metal production plants; ( t ) Chemical process plants—The term chemical processing plant shall not include ethanol production facilities that produce ethanol by natural fermentation included in NAICS codes 325193 or 312140; ( u ) Fossil-fuel boilers (or combination thereof) totaling more than 250 million British thermal units per hour heat input; ( v ) Petroleum storage and transfer units with a total storage capacity exceeding 300,000 barrels;

( w ) Taconite ore processing plants; ( x ) Glass fiber processing plants; ( y ) Charcoal production plants; ( z ) Fossil fuel-fired steam electric plants of more than 250 million British thermal units per hour heat input; ( aa ) Any other stationary source category which, as of August 7, 1980, is being regulated under section 111 or 112 of the Act; or (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: 40 CFR 52.21(i)(1)(viii)

( a ) The source proposes to relocate and emissions of the source at the new location would be temporary; and 40 CFR 52.21(i)(1)(viii)(a )

( b ) The emissions from the source would not exceed its allowable emissions; and 40 CFR 52.21(i)(1)(viii)(b ) 40 CFR 52.21(i)(1)(vii)

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( c ) The emissions from the source would impact no Class I area and no area where an applicable increment is known to be violated; and 40 CFR 52.21(i)(1)(viii)(c ) ( d ) 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. 40 CFR 52.21(i)(1)(viii)(d )

(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. 40 CFR 52.21(i)(2)

(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. 40 CFR 52.21(i)(3)

(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. 40 CFR 52.21(i)(4)

(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: 40 CFR 52.21(i)(5)

(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: ( a ) Carbon monoxide—575 ug/m 3, 8-hour average;

( b ) Nitrogen dioxide—14 ug/m 3, annual average; ( c ) PM 2.5–4 μg/m 3, 24-hour average; ( d ) PM 10–10 μg/m 3, 24-hour average; ( e ) Sulfur dioxide—13 ug/m 3, 24-hour average; ( f ) Ozone; 1

1No de minimis 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 ( g ) Lead—0.1 μg/m 3, 3-month average. ( h ) Fluorides—0.25 μg/m 3, 24-hour average; ( i ) Total reduced sulfur—10 μg/m 3, 1-hour average

( j ) Hydrogen sulfide—0.2 μg/m 3, 1-hour average; ( k ) Reduced sulfur compounds—10 μg/m 3, 1-hour average; or 40 CFR 52.21(i)(5)(i)

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(ii) The concentrations of the pollutant in the area that the source or modification would affect are less than the concentrations listed in paragraph (i)(5)(i) of this section; or 40 CFR 52.21(i)(5)(ii)
(iii) The pollutant is not listed in paragraph (i)(5)(i) of this section. 40 CFR 52.21(i)(5)(iii) (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.
(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 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.
(8) The plan may provide that the permitting requirements equivalent to those contained in paragraph (k)(1)(ii) of this section do not apply to a stationary source or modification with respect to any maximum allowable increase for nitrogen oxides if the owner or operator of the source or modification submitted an application for a permit under the applicable permit program approved or promulgated under the Act before the provisions embodying the maximum allowable increase took effect as part of the plan and the permitting authority subsequently determined that the application as submitted before that date was complete. 40 CFR 52.21(i)(9)

(9) The plan may provide that the permitting requirements equivalent to those contained in paragraph (k)(1)(ii) of this section shall not apply to a stationary source or modification with respect to any maximum allowable increase for PM–10 if (i) the owner or operator of the source or modification submitted an application for a permit under the applicable permit program approved under the Act before the provisions embodying the maximum allowable increases for PM–10 took effect as part of the plan, and (ii) the permitting authority subsequently determined that the application as submitted before that date was complete. Instead, the applicable requirements equivalent to paragraph (k)(1)(ii) shall apply with respect to the maximum allowable increases for TSP as in effect on the date the application was submitted. 40 CFR 52.21(i)(10)

(j) Control

technology review (j) Control technology review. The plan shall provide that: 40 CFR 52.21(j)

(1) A major stationary source or major modification shall meet each applicable emissions limitation under the State Implementation Plan and each applicable emission standards and standard of performance under 40 CFR parts 60 and 61. 40 CFR 52.21

(2) A new major stationary source shall apply best available control technology for each a regulated NSR pollutant that it would have the potential to emit in significant amounts. 40 CFR 52.21
(3) A major modification shall apply best available control technology for each a regulated NSR pollutant for which it would be a significant net emissions increase at the source. This requirement applies to each proposed emissions unit at which a net emissions increase in the pollutant would occur as a result of a physical change or change in the method of operation in the unit. 40 CFR 52.21 District Rule 1714(c)(1) excludes the related provisions in 40 CFR 52.21(i)(1)(i-v, ix-x) and 40 CFR 52.21(i)(6-8). A plan "may" provide for these exemptions.

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(4) For phased construction projects, the determination of best available control technology shall be reviewed and modified as appropriate at the least reasonable time which occurs no later than 18 months prior to commencement of construction of each independent phase of the project. At such time, the owner or operator of the applicable stationary source may be required to demonstrate the adequacy of any previous determination of best available control technology for the source. 40 CFR 52.21

(k) Source impact

analysis (k) Source impact analysis

— (1) Required demonstration. The plan shall provide that the owner or operator of the proposed source or modification shall demonstrate that allowable emission increases from the proposed source or modification, in conjunction with all other applicable emissions increases or reduction (including secondary emissions), would not cause or contribute to air pollution in violation of:
(i) Any national ambient air quality standard in any air quality control region; or (ii) Any applicable maximum allowable increase over the baseline concentration in any area.

(2) Significant impact levels. The plan may provide that, for purposes of PM 2.5, the demonstration required in paragraph (k)(1) of this section is deemed to have been made if the emissions increase from the new stationary source alone or from the modification alone would cause, in all areas, air quality impacts less than the following amounts: See Table 2 below. (l) Air quality models (l) Air quality models. The plan shall provide for procedures which specify that—

(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). (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.
(m) Air quality

analysis (m) Air quality analysis

—
(1) Preapplication analysis. (i) The plan shall provide that any application for a permit under regulations approved pursuant to this section shall contain an analysis of ambient air quality in the area that the major stationary source or major modification would affect for each of the following pollutants:

( a ) For the source, each pollutant that it would have the potential to emit in a significant amount;

( b ) For the modification, each pollutant for which it would result in a significant net emissions increase. District Rule 1714(c)(1) excludes the related provisions in 40 CFR 52.21(k). The source impact analysis does not apply to GHGs.

District Rule 1714(c)(1) excludes the related provisions in 40 CFR 52.21(l) because GHG emissions are not modeled.

District Rule 1714(c)(1) excludes the related provisions in 40 CFR 52.21(m) because GHG emissions are not subject to the air quality analysis.

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(ii) The plan shall provide that, with respect to any such pollutant for which no National Ambient Air Quality Standard exists, the analysis shall contain such air quality monitoring data as the reviewing authority determines is necessary to assess ambient air quality for that pollutant in any area that the emissions of that pollutant would affect. (iii) The plan shall provide that with respect to any such pollutant (other than nonmethane hydrocarbons) for which such a standard does exist, the analysis shall contain continuous air quality monitoring data gathered for purposes of determining whether emissions of that pollutant would cause or contribute to a violation of the standard or any maxiumum allowable increase.
(iv) The plan shall provide that, in general, the continuous air monitoring data that is required shall have been gathered over a period of one year and shall represent the year preceding receipt of the application, except that, if the reviewing authority determines that a complete and adequate analysis can be accomplished with monitoring data gathered over a period shorter than one year (but not to be less than four months), the data that is required shall have been gathered over at least that shorter period.
(v) The plan may provide that the owner or operator of a proposed major stationary source or major modification of volatile organic compounds who satisfies all conditions of 40 CFR part 51 appendix S, section IV may provide postapproval monitoring data for ozone in lieu of providing preconstruction data as required under paragraph (m)(1) of this section.
(2) Post-construction monitoring. The plan shall provide that the owner or operator of a major stationary source or major modification shall, after construction of the stationary source or modification, conduct such ambient monitoring as the reviewing authority determines is necessary to determine the effect emissions from the stationary source or modification may have, or are having, on air quality in any area.
(3) Operation of monitoring stations. The plan shall provide that the owner or operator of a major stationary source or major modification shall meet the requirements of appendix B to part 58 of this chapter during the operation of monitoring stations for purposes of satisfying paragraph (m) of this section. (n) Source

information (n) Source information. 40 CFR 52.21(n)
(1) The plan shall provide that the owner or operator of a proposed source or modification shall submit all information necessary to perform any analysis or make any determination required under procedures established in accordance with this section. 40 CFR 52.21(n)

(2) The plan may provide that such information shall include: 40 CFR 52.21(n)(1) (i) A description of the nature, location, design capacity, and typical operating schedule of the source or modification, including specifications and drawings showing its design and plant layout; 40 CFR 52.21(n)(1)(i)

(ii) A detailed schedule for construction of the source or modification; 40 CFR 52.21(n)(1)(ii)

(iii) A detailed description as to what system of continuous emission reduction is planned by the source or modification, emission estimates, and any other information as necessary to determine that best available control technology as applicable would be applied; 40 CFR 52.21(n)(1)(iii)

(3) The plan shall provide that upon request of the State, the owner or operator shall also provide information on: 40 CFR 52.21(n)(2)
(i) The air quality impact of the source or modification, including meteorological and topographical data necessary to estimate such impact; and 40 CFR 52.21(n)(2)(i) District Rule 1714(c)(1) excludes the related provisions in 40 CFR 52.21(m) because GHG emissions are not subject to the air quality analysis.

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(ii) The air quality impacts and the nature and extent of any or all general commercial, residential, industrial, and other growth which has occurred since August 7, 1977, in the area the source or modification would affect. 40 CFR 52.21(n)(2)(ii)

(o) Additional impact

analyses (o) Additional impact analyses. The plan shall provide that—

(1) The owner or operator shall provide an analysis of the impairment to visibility, soils, and vegetation that would occur as a result of the source or modification and general commercial, residential, industrial, and other growth associated with the source or modification. The owner or operator need not provide an analysis of the impact on vegetation having no significant commercial or recreational value.
(2) The owner or operator shall provide an analysis of the air quality impact projected for the area as a result of general commercial, residential, industrial, and other growth associated with the source or modification. (p) Sources impacting

Federal Class I

areas (p) Sources impacting Federal Class I areas—additional requirements

—

(1) Notice to EPA. The plan shall provide that the reviewing authority shall transmit to the Administrator a copy of each permit application relating to a major stationary source or major modification and provide notice to the Administrator of every action related to the consideration of such permit. See the TSD for this rulemaking for additioal information regarding this requirement, which is met to a certain extent but the District has agreed to revise for clarifty the next timr Rule 1714 is open for revisions. (2) Federal Land Manager. The Federal Land Manager and the Federal official charged with direct responsibility for management of Class I lands have an affirmative responsibility to protect the air quality related values (including visibility) of any such lands and to consider, in consultation with the Administrator, whether a proposed source or modification would have an adverse impact on such values.
(3) Denial—impact on air quality related values. The plan shall provide a mechanism whereby a Federal Land Manager of any such lands may present to the State, after the reviewing authority's preliminary determination required under procedures developed in accordance with paragraph (r) of this section, a demonstration that the emissions from the proposed source or modification would have an adverse impact on the air quality-related values (including visibility) of any Federal mandatory Class I lands, notwithstanding that the change in air quality resulting from emissions from such source or modification would not cause or contribute to concentrations which would exceed the maximum allowable increases for a Class I area. If the State concurs with such demonstration, the reviewing authority shall not issue the permit. 40 CFR 52.21(o) - District Rule 1714(c)(1) excludes the related provisions in 40 CFR 52.21(o) because additional air impacts are associated with NAAQS pollutants.

District Rule 1714(c)(1) excludes the related provisions in 40 CFR 52.21(p) that pertain to sources impacting Class I areas, since such analyses do not apply to GHGs.

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(4) Class I Variances. The plan may provide that the owner or operator of a proposed source or modification may demonstrate to the Federal Land Manager that the emissions from such source would have no adverse impact on the air quality related values of such lands (including visibility), notwithstanding that the change in air quality resulting from emissions from such source or modification would cause or contribute to concentrations which would exceed the maximum allowable increases for a Class I area. If the Federal land manager concurs with such demonstration and so certifies to the State, the reviewing authority may: Provided, That applicable requirements are otherwise met, issue the permit with such emission limitations as may be necessary to assure that emissions of sulfur dioxide, PM 2.5, PM 10, and nitrogen oxides would not exceed the following maximum allowable increases over minor source baseline concentration for such pollutants:
See Table 3 below. (5) Sulfur dioxide variance by Governor with Federal Land Manager's concurrence. The plan may provide that— (i) The owner or operator of a proposed source or modification which cannot be approved under procedures developed pursuant to paragraph (q)(4) of this section may demonstrate to the Governor that the source or modification cannot be constructed by reason of any maximum allowable increase for sulfur dioxide for periods of twenty-four hours or less applicable to any Class I area and, in the case of Federal mandatory Class I areas, that a variance under this clause would not adversely affect the air quality related values of the area (including visibility);
(ii) The Governor, after consideration of the Federal Land Manager's recommendation (if any) and subject to his concurrence, may grant, after notice and an opportunity for a public hearing, a variance from such maximum allowable increase; and (iii) If such variance is granted, the reviewing authority may issue a permit to such source or modification in accordance with provisions developed pursuant to paragraph (q)(7) of this section: Provided, That the applicable requirements of the plan are otherwise met.
(6) Variance by the Governor with the President's concurrence. The plan may provide that—
(i) The recommendations of the Governor and the Federal Land Manager shall be transferred to the President in any case where the Governor recommends a variance in which the Federal Land Manager does not concur; (ii) The President may approve the Governor's recommendation if he finds that such variance is in the national interest; and (iii) If such a variance is approved, the reviewing authority may issue a permit in accordance with provisions developed pursuant to the requirements of paragraph (q)(7) of this section: Provided, That the applicable requirements of the plan are otherwise met.
(7) Emission limitations for Presidential or gubernatorial variance. The plan shall provide that in the case of a permit issued under procedures developed pursuant to paragraph (q) (5) or (6) of this section, the source or modification shall comply with emission limitations as may be necessary to assure that emissions of sulfur dioxide from the source or modification would not (during any day on which the otherwise applicable maximum allowable increases are exceeded) cause or contribute to concentrations which would exceed the following maximum allowable increases over the baseline concentration and to assure that such emissions would not cause or contribute to concentrations which exceed the otherwise applicable maximum allowable increases for periods of exposure of 24 hours or less for more than 18 days, not necessarily consecutive, during any annual period: District Rule 1714(c)(1) excludes the related provisions in 40 CFR 52.21(p) that pertain to sources impacting Class I areas, since such analyses do not apply to GHGs.

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See Table 4 below. (q) Public

participation (q) Public participation. The plan shall provide that— District Rule 1714(c)(1) excludes the public participation requirements in 40 CFR 52.21(q) and adopts its own public participation requirements in Rule 1714(e).

(1) The reviewing authority shall notify all applicants within a specified time period as to the completeness of the application or any deficiency in the application or information submitted. In the event of such a deficiency, the date of receipt of the application shall be the date on which the reviewing authority received all required information. This requirement is metby an existing SIPapproved rule that applies to all permits that are issued by the Distrit - Rule 220(b).
(2) Within one year after receipt of a complete application, the reviewing authority shall: This requirement is metby an existing SIPapproved rule that applies to all permits that are issued by the Distrit - Rule 220(d). Rule 220(d) requires the final action to be taken within 180 days of a complete application

(i) Make a preliminary determination whether construction should be approved, approved with conditions, or disapproved. Rule 1714(e)(1)

(ii) Make available in at least one location in each region in which the proposed source would be constructed a copy of all materials the applicant submitted, a copy of the preliminary determination, and a copy or summary of other materials, if any, considered in making the preliminary determination. Rule 1714(e)(2)

(iii) Notify the public, by advertisement in a newspaper of general circulation in each region in which the proposed source would be constructed, of the application, the preliminary determination, the degree of increment consumption that is expected from the source or modification, and of the opportunity for comment at a public hearing as well as written public comment. Rule 1714(e)(3)

(iv) Send a copy of the notice of public comment to the applicant, the Administrator and to officials and agencies having cognizance over the location where the proposed construction would occur as follows: Any other State or local air pollution control agencies, the chief executives of the city and county where the source would be located; any comprehensive regional land use planning agency, and any State, Federal Land Manager, or Indian Governing body whose lands may be affected by emissions from the source or modification. Rule 1714(e)(4) District Rule 1714(c)(1) excludes the related provisions in 40 CFR 52.21(p) that pertain to sources impacting Class I areas, since such analyses do not apply to GHGs.

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(v) Provide opportunity for a public hearing for interested persons to appear and submit written or oral comments on the air quality impact of the source, alternatives to it, the control technology required, and other appropriate considerations. Rule 1714(e)(5)

(vi) Consider all written comments submitted within a time specified in the notice of public comment and all comments received at any public hearing(s) in making a final decision on the approvability of the application. The reviewing authority shall make all comments available for public inspection in the same Rule 1714(e)(6)

(vii) Make a final determination whether construction should be approved, approved with conditions, or disapproved. Rule 1714(e)(7)
(viii) Notify the applicant in writing of the final determination and make such notification available for public inspection at the same location where the reviewing authority made available preconstruction information and public comments relating to the source. Rule 1714(e)(8)

(r ) Source obligation (r) Source obligation. 40 CFR 52.21(r )

(1) The plan shall include enforceable procedures to provide that approval to construct shall not relieve any owner or operator of the responsibility to comply fully with applicable provisions of the plan and any other requirements under local, State or Federal law. 40 CFR 52.21(r)(1-3)

(2) The plan shall provide that 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 enforceable 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 paragraphs (j) through (s) of this section shall apply to the source or modification as though construction had not yet commenced on the source or modification. 40 CFR 52.21(r)(4)

(3)–(5) [Reserved] (6) Each plan shall provide that, except as otherwise provided in paragraph (r)(6)(vi) of this section, the following specific provisions apply with respect to any regulated NSR pollutant emitted from projects at existing emissions units at a major stationary source (other than projects at a source with a PAL) in circumstances where there is a reasonable possibility, within the meaning of paragraph (r)(6)(vi) of this section, that a project that is not a part of a major modification may result in a significant emissions increase of such pollutant, and the owner or operator elects to use the method specified in paragraphs (b)(40)(ii)( a ) through ( c ) 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 (r)(6)(i) through (vi) of this section. 40 CFR 52.21(r)(6)

(i) Before beginning actual construction of the project, the owner or operator shall document and maintain a record of the following information: 40 CFR 52.21(r)(6)(i)

( a ) A description of the project; 40 CFR 52.21(r)(6)(i)(a )

( b ) Identification of the emissions unit(s) whose emissions of a regulated NSR pollutant could be affected by the project; and 40 CFR 52.21(r)(6)(i)(b )

( 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 (b)(40)(ii)( c ) of this section and an explanation for why such amount was excluded, and any netting calculations, if applicable. 40 CFR 52.21(r)(6)(i)(c )

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(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 (r)(6)(i) of this section to the reviewing authority. Nothing in this paragraph (r)(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. 40 CFR 52.21(r)(6)(ii)

(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 unit identified in paragraph (r)(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. 40 CFR 52.21(r)(6)(iii)

(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 (r)(6)(iii) of this section setting out the unit's annual emissions during the calendar year that preceded submission of the report. 40 CFR 52.21(r)(6)(iv)

(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 (r)(6)(i) of this section, exceed the baseline actual emissions (as documented and maintained pursuant to paragraph (r)(6)(i)( c ) of this section) by a significant amount (as defined in paragraph (b)(23) of this section) for that regulated NSR pollutant, and if such emissions differ from the preconstruction projection as documented and maintained pursuant to paragraph (r)(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: 40 CFR 52.21(r)(6)(v)

( a ) The name, address and telephone number of the major stationary source; 40 CFR 52.21(r)(6)(v)(a )

( b ) The annual emissions as calculated pursuant to paragraph (r)(6)(iii) of this section; and 40 CFR 52.21(r)(6)(v)(b )

( c ) Any other information that the owner or operator wishes to include in the report (e.g., an explanation as to why the emissions differ from the preconstruction projection). 40 CFR 52.21(r)(6)(v)(c )

(vi) A ―reasonable possibility‖ under paragraph (r)(6) of this section occurs when the owner or operator calculates the project to result in either: 40 CFR 52.21(r)(6)(vi)

( a ) A projected actual emissions increase of at least 50 percent of the amount that is a ―significant emissions increase,‖ as defined under paragraph (b)(39) of this section (without reference to the amount that is a significant net emissions increase), for the regulated NSR pollutant; or 40 CFR 52.21(r)(6)(vi)(a )

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( b ) A projected actual emissions increase that, added to the amount of emissions excluded under paragraph (b)(40)(ii)( c ), sums to at least 50 percent of the amount that is a ―significant emissions increase,‖ as defined under paragraph (b)(39) of this section (without reference to the amount that is a significant net emissions increase), for the regulated NSR pollutant. For a project for which a reasonable possibility occurs only within the meaning of paragraph (r)(6)(vi)( b ) of this section, and not also within the meaning of paragraph (a)(6)(vi)( a ) of this section, then provisions (a)(6)(ii) through (v) do not apply to the project. 40 CFR 52.21(r)(6)(vi)(b )

(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 (r)(6) of this section available for review upon 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. 40 CFR 52.21(r)(7)

(s) Innovative control

technology (s) Innovative control technology.

(1) The plan may provide that an owner or operator of a proposed major stationary source or major modification may request the reviewing authority to approve a system of innovative control technology.
(2) The plan may provide that the reviewing authority may, with the consent of the Governor(s) of other affected State(s), determine that the source or modification may employ a system of innovative control technology, if: (i) The proposed control system would not cause or contribute to an unreasonable risk to public health, welfare, or safety in its operation or function; (ii) The owner or operator agrees to achieve a level of continuous emissions reduction equivalent to that which would have been required under paragraph (j)(2) of this section, by a date specified by the reviewing authority. Such date shall not be later than 4 years from the time of startup or 7 years from permit issuance; (iii) The source or modification would meet the requirements equivalent to those in paragraphs (j) and (k) of this section, based on the emissions rate that the stationary source employing the system of innovative control technology would be required to meet on the date specified by the reviewing authority; (iv) The source or modification would not before the date specified by the reviewing authority:

( a ) Cause or contribute to any violation of an applicable national ambient air quality standard; or

( b ) Impact any area where an applicable increment is known to be violated; (v) All other applicable requirements including those for public participation have been met.
(vi) The provisions of paragraph (p) of this section (relating to Class I areas) have been satisfied with respect to all periods during the life of the source or modification. (3) The plan shall provide that the reviewing authority shall withdraw any approval to employ a system of innovative control technology made under this section, if: (i) The proposed system fails by the specified date to achieve the required continuous emissions reduction rate; or (ii) The proposed system fails before the specified date so as to contribute to an unreasonable risk to public health, welfare, or safety; or (iii) The reviewing authority decides at any time that the proposed system is unlikely to achieve the required level of control or to protect the public health, welfare, or safety. Rule 1714(c)(1) excludes these related provisions in 40 CFR 52.21(v). 51.166 statest that the plan "may" provide these provisions.

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(4) The plan may provide that if a source or modification fails to meet the required level of continuous emissions reduction within the specified time period, or if the approval is withdrawn in accordance with paragraph (s)(3) of this section, the reviewing authority may allow the source or modification up to an additional 3 years to meet the requirement for the application of best available control technology through use of a demonstrated system of control.
(t)-(v) (t)–(v) [Reserved] (w) Actuals PALs (w) Actuals PALs. The plan shall provide for PALs according to the provisions in paragraphs (w)(1) through (15) of this section. (1) Applicability. (i) The reviewing authority may approve the use of an actuals PAL for any existing major stationary source if the PAL meets the requirements in paragraphs (w)(1) through (15) of this section. The term ―PAL‖ shall mean ―actuals PAL‖ throughout paragraph (w) of this section.
(ii) 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 (w)(1) through (15) of this section, and complies with the PAL permit:
( a ) Is not a major modification for the PAL pollutant; ( b ) Does not have to be approved through the plan's major NSR program; and ( c ) Is not subject to the provisions in paragraph (r)(2) of this section (restrictions on relaxing enforceable emission limitations that the major stationary source used to avoid applicability of the major NSR program). (iii) Except as provided under paragraph (w)(1)(ii)(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.
(2) Definitions. The plan shall use the definitions in paragraphs (w)(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 (w)(1) through (15) of this section. When a term is not defined in these paragraphs, it shall have the meaning given in paragraph (b) of this section or in the Act.
(i) Actuals PAL for a major stationary source means a PAL based on the baseline actual emissions (as defined in paragraph (b)(47) of this section) of all emissions units (as defined in paragraph (b)(7) of this section) at the source, that emit or have the potential to emit the PAL pollutant.
(ii) Allowable emissions means ―allowable emissions‖ as defined in paragraph (b)(16) of this section, except as this definition is modified according to paragraphs (w)(2)(ii)( a ) and ( b ) of this section.
( 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.
( b ) An emissions unit's potential to emit shall be determined using the definition in paragraph (b)(4) of this section, except that the words ―or enforceable as a practical matter‖ should be added after ―federally enforceable.‖ Rule 1714(c)(1) exludes these provisions from 40 CFR 52.21(aa). Without these provisions Rule 1714 is more stringent or at least as stringent as the requirements of 51.166 Rule 1714(c)(1) excludes these related provisions in 40 CFR 52.21(v). 51.166 statest that the plan "may" provide these provisions.

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(iii) Small emissions unit 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 (b)(23) of this section or in the Act, whichever is lower. (iv) Major emissions unit means: ( 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 ( 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.
(v) Plantwide applicability limitation (PAL) means an emission limitation expressed in tons per year, fora pollutant at a major stationary source, that is enforceable as a practical matter and established sourcewide in accordance with paragraphs (w)(1) through (15) of this section.
(vi) PAL effective date 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 that is part of the PAL major modification becomes operational and begins to emit the PAL pollutant.
(vii) PAL effective period means the period beginning with the PAL effective date and ending 10 years later. (viii) PAL major modification means, notwithstanding paragraphs (b)(2) and (b)(3) 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. (ix) PAL permit 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. (x) PAL pollutant means the pollutant for which a PAL is established at a major stationary source.

(xi) Significant emissions unit 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 paragraph (b)(23) 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 (w)(2)(iv) of this section.
(3) Permit application requirements. As part of a permit application requesting a PAL, the owner or operator of a major stationary source shall submit the following information in paragraphs (w)(3)(i) through (iii) of this section to the reviewing authority for approval. (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.
(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. Rule 1714(c)(1) exludes these provisions from 40 CFR 52.21(aa). Without these provisions Rule 1714 is more stringent or at least as stringent as the requirements of 51.166

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(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 (w)(13)(i) of this section.
(4) General requirements for establishing PALs. (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 (w)(4)(i)(a) through (g) of this section are met.
( 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.
( b ) The PAL shall be established in a PAL permit that meets the public participation requirements in paragraph (w)(5) of this section. ( c ) The PAL permit shall contain all the requirements of paragraph (w)(7) of this section.

( 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.
( e ) Each PAL shall regulate emissions of only one pollutant. ( f ) Each PAL shall have a PAL effective period of 10 years. ( 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 (w)(12) through (14) of this section for each emissions unit under the PAL through the PAL effective period.
(ii) At no time (during or after the PAL effective period) are emissions reductions of a PAL pollutant that occur during the PAL effective period creditable as decreases for purposes of offsets under §51.165(a)(3)(ii) of this chapter 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.
(5) Public participation requirements for PALs. 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.
(6) Setting the 10-year actuals PAL level. Rule 1714(c)(1) exludes these provisions from 40 CFR 52.21(aa). Without these provisions Rule 1714 is more stringent or at least as stringent as the requirements of 51.166

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(i) Except as provided in paragraph (w)(6)(ii) of this section, the plan shall provide that the actuals PAL level for a major stationary source shall be established as the sum of the baseline actual emissions (as defined in paragraph (b)(47) 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 (b)(23) 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 NOXto a (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 (w)(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. (7) Contents of the PAL permit. The plan shall require that the PAL permit contain, at a minimum, the information in paragraphs (w)(7)(i) through (x) of this section. (i) The PAL pollutant and the applicable source-wide emission limitation in tons per year. (ii) The PAL permit effective date and the expiration date of the PAL (PAL effective period).
(iii) Specification in the PAL permit that if a major stationary source owner or operator applies to renew a PAL in accordance with paragraph (w)(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.
(iv) A requirement that emission calculations for compliance purposes include emissions from startups, shutdowns and malfunctions. (v) A requirement that, once the PAL expires, the major stationary source is subject to the requirements of paragraph (w)(9) of this section. (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 (w)(3)(i) of this section.
(vii) A requirement that the major stationary source owner or operator monitor all emissions units in accordance with the provisions under paragraph (w)(13) of this section.
(viii) A requirement to retain the records required under paragraph (w)(13) of this section on site. Such records may be retained in an electronic format. (ix) A requirement to submit the reports required under paragraph (w)(14) of this section by the required deadlines. (x) Any other requirements that the reviewing authority deems necessary to implement and enforce the PAL. (8) PAL effective period and reopening of the PAL permit. The plan shall require the information in paragraphs (w)(8)(i) and (ii) of this section. (i) PAL effective period. The reviewing authority shall specify a PAL effective period of 10 years. Rule 1714(c)(1) exludes these provisions from 40 CFR 52.21(aa). Without these provisions Rule 1714 is more stringent or at least as stringent as the requirements of 51.166

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(ii) Reopening of the PAL permit. ( a ) During the PAL effective period, the plan shall require the reviewing authority to reopen the PAL permit to: ( 1 ) Correct typographical/calculation errors made in setting the PAL or reflect a more accurate determination of emissions used to establish the PAL; ( 2 ) Reduce the PAL if the owner or operator of the major stationary source creates creditable emissions reductions for use as offsets under §51.165(a)(3)(ii) of this chapter; and
( 3 ) Revise the PAL to reflect an increase in the PAL as provided under paragraph (w)(11) of this section. ( b ) The plan shall provide the reviewing authority discretion to reopen the PAL permit for the following: ( 1 ) Reduce the PAL to reflect newly applicable Federal requirements (for example, NSPS) with compliance dates after the PAL effective date; ( 2 ) 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; and
( 3 ) 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 AQRV 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.
( c ) Except for the permit reopening in paragraph (w)(8)(ii)( a )( 1 ) of this section for the correction of typographical/calculation errors that do not increase the PAL level, all reopenings shall be carried out in accordance with the public participation requirements of paragraph (w)(5) of this section. (9) Expiration of a PAL. Any PAL that is not renewed in accordance with the procedures in paragraph (w)(10) of this section shall expire at the end of the PAL effective period, and the requirements in paragraphs (w)(9)(i) through (v) of this section shall apply. (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 (w)(9)(i)( a ) and ( b ) of this section. ( a ) Within the time frame specified for PAL renewals in paragraph (w)(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 (w)(10)(v) of this section, such distribution shall be made as if the PAL had been adjusted.

( 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.
(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. Rule 1714(c)(1) exludes these provisions from 40 CFR 52.21(aa). Without these provisions Rule 1714 is more stringent or at least as stringent as the requirements of 51.166

## Attachment 6 Requirements for a SIP Approved PSD Program in 40 CFR 51.166 and How those Requirements are met by South Coast AQMD Rule 1714 Page 41of 53

(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 (w)(9)(i)( b ) 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. (iv) Any physical change or change in the method of operation at the major stationary source will be subject to major NSR requirements if such change meets the definition of major modification in paragraph (b)(2) of this section. (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 (r)(2) of this section, but were eliminated by the PAL in accordance with the provisions in paragraph (w)(1)(ii)(c) of this section.
(10) Renewal of a PAL. (i) The reviewing authority shall follow the procedures specified in paragraph (w)(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. (ii) Application deadline. 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.
(iii) Application requirements. The application to renew a PAL permit shall contain the information required in paragraphs (w)(10)(iii) ( a ) through ( d ) of this section. ( a ) The information required in paragraphs (w)(3)(i) through (iii) of this section. ( b ) A proposed PAL level. ( c ) The sum of the potential to emit of all emissions units under the PAL (with supporting documentation). ( d ) Any other information the owner or operator wishes the reviewing authority to consider in determining the appropriate level for renewing the PAL. (iv) PAL adjustment. In determining whether and how to adjust the PAL, the reviewing authority shall consider the options outlined in paragraphs (w)(10)(iv) ( a ) and ( b ) of this section. However, in no case may any such adjustment fail to comply with paragraph (w)(10)(iv)( c ) of this section.
( a ) If the emissions level calculated in accordance with paragraph (w)(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 (w)(10)(iv)( b ) of this section; or Rule 1714(c)(1) exludes these provisions from 40 CFR 52.21(aa). Without these provisions Rule 1714 is more stringent or at least as stringent as the requirements of 51.166

## Attachment 6 Requirements for a SIP Approved PSD Program in 40 CFR 51.166 and How those Requirements are met by South Coast AQMD Rule 1714 Page 42of 53

( 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.
( c ) Notwithstanding paragraphs (w)(10)(iv) ( a ) and ( b ) of this section: ( 1 ) 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
( 2 ) 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 (w)(11) of this section (increasing a PAL). (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. (11) Increasing a PAL during the PAL effective period. (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 (w)(11)(i) ( a ) through ( d ) of this section. ( 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) contributing to the increase in emissions so as to cause the major stationary source's emissions to equal or exceed its PAL. ( 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. ( c ) The owner or operator obtains a major NSR permit for all emissions unit(s) identified in paragraph (w)(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 major NSR process (for example, BACT), even though they have also become subject to the PAL or continue to be subject to the PAL.
( 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. Rule 1714(c)(1) exludes these provisions from 40 CFR 52.21(aa). Without these provisions Rule 1714 is more stringent or at least as stringent as the requirements of 51.166

## Attachment 6 Requirements for a SIP Approved PSD Program in 40 CFR 51.166 and How those Requirements are met by South Coast AQMD Rule 1714 Page 43of 53

(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 (w)(11)(i)( b ) of this section), plus the sum of the baseline actual emissions of the small emissions units. (iii) The PAL permit shall be revised to reflect the increased PAL level pursuant to the public notice requirements of paragraph (w)(5) of this section. (12) Monitoring requirements for PALs

— (i) General requirements. 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.
( a ) Each PAL permit must contain enforceable requirements for the monitoring system that accurately determines plantwide ( b ) The PAL monitoring system must employ one or more of the four general monitoring approaches meeting the minimum requirements set forth in paragraphs (w)(12)(ii) ( a ) through ( d ) of this section and must be approved by the reviewing authority.
( c ) Notwithstanding paragraph (w)(12)(i)( b ) of this section, you may also employ an alternative monitoring approach that meets paragraph (w)(12)(i)( a ) of this section if approved by the reviewing authority. ( d ) Failure to use a monitoring system that meets the requirements of this section renders the PAL invalid. (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 (w)(12)(iii) through (ix) of this section: ( a ) Mass balance calculations for activities using coatings or solvents; ( b ) CEMS; ( c ) CPMS or PEMS; and ( d ) Emission factors. (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:
( 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;
( 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 ( 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. Rule 1714(c)(1) exludes these provisions from 40 CFR 52.21(aa). Without these provisions Rule 1714 is more stringent or at least as stringent as the requirements of 51.166

## Attachment 6 Requirements for a SIP Approved PSD Program in 40 CFR 51.166 and How those Requirements are met by South Coast AQMD Rule 1714 Page 44of 53

(iv) CEMS. An owner or operator using CEMS to monitor PAL pollutant emissions shall meet the following requirements: ( a ) CEMS must comply with applicable Performance Specifications found in 40 CFR part 60, appendix B; and ( b ) CEMS must sample, analyze, and record data at least every 15 minutes while the emissions unit is operating. (v) CPMS or PEMS. An owner or operator using CPMS or PEMS to monitor PAL pollutant emissions shall meet the following requirements: ( 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 ( 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. (vi) Emission factors. An owner or operator using emission factors to monitor PAL pollutant emissions shall meet the following requirements: ( a ) All emission factors shall be adjusted, if appropriate, to account for the degree of uncertainty or limitations in the factors' development; ( b ) The emissions unit shall operate within the designated range of use for the emission factor, if applicable; and ( c ) If technically practicable, the owner or operator of a significant emissions unit that relies on anemission factor to calculate PAL pollutant emissions shall conduct validation testing to determine a sitespecific emission factor within 6 months of PAL permit issuance, unless the reviewing authority determines that testing is not required. (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. (viii) Notwithstanding the requirements in paragraphs (w)(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:
( 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 ( 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.
(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.
(13) Recordkeeping requirements. (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 (w) of this section and of the PAL, including a determination of each emissions unit's 12-month rolling total emissions, for 5 years from the date of such record. Rule 1714(c)(1) exludes these provisions from 40 CFR 52.21(aa). Without these provisions Rule 1714 is more stringent or at least as stringent as the requirements of 51.166

## Attachment 6 Requirements for a SIP Approved PSD Program in 40 CFR 51.166 and How those Requirements are met by South Coast AQMD Rule 1714 Page 45of 53

(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: ( a ) A copy of the PAL permit application and any applications for revisions to the PAL; and

( b ) Each annual certification of compliance pursuant to title V and the data relied on in certifying the compliance. (14) Reporting and notification requirements. 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 (w)(14)(i) through (iii) of this section. (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 (w)(14)(i)( a ) through ( g ) of this section. ( a ) The identification of owner and operator and the permit number. ( b ) Total annual emissions (tons/year) based on a 12-month rolling total for each month in the reporting period recorded pursuant to paragraph (w)(13)(i) of this section.
( 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. ( d ) A list of any emissions units modified or added to the major stationary source during the preceding 6-month period. ( 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.
( 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 (w)(12)(vii) of this section.
( 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. (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:
( a ) The identification of owner and operator and the permit number; ( b ) The PAL requirement that experienced the deviation or that was exceeded; ( c ) Emissions resulting from the deviation or the exceedance; and ( 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. Rule 1714(c)(1) exludes these provisions from 40 CFR 52.21(aa). Without these provisions Rule 1714 is more stringent or at least as stringent as the requirements of 51.166

## Attachment 6 Requirements for a SIP Approved PSD Program in 40 CFR 51.166 and How those Requirements are met by South Coast AQMD Rule 1714 Page 46of 53

(iii) Re-validation results. The owner or operator shall submit to the reviewing authority the results of any re-validation test or method within three months after completion of such test or method.
(15) Transition requirements. (i) No reviewing authority may issue a PAL that does not comply with the requirements in paragraphs (w)(1) through (15) of this section after the Administrator has approved regulations incorporating these requirements into a plan. (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 that complies with the requirements of paragraphs (w)(1) through (15) of this section. (x) (x) 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. 40 CFR 52.21(bb)

(y) (y) Equipment replacement provision. 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 (y)(1) through (3) of this section are met.
(1) Capital Cost threshold for Equipment Replacement. (i) For an electric utility steam generating unit, as defined in §51.166(b)(30), 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.

(ii) In determining the replacement value of the process unit; and, except as otherwise allowed under paragraph (y)(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.
(iii) As an alternative to paragraph (y)(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 (y)(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 Rule 1714(c)(1) exludes these provisions from 40 CFR 52.21(aa). Without these provisions Rule 1714 is more stringent or at least as stringent as the requirements of 51.166

These provisions were stayed indefinitely by a court order on December 24, 2003. District Rule 1714(c)(1) excludes these provisions as they appear in 40 CFR 52.21(cc).

## Attachment 6 Requirements for a SIP Approved PSD Program in 40 CFR 51.166 and How those Requirements are met by South Coast AQMD Rule 1714 Page 47of 53

(2) Basic design parameters. The replacement does not change the basic design parameter(s) of the process unit to which the activity pertains. (i) Except as provided in paragraph (y)(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-fired electric utility steam generating unit.
(ii) Except as provided in paragraph (y)(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.
(iii) If the owner or operator believes the basic design parameter(s) in paragraphs (y)(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).
(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 (y)(2)(i) and (ii) of this section.
(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.
(vi) Efficiency of a process unit is not a basic design parameter. (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. Note to paragraph (y): By a court order on December 24, 2003, this paragraph (y) 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 Federal Register advising the public of the termination of the stay.

(Secs. 101(b)(1), 110, 160–169, 171–178, and 301(a), Clean Air Act, as amended (42 U.S.C. 7401(b)(1), 7410, 7470–7479, 7501–7508, and 7601(a)); sec. 129(a), Clean Air Act Amendments of 1977 (Pub. L. 95–95, 91 Stat. 685 (Aug. 7, 1977))) [43 FR 26382, June 19, 1978] These provisions were stayed indefinitely by a court order on December 24, 2003. District Rule 1714(c)(1) excludes these provisions as they appear in 40 CFR 52.21(cc).

## Attachment 6 Requirements for a SIP Approved PSD Program in 40 CFR 51.166 and How those Requirements are met by South Coast AQMD Rule 1714 Page 48of 53

Editorial Note:For Federal Register citations affecting §51.166, see the List of CFR Sections Affected, which appears in the Finding Aids section of the printed volume and at www.fdsys.gov

.
Effective Date Note:At 76 FR 17553, Mar. 30, 2011, §51.166 paragraphs (b)(2)(v) and (b)(3)(iii) (d) are stayed indefinitely.

Sections in 40 CFR 52.21 that are not otherwise required, or may be required, for a PSD program in 40 CFR 51.166 and that were not excluded by Distric Rule 1714

40 CFR 52.21(b)(54) RACT (54) Reasonably available control technology (RACT) is as defined in §51.100(o) of this chapter. Definition not in 51.166, but does not effect the other definitions or requirements for a PSD program

## Attachment 6 Requirements for a SIP Approved PSD Program in 40 CFR 51.166 and How those Requirements are met by South Coast AQMD Rule 1714 Page 49of 53

Table 1

Pollutant Maximum allowable increase (mg/m3

## )

PM2.5

## : Annual arithmetic mean 1 24-hr maximum 2 PM 10

## : Annual arithmetic mean 4 24-hr maximum 8 Sulfur dioxide: Annual arithmetic mean 2 24-hr maximum 5 3-hr maximum 25 Nitrogen dioxide: Annual arithmetic mean 2.5

PM2.5

## : Annual arithmetic mean 4 24-hr maximum 9 PM 10

## : Annual arithmetic mean 17 24-hr maximum 30 Sulfur dioxide: Annual arithmetic mean 20 24-hr maximum 91 3-hr maximum 512 Nitrogen dioxide: Annual arithmetic mean 25

Class I Area

Class II Area

Class III Area PM2.5

## :

## Attachment 6 Requirements for a SIP Approved PSD Program in 40 CFR 51.166 and How those Requirements are met by South Coast AQMD Rule 1714 Page 50of 53

Annual arithmetic mean 8 24-hr maximum 18 PM 10

## : Annual arithmetic mean 34 24-hr maximum 60 Sulfur dioxide: Annual arithmetic mean 40 24-hr maximum 182 3-hr maximum 700 Nitrogen dioxide: Annual arithmetic mean 50

## Attachment 6 Requirements for a SIP Approved PSD Program in 40 CFR 51.166 and How those Requirements are met by South Coast AQMD Rule 1714 Page 51of 53

Table 2

Class I Class II Class III

area area area

PM2.5 

## Annual 0.06 μg/m3 

## 0.3 μg/m3 

## 0.3 μg/m3



## 24-hour 0.07 μg/m3 Public notice (10/15/20 10) and public hearing (11/5/201 0) were held. 

## 1.2 μg/m3 

## Pollutant Averaging

time

## Attachment 6 Requirements for a SIP Approved PSD Program in 40 CFR 51.166 and How those Requirements are met by South Coast AQMD Rule 1714 Page 52of 53

Table 3

Pollutant Maximum allowable increase [microgram per cubic meater]
PM2.5

## : Annual arithmetic

mean 4 24-hr maximum 9 PM 10

## : Annual arithmetic

mean 17 24-hr maximum 30 Sulfur dioxide: Annual arithmetic

mean 20 24-hr maximum 91 3-hr maximum 325 Nitrogen dioxide: Annual arithmetic

mean 25

## Attachment 6 Requirements for a SIP Approved PSD Program in 40 CFR 51.166 and How those Requirements are met by South Coast AQMD Rule 1714 Page 53of 53

Table 4

Low High 24-hr maximum 36 62 3-hr maximum 130 221 Period of
exposure Terrain areas Maximum Allowable Increase [Micrograms per cubic meter]