51.123—Findings and requirements for submission of State implementation plan revisions relating to emissions of oxides of nitrogen pursuant to the Clean Air Interstate Rule.
(a)
(1)
Under section 110(a)(1) of the CAA, 42 U.S.C. 7410(a)(1), the Administrator determines that each State identified in paragraph (c)(1) and (2) of this section must submit a SIP revision to comply with the requirements of section 110(a)(2)(D)(i)(I) of the CAA, 42 U.S.C. 7410(a)(2)(D)(i)(I), through the adoption of adequate provisions prohibiting sources and other activities from emitting NOX in amounts that will contribute significantly to nonattainment in, or interfere with maintenance by, one or more other States with respect to the fine particles (PM2.5) NAAQS.
(2)
(a)
Under section 110(a)(1) of the CAA, 42 U.S.C. 7410(a)(1), the Administrator determines that each State identified in paragraph (c)(1) and (3) of this section must submit a SIP revision to comply with the requirements of section 110(a)(2)(D)(i)(I) of the CAA, 42 U.S.C. 7410(a)(2)(D)(i)(I), through the adoption of adequate provisions prohibiting sources and other activities from emitting NOX in amounts that will contribute significantly to nonattainment in, or interfere with maintenance by, one or more other States with respect to the 8-hour ozone NAAQS.
(3)
Notwithstanding the other provisions of this section, such provisions are not applicable as they relate to the State of Minnesota as of December 3, 2009.
(b)
For each State identified in paragraph (c) of this section, the SIP revision required under paragraph (a) of this section will contain adequate provisions, for purposes of complying with section 110(a)(2)(D)(i)(I) of the CAA, 42 U.S.C. 7410(a)(2)(D)(i)(I), only if the SIP revision contains control measures that assure compliance with the applicable requirements of this section.
(1)
Alabama, Delaware, Florida, Illinois, Indiana, Iowa, Kentucky, Louisiana, Maryland, Michigan, Mississippi, Missouri, New Jersey, New York, North Carolina, Ohio, Pennsylvania, South Carolina, Tennessee, Virginia, West Virginia, Wisconsin, and the District of Columbia shall be subject to the requirements contained in paragraphs (e) through (cc) of this section;
(2)
Georgia, Minnesota, and Texas shall be subject to the requirements in paragraphs (e) through (o) and (cc) of this section; and
(3)
Arkansas, Connecticut, and Massachusetts shall be subject to the requirements contained in paragraphs (q) through (cc) of this section.
(d)
(1)
The State's SIP revision under paragraph (a) of this section must be submitted to EPA by no later than September 11, 2006.
(2)
The requirements of appendix V to this part shall apply to the SIP revision under paragraph (a) of this section.
(3)
The State shall deliver 5 copies of the SIP revision under paragraph (a) of this section to the appropriate Regional Office, with a letter giving notice of such action.
(e)
The State's SIP revision shall contain control measures and demonstrate that they will result in compliance with the State's Annual EGU NOX Budget, if applicable, and achieve the State's Annual Non-EGU NOX Reduction Requirement, if applicable, for the appropriate periods. The amounts of the State's Annual EGU NOX Budget and Annual Non-EGU NOX Reduction Requirement shall be determined as follows:
(1)
(i)
The Annual EGU NOX Budget for the State is defined as the total amount of NOX emissions from all EGUs in that State for a year, if the State meets the requirements of paragraph (a)(1) of this section by imposing control measures, at least in part, on EGUs. If the State imposes control measures under this section on only EGUs, the Annual EGU NOX Budget for the State shall not exceed the amount, during the indicated periods, specified in paragraph (e)(2) of this section.
(ii)
The Annual Non-EGU NOX Reduction Requirement, if applicable, is defined as the total amount of NOX emission reductions that the State demonstrates, in accordance with paragraph (g) of this section, it will achieve from non-EGUs during the appropriate period. If the State meets the requirements of paragraph (a)(1) of this section by imposing control measures on only non-EGUs, then the State's Annual Non-EGU NOX Reduction Requirement shall equal or exceed, during the appropriate periods, the amount determined in accordance with paragraph (e)(3) of this section.
(iii)
If a State meets the requirements of paragraph (a)(1) of this section by imposing control measures on both EGUs and non-EGUs, then:
(A)
The Annual Non-EGU NOX Reduction Requirement shall equal or exceed the difference between the amount specified in paragraph (e)(2) of this section for the appropriate period and the amount of the State's Annual EGU NOX Budget specified in the SIP revision for the appropriate period; and
(B)
The Annual EGU NOX Budget shall not exceed, during the indicated periods, the amount specified in paragraph (e)(2) of this section plus the amount of the Annual Non-EGU NOX Reduction Requirement under paragraph (e)(1)(iii)(A) of this section for the appropriate period.
(2)
For a State that complies with the requirements of paragraph (a)(1) of this section by imposing control measures on only EGUs, the amount of the Annual EGU NOX Budget, in tons of NOX per year, shall be as follows, for the indicated State for the indicated period:
| State | Annual EGU NOX budget for 2009-2014 (tons) | Annual EGU NOX budget for 2015 and thereafter (tons) |
|---|---|---|
| Alabama | 69,020 | 57,517 |
| Delaware | 4,166 | 3,472 |
| District of Columbia | 144 | 120 |
| Florida | 99,445 | 82,871 |
| Georgia | 66,321 | 55,268 |
| Illinois | 76,230 | 63,525 |
| Indiana | 108,935 | 90,779 |
| Iowa | 32,692 | 27,243 |
| Kentucky | 83,205 | 69,337 |
| Louisiana | 35,512 | 29,593 |
| Maryland | 27,724 | 23,104 |
| Michigan | 65,304 | 54,420 |
| Minnesota | 31,443 | 26,203 |
| Mississippi | 17,807 | 14,839 |
| Missouri | 59,871 | 49,892 |
| New Jersey | 12,670 | 10,558 |
| New York | 45,617 | 38,014 |
| North Carolina | 62,183 | 51,819 |
| Ohio | 108,667 | 90,556 |
| Pennsylvania | 99,049 | 82,541 |
| South Carolina | 32,662 | 27,219 |
| Tennessee | 50,973 | 42,478 |
| Texas | 181,014 | 150,845 |
| Virginia | 36,074 | 30,062 |
| West Virginia | 74,220 | 61,850 |
| Wisconsin | 40,759 | 33,966 |
(3)
For a State that complies with the requirements of paragraph (a)(1) of this section by imposing control measures on only non-EGUs, the amount of the Annual Non-EGU NOX Reduction Requirement, in tons of NOX per year, shall be determined, for the State for 2009 and thereafter, by subtracting the amount of the State's Annual EGU NOX Budget for the appropriate year, specified in paragraph (e)(2) of this section from the amount of the State's NOX baseline EGU emissions inventory projected for the appropriate year, specified in Table 5 of “Regional and State SO2 and NOX Budgets”, March 2005 (available at http://www.epa.gov/cleanairinterstaterule ).
(4)
(i)
Notwithstanding the State's obligation to comply with paragraph (e)(2) or (3) of this section, the State's SIP revision may allow sources required by the revision to implement control measures to demonstrate compliance using credit issued from the State's compliance supplement pool, as set forth in paragraph (e)(4)(ii) of this section.
| State | Compliance supplement pool |
|---|---|
| Alabama | 10,166 |
| Delaware | 843 |
| District of Columbia | 0 |
| Florida | 8,335 |
| Georgia | 12,397 |
| Illinois | 11,299 |
| Indiana | 20,155 |
| Iowa | 6,978 |
| Kentucky | 14,935 |
| Louisiana | 2,251 |
| Maryland | 4,670 |
| Michigan | 8,347 |
| Minnesota | 6,528 |
| Mississippi | 3,066 |
| Missouri | 9,044 |
| New Jersey | 660 |
| New York | 0 |
| North Carolina | 0 |
| Ohio | 25,037 |
| Pennsylvania | 16,009 |
| South Carolina | 2,600 |
| Tennessee | 8,944 |
| Texas | 772 |
| Virginia | 5,134 |
| West Virginia | 16,929 |
| Wisconsin | 4,898 |
(iii)
The SIP revision may provide for the distribution of credits from the compliance supplement pool to sources that are required to implement control measures using one or both of the following two mechanisms:
(A)
The State may issue credit from compliance supplement pool to sources that are required by the SIP revision to implement NOX emission control measures and that implement NOX emission reductions in 2007 and 2008 that are not necessary to comply with any State or federal emissions limitation applicable at any time during such years. Such a source may be issued one credit from the compliance supplement pool for each ton of such emission reductions in 2007 and 2008.
(1) The State shall complete the issuance process by January 1, 2010.
(2) The emissions reductions for which credits are issued must have been demonstrated by the owners and operators of the source to have occurred during 2007 and 2008 and not to be necessary to comply with any applicable State or federal emissions limitation.
(3) The emissions reductions for which credits are issued must have been quantified by the owners and operators of the source:
(i) For EGUs and for fossil-fuel-fired non-EGUs that are boilers or combustion turbines with a maximum design heat input greater than 250 mmBut/hr, using emissions data determined in accordance with subpart H of part 75 of this chapter; and
(ii) For non-EGUs not described in paragraph (e)(4)(iii)(A)(3)(i) of this section, using emissions data determined in accordance with subpart H of part 75 of this chapter or, if the State demonstrates that compliance with subpart H of part 75 of this chapter is not practicable, determined, to the extent practicable, with the same degree of assurance with which emissions data are determined for sources subject to subpart H of part 75.
(4) If the SIP revision contains approved provisions for an emissions trading program, the owners and operators of sources that receive credit according to the requirements of this paragraph may transfer the credit to other sources or persons according to the provisions in the emissions trading program.
(B)
The State may issue credit from the compliance supplement pool to sources that are required by the SIP revision to implement NOX emission control measures and whose owners and operators demonstrate a need for an extension, beyond 2009, of the deadline for the source for implementing such emission controls.
(1) The State shall complete the issuance process by January 1, 2010.
(2) The State shall issue credit to a source only if the owners and operators of the source demonstrate that:
(i) For a source used to generate electricity, implementation of the SIP revision's applicable control measures by 2009 would create undue risk for the reliability of the electricity supply. This demonstration must include a showing that it would not be feasible for the owners and operators of the source to obtain a sufficient amount of electricity, to prevent such undue risk, from other electricity generation facilities during the installation of control technology at the source necessary to comply with the SIP revision.
(ii) For a source not used to generate electricity, compliance with the SIP revision's applicable control measures by 2009 would create undue risk for the source or its associated industry to a degree that is comparable to the risk described in paragraph (e)(4)(iii)(B)(2)(i) of this section.
(iii) This demonstration must include a showing that it would not be possible for the source to comply with applicable control measures by obtaining sufficient credits under paragraph (e)(4)(iii)(A) of this section, or by acquiring sufficient credits from other sources or persons, to prevent undue risk.
(f)
Each SIP revision must set forth control measures to meet the amounts specified in paragraph (e) of this section, as applicable, including the following:
(2)
(i)
If a State elects to impose control measures on EGUs, then those measures must impose an annual NOX mass emissions cap on all such sources in the State.
(ii)
If a State elects to impose control measures on fossil fuel-fired non-EGUs that are boilers or combustion turbines with a maximum design heat input greater than 250 mmBtu/hr, then those measures must impose an annual NOX mass emissions cap on all such sources in the State.
(iii)
If a State elects to impose control measures on non-EGUs other than those described in paragraph (f)(2)(ii) of this section, then those measures must impose an annual NOX mass emissions cap on all such sources in the State or the State must demonstrate why such emissions cap is not practicable and adopt alternative requirements that ensure that the State will comply with its requirements under paragraph (e) of this section, as applicable, in 2009 and subsequent years.
(g)
(1)
Each SIP revision that contains control measures covering non-EGUs as part or all of a State's obligation in meeting its requirement under paragraph (a)(1) of this section must demonstrate that such control measures are adequate to provide for the timely compliance with the State's Annual Non-EGU NOX Reduction Requirement under paragraph (e) of this section and are not adopted or implemented by the State, as of May 12, 2005, and are not adopted or implemented by the Federal government, as of the date of submission of the SIP revision by the State to EPA.
(2)
The demonstration under paragraph (g)(1) of this section must include the following, with respect to each source category of non-EGUs for which the SIP revision requires control measures:
(i)
A detailed historical baseline inventory of NOX mass emissions from the source category in a representative year consisting, at the State's election, of 2002, 2003, 2004, or 2005, or an average of 2 or more of those years, absent the control measures specified in the SIP revision.
(A)
This inventory must represent estimates of actual emissions based on monitoring data in accordance with subpart H of part 75 of this chapter, if the source category is subject to monitoring requirements in accordance with subpart H of part 75 of this chapter.
(B)
In the absence of monitoring data in accordance with subpart H of part 75 of this chapter, actual emissions must be quantified, to the maximum extent practicable, with the same degree of assurance with which emissions are quantified for sources subject to subpart H of part 75 of this chapter and using source-specific or source-category-specific assumptions that ensure a source's or source category's actual emissions are not overestimated. If a State uses factors to estimate emissions, production or utilization, or effectiveness of controls or rules for a source category, such factors must be chosen to ensure that emissions are not overestimated.
(C)
For measures to reduce emissions from motor vehicles, emission estimates must be based on an emissions model that has been approved by EPA for use in SIP development and must be consistent with the planning assumptions regarding vehicle miles traveled and other factors current at the time of the SIP development.
(D)
For measures to reduce emissions from nonroad engines or vehicles, emission estimates methodologies must be approved by EPA.
(ii)
A detailed baseline inventory of NOX mass emissions from the source category in the years 2009 and 2015, absent the control measures specified in the SIP revision and reflecting changes in these emissions from the historical baseline year to the years 2009 and 2015, based on projected changes in the production input or output, population, vehicle miles traveled, economic activity, or other factors as applicable to this source category.
(A)
These inventories must account for implementation of any control measures that are otherwise required by final rules already promulgated, as of May 12, 2005, or adopted or implemented by any federal agency, as of the date of submission of the SIP revision by the State to EPA, and must exclude any control measures specified in the SIP revision to meet the NOX emissions reduction requirements of this section.
(B)
Economic and population forecasts must be as specific as possible to the applicable industry, State, and county of the source or source category and must be consistent with both national projections and relevant official planning assumptions, including estimates of population and vehicle miles traveled developed through consultation between State and local transportation and air quality agencies. However, if these official planning assumptions are inconsistent with official U.S. Census projections of population or with energy consumption projections contained in the U.S. Department of Energy's most recent Annual Energy Outlook, then the SIP revision must make adjustments to correct the inconsistency or must demonstrate how the official planning assumptions are more accurate.
(C)
These inventories must account for any changes in production method, materials, fuels, or efficiency that are expected to occur between the historical baseline year and 2009 or 2015, as appropriate.
(iii)
A projection of NOX mass emissions in 2009 and 2015 from the source category assuming the same projected changes as under paragraph (g)(2)(ii) of this section and resulting from implementation of each of the control measures specified in the SIP revision.
(A)
These inventories must address the possibility that the State's new control measures may cause production or utilization, and emissions, to shift to unregulated or less stringently regulated sources in the source category in the same or another State, and these inventories must include any such amounts of emissions that may shift to such other sources.
(B)
The State must provide EPA with a summary of the computations, assumptions, and judgments used to determine the degree of reduction in projected 2009 and 2015 NOX emissions that will be achieved from the implementation of the new control measures compared to the relevant baseline emissions inventory.
(iv)
The result of subtracting the amounts in paragraph (g)(2)(iii) of this section for 2009 and 2015, respectively, from the lower of the amounts in paragraph (g)(2)(i) or (g)(2)(ii) of this section for 2009 and 2015, respectively, may be credited towards the State's Annual Non-EGU NOX Reduction Requirement in paragraph (e)(3) of this section for the appropriate period.
(v)
Each SIP revision must identify the sources of the data used in each estimate and each projection of emissions.
(i)
Each SIP revision must provide for monitoring the status of compliance with any control measures adopted to meet the State's requirements under paragraph (e) of this section as follows:
(1)
The SIP revision must provide for legally enforceable procedures for requiring owners or operators of stationary sources to maintain records of, and periodically report to the State:
(ii)
Other information as may be necessary to enable the State to determine whether the sources are in compliance with applicable portions of the control measures;
(2)
The SIP revision must comply with § 51.212 (regarding testing, inspection, enforcement, and complaints);
(3)
If the SIP revision contains any transportation control measures, then the SIP revision must comply with § 51.213 (regarding transportation control measures);
(4)
(i)
If the SIP revision contains measures to control EGUs, then the SIP revision must require such sources to comply with the monitoring, recordkeeping, and reporting provisions of subpart H of part 75 of this chapter.
(ii)
If the SIP revision contains measures to control fossil fuel-fired non-EGUs that are boilers or combustion turbines with a maximum design heat input greater than 250 mmBtu/hr, then the SIP revision must require such sources to comply with the monitoring, recordkeeping, and reporting provisions of subpart H of part 75 of this chapter.
(iii)
If the SIP revision contains measures to control any other non-EGUs that are not described in paragraph (i)(4)(ii) of this section, then the SIP revision must require such sources to comply with the monitoring, recordkeeping, and reporting provisions of subpart H of part 75 of this chapter, or the State must demonstrate why such requirements are not practicable and adopt alternative requirements that ensure that the required emissions reductions will be quantified, to the maximum extent practicable, with the same degree of assurance with which emissions are quantified for sources subject to subpart H of part 75 of this chapter.
(j)
Each SIP revision must show that the State has legal authority to carry out the SIP revision, including authority to:
(1)
Adopt emissions standards and limitations and any other measures necessary for attainment and maintenance of the State's relevant Annual EGU NOX Budget or the Annual Non-EGU NOX Reduction Requirement, as applicable, under paragraph (e) of this section;
(3)
Obtain information necessary to determine whether air pollution sources are in compliance with applicable laws, regulations, and standards, including authority to require recordkeeping and to make inspections and conduct tests of air pollution sources; and
(4)
(i)
Require owners or operators of stationary sources to install, maintain, and use emissions monitoring devices and to make periodic reports to the State on the nature and amounts of emissions from such stationary sources; and
(ii)
Make the data described in paragraph (j)(4)(i) of this section available to the public within a reasonable time after being reported and as correlated with any applicable emissions standards or limitations.
(k)
(1)
The provisions of law or regulation that the State determines provide the authorities required under this section must be specifically identified, and copies of such laws or regulations must be submitted with the SIP revision.
(2)
Legal authority adequate to fulfill the requirements of paragraphs (j)(3) and (4) of this section may be delegated to the State under section 114 of the CAA.
(n)
Each SIP revision must provide for State compliance with the reporting requirements in § 51.125.
(o)
(1)
Notwithstanding any other provision of this section, if a State adopts regulations substantively identical to subparts AA through II of part 96 of this chapter (CAIR NOX Annual Trading Program), incorporates such subparts by reference into its regulations, or adopts regulations that differ substantively from such subparts only as set forth in paragraph (o)(2) of this section, then such emissions trading program in the State's SIP revision is automatically approved as meeting the requirements of paragraph (e) of this section, provided that the State has the legal authority to take such action and to implement its responsibilities under such regulations. Before January 1, 2009, a State's regulations shall be considered to be substantively identical to subparts AA through II of part 96 of this chapter, or differing substantively only as set forth in paragraph (o)(2) of this section, regardless of whether the State's regulations include the definition of “Biomass”, paragraph (3) of the definition of “Cogeneration unit”, and the second sentence of the definition of “Total energy input” in § 96.102 of this chapter promulgated on October 19, 2007, provided that the State timely submits to the Administrator a SIP revision that revises the State's regulations to include such provisions. Submission to the Administrator of a SIP revision that revises the State's regulations to include such provisions shall be considered timely if the submission is made by January 1, 2009.
(2)
If a State adopts an emissions trading program that differs substantively from subparts AA through II of part 96 of this chapter only as follows, then the emissions trading program is approved as set forth in paragraph (o)(1) of this section.
(A)
Subpart II of this part and the provisions applicable only to CAIR NOX opt-in units in subparts AA through HH of this part;
(B)
Section 96.188(b) of this chapter and the provisions of subpart II of this part applicable only to CAIR NOX opt-in units under § 96.188(b); or
(C)
Section 96.188(c) of this chapter and the provisions of subpart II of this part applicable only to CAIR NOX opt-in units under § 96.188(c).
(ii)
The State may decline to adopt the allocation provisions set forth in subpart EE of part 96 of this chapter and may instead adopt any methodology for allocating CAIR NOX allowances to individual sources, as follows:
(A)
The State's methodology must not allow the State to allocate CAIR NOX allowances for a year in excess of the amount in the State's Annual EGU NOX Budget for such year;
(B)
The State's methodology must require that, for EGUs commencing operation before January 1, 2001, the State will determine, and notify the Administrator of, each unit's allocation of CAIR NOX allowances by October 31, 2006 for 2009, 2010, and 2011 and by October 31, 2008 and October 31 of each year thereafter for 4th the year after the year of the notification deadline;
(C)
The State's methodology must require that, for EGUs commencing operation on or after January 1, 2001, the State will determine, and notify the Administrator of, each unit's allocation of CAIR NOX allowances by October 31 of the year for which the CAIR NOX allowances are allocated; and
(D)
The State's methodology for allocating the compliance supplement pool must be substantively identical to § 97.143 (except that the permitting authority makes the allocations and the Administrator records the allocations made by the permitting authority) or otherwise in accordance with paragraph (e)(4) of this section.
(3)
A State that adopts an emissions trading program in accordance with paragraph (o)(1) or (2) of this section is not required to adopt an emissions trading program in accordance with paragraph (aa)(1) or (2) of this section or § 96.124(o)(1) or (2).
(4)
If a State adopts an emissions trading program that differs substantively from subparts AA through HH of part 96 of this chapter, other than as set forth in paragraph (o)(2) of this section, then such emissions trading program is not automatically approved as set forth in paragraph (o)(1) or (2) of this section and will be reviewed by the Administrator for approvability in accordance with the other provisions of this section, provided that the NOX allowances issued under such emissions trading program shall not, and the SIP revision shall state that such NOX allowances shall not, qualify as CAIR NOX allowances or CAIR NOX Ozone Season allowances under any emissions trading program approved under paragraphs (o)(1) or (2) or (aa)(1) or (2) of this section.
(p)
Notwithstanding any other provision of this section, a State may adopt, and include in a SIP revision submitted by March 31, 2007, regulations relating to the Federal CAIR NOX Annual Trading Program under subparts AA through HH of part 97 of this chapter as follows:
(1)
The State may adopt, as CAIR NOX allowance allocation provisions replacing the provisions in subpart EE of part 97 of this chapter :
(i)
Allocation provisions substantively identical to subpart EE of part 96 of this chapter, under which the permitting authority makes the allocations; or
(ii)
Any methodology for allocating CAIR NOX allowances to individual sources under which the permitting authority makes the allocations, provided that:
(A)
The State's methodology must not allow the permitting authority to allocate CAIR NOX allowances for a year in excess of the amount in the State's Annual EGU NOX budget for such year.
(B)
The State's methodology must require that, for EGUs commencing operation before January 1, 2001, the permitting authority will determine, and notify the Administrator of, each unit's allocation of CAIR NOX allowances by April 30, 2007 for 2009, 2010, and 2011 and by October 31, 2008 and October 31 of each year thereafter for the 4th year after the year of the notification deadline.
(C)
The State's methodology must require that, for EGUs commencing operation on or after January 1, 2001, the permitting authority will determine, and notify the Administrator of, each unit's allocation of CAIR NOX allowances by October 31 of the year for which the CAIR NOX allowances are allocated.
(2)
The State may adopt, as compliance supplement pool provisions replacing the provisions in § 97.143 of this chapter :
(i)
Provisions for allocating the State's compliance supplement pool that are substantively identical to § 97.143 of this chapter, except that the permitting authority makes the allocations and the Administrator records the allocations made by the permitting authority;
(ii)
Provisions for allocating the State's compliance supplement pool that are substantively identical to § 96.143 of this chapter; or
(iii)
Other provisions for allocating the State's compliance supplement pool that are in accordance with paragraph (e)(4) of this section.
(i)
Provisions for CAIR opt-in units, including provisions for applications for CAIR opt-in permits, approval of CAIR opt-in permits, treatment of units as CAIR opt-in units, and allocation and recordation of CAIR NOX allowances for CAIR opt-in units, that are substantively identical to subpart II of part 96 of this chapter and the provisions of subparts AA through HH that are applicable to CAIR opt-in units or units for which a CAIR opt-in permit application is submitted and not withdrawn and a CAIR opt-in permit is not yet issued or denied;
(ii)
Provisions for CAIR opt-in units, including provisions for applications for CAIR opt-in permits, approval of CAIR opt-in permits, treatment of units as CAIR opt-in units, and allocation and recordation of CAIR NOX allowances for CAIR opt-in units, that are substantively identical to subpart II of part 96 of this chapter and the provisions of subparts AA through HH that are applicable to CAIR opt-in units or units for which a CAIR opt-in permit application is submitted and not withdrawn and a CAIR opt-in permit is not yet issued or denied, except that the provisions exclude § 96.188(b) of this chapter and the provisions of subpart II of part 96 of this chapter that apply only to units covered by § 96.188(b) of this chapter; or
(iii)
Provisions for applications for CAIR opt-in units, including provisions for CAIR opt-in permits, approval of CAIR opt-in permits, treatment of units as CAIR opt-in units, and allocation and recordation of CAIR NOX allowances for CAIR opt-in units, that are substantively identical to subpart II of part 96 of this chapter and the provisions of subparts AA through HH that are applicable to CAIR opt-in units or units for which a CAIR opt-in permit application is submitted and not withdrawn and a CAIR opt-in permit is not yet issued or denied, except that the provisions exclude § 96.188(c) of this chapter and the provisions of subpart II of part 96 of this chapter that apply only to units covered by § 96.188(c) of this chapter.
(q)
The State's SIP revision shall contain control measures and demonstrate that they will result in compliance with the State's Ozone Season EGU NOX Budget, if applicable, and achieve the State's Ozone Season Non-EGU NOX Reduction Requirement, if applicable, for the appropriate periods. The amounts of the State's Ozone Season EGU NOX Budget and Ozone Season Non-EGU NOX Reduction Requirement shall be determined as follows:
(1)
(i)
The Ozone Season EGU NOX Budget for the State is defined as the total amount of NOX emissions from all EGUs in that State for an ozone season, if the State meets the requirements of paragraph (a)(2) of this section by imposing control measures, at least in part, on EGUs. If the State imposes control measures under this section on only EGUs, the Ozone Season EGU NOX Budget for the State shall not exceed the amount, during the indicated periods, specified in paragraph (q)(2) of this section.
(ii)
The Ozone Season Non-EGU NOX Reduction Requirement, if applicable, is defined as the total amount of NOX emission reductions that the State demonstrates, in accordance with paragraph (s) of this section, it will achieve from non-EGUs during the appropriate period. If the State meets the requirements of paragraph (a)(2) of this section by imposing control measures on only non-EGUs, then the St