SCAQMD RULE 2002 ALLOCATIONS FOR OXIDES OF NITROGEN (NOx> ) OXIDES OF SULFUR (SOx)
LAST REVISED 7/12/96


(Adopted October 15, 1993)(Amended March 10, 1995) (Amended December 7, 1995)
(Amended July 12, 1996)

RULE 2002 - ALLOCATIONS FOR OXIDES OF NITROGEN (NOx )AND OXIDES OF SULFUR (SOx)

(a) Purpose
The purpose of this rule is to establish the methodology for calculating facility Allocations for Oxides of Nitrogen (NOx) and Oxides of Sulfur (SOx).

(b) RECLAIM Allocations

  1. RECLAIM Allocations will begin in 1994.
  2. An annual Allocation will be issued to each facility for each compliance year starting from 1994.
  3. Allocations for each year after 2003 are equal to the facility's ending Allocation, as determined pursuant to subdivision (e) unless, as part of the AQMP process, and pursuant to Rule 2015 (b)(1), (b)(3), (b)(4), or (c), the District Governing Board determines that additional reductions are necessary to meet air quality standards, taking into consideration the current and projected state of technology available and cost-effectiveness to achieve further emission reductions.
  4. The Facility Permit issued at the beginning of each compliance year, pursuant to Rule 2006 - Permits, shall include allocations determined pursuant to subdivisions (c), (d), (e), and (f) and any RECLAIM Trading Credits (RTC) obtained pursuant to Rule 2007 - Trading Requirements for the next fifteen years thereafter.

(c) Establishment of Starting Allocations

  1. The starting Allocation for RECLAIM NOx and SOx facilities initially permitted by the District prior to October 15, 1993, shall be determined by the Executive Officer utilizing the following methodology:
  2. Starting Allocation = Undisplayed Graphic [A X B1] + ERCs + External Offsets, where

    A = the throughput for each NOx and SOx source or process unit in the facility for the maximum throughput year from 1989 to 1992, inclusive; and

    B1 = the applicable starting emission factor for the subject source or process unit, as specified in Table 1 or Table 2.

  3. (A) Use of 1992 data is subject to verification and revision by the Executive Officer or designee to assure validity and accuracy.
  4. (B) The maximum throughput year will be determined by the Executive Officer or designee from throughput data reported through annual emissions reports submitted pursuant to Rule 301 - Permit Fees, or may be designated by the permit holder prior to issuance of the Facility Permit.

    (C) To determine the applicable starting emission factor in Table 1 or Table 2, the Executive Officer or designee will categorize the equipment at each facility based on information relative to hours of operation, equipment size, heating capacity, and permit information submitted pursuant to Rule 201 - Permit to Construct, and other relevant parameters as determined by the Executive Officer or designee. No information used for purposes of this subparagraph may be inconsistent with any information or statement previously submitted on behalf of the facility to the District, including but not limited to information and statements previously submitted pursuant to Rule 301 - Permit Fees, unless the facility can demonstrate, by clear and convincing documentation, that such information or statement was inaccurate.

    (D) Throughput associated with each piece of equipment or NOx or SOx source will be multiplied by the starting emission factors specified in Table 1 or Table 2. If a lower emission factor was utilized for a given piece of equipment or NOx or SOx source pursuant to Rule 301 - Permit Fees, than the factor in Table 1 or Table 2, the lower factor will be used for determining that portion of the Allocation.

    (E) Fuel heating values may be used to convert throughput records into the appropriate units for determining Allocations based on the emission factors in Table 1 or Table 2. If a different unit basis than set forth in Tables 1 and 2 is needed for emissions calculations, the Executive Officer shall use a default heating value to determine source emissions, unless the Facility Permit holder can demonstrate with substantial evidence to the Executive Officer that a different value should be used to determine emissions from that source.

  5. All NOx and SOx ERCs held by a RECLAIM Facility Permit holder shall be reissued as RTCs. RECLAIM facilities will have these RTCs added to their starting Allocations. RTCs generated from the conversion of ERCs shall have a zero rate of reduction for the year 1994 through the year 2000. Such RTCs shall have a cumulative rate of reduction for the years 2001, 2002, and 2003, equal to the percentage inventory adjustment factor applied to 2003 Allocations pursuant to paragraph (e)(1) of this rule.
  6. Non-RECLAIM facilities may elect to have their ERCs converted to RTCs and listed on the RTC Listing maintained by the Executive Officer or designee pursuant to Rule 2007 - Trading Requirements, so long as the written request is filed before July 1, 1994. Such RTCs will be assigned to the trading zone in which the generating facility is located. RTCs generated from the conversion of ERCs shall have a zero rate of reduction for the year 1994 through the year 2000. Such RTCs shall have a cumulative rate of reduction for the years, 2001, 2002, and 2003, equal to the percentage inventory adjustment factor applied to 2003 Allocations pursuant to paragraph (e)(1) of this rule.
  7. External offsets provided pursuant to Regulation XIII - New Source Review, not including any offsets in excess of a 1 to 1 ratio, will be added to the starting Allocation pursuant to paragraph (c)(1) provided:
  8. (A) The offsets were not received from either the Community Bank or the Priority Reserve.

    (B) External offsets will only be added to the starting Allocation to the extent that the Facility Permit holder demonstrates that they have not already been included in the starting Allocation or as an ERC. RTCs issued for external offsets shall not include any offsets in excess of a 1 to 1 ratio required under Regulation XIII - New Source Review.

    (C) RTCs generated from the conversion of external offsets shall have a zero rate of reduction for the year 1994 through the year 2000. These RTCs shall have a cumulative rate of reduction for the years 2001, 2002, and 2003, equal to the percentage inventory adjustment factor applied to 2003 Allocations pursuant to paragraph (e)(1) of this rule.

    (D) Existing facilities with units that have Permits to Construct issued pursuant to Regulation II - Permits, dated on or after January 1, 1992, or existing facilities which have, between January 1, 1992 and October 15, 1993, installed air pollution control equipment that was exempt from offset requirements pursuant to Rule 1304 (a)(5), shall have their starting Allocations increased by the total external offsets provided, or the amount that would have been offset if the exemption had not applied.

    (E) Existing facilities with units whose reported emissions are below capacity due to phased construction, and/or where the Permit to Operate issued pursuant to Regulation II - Permits, was issued after January 1, 1992, shall have their starting Allocations increased by the total external offsets provided.

  9. If a Facility Permit holder can demonstrate that its 1994 Allocation is less than the 1992 emissions reported pursuant to Rule 301 - Permit Fees, and that the facility was, in 1992, operating in compliance with all applicable District rules in effect as of December 31, 1993, the facility's starting Allocation will be equal to the 1992 reported emissions.
  10. For new facilities initially totally permitted on or after January 1, 1993 but prior to October 15, 1993, the starting Allocation shall be equal to the external offsets provided by the facility to offset emission increases at the facility pursuant to Regulation XIII - New Source Review, not including any offsets in excess of a 1 to 1 ratio.
  11. The Allocation for new facilities initially totally permitted on and after October 15, 1993, shall be equal to the total RTCs provided by the facility to offset emission increases at the facility pursuant to Rule 2005- New Source Review for RECLAIM.
  12. The starting Allocation for facilities which enter the RECLAIM program pursuant to Rule 2001 - Applicability, shall be determined by the methodology in paragraph (c)(1) of this rule. The most recent two years reported emission fee data filed pursuant to Rule 301 - Permit Fees, may be used if 1989 through 1992 emission fee data is not available. For facilities lacking reported emission fee data, the Allocation shall be equal to the external offsets provided pursuant to Regulation XIII - New Source Review, not including any offsets in excess of a 1 to 1 ratio. The Allocation shall not include any emission offsets received from either the Community Bank or the Priority Reserve.
  13. A facility may not receive more than one set of Allocations.
  14. A facility that is no longer holding a valid District permit on January 1, 1994 will not receive an Allocation, but may, if authorized by Regulation XIII, apply for ERCs.
  15. Clean Fuel Adjustment to Starting Allocation
    Any refiner who is required to make modifications to comply with CARB Phase II reformulated gasoline production (California Code of Regulations, Title 13, Sections 2250, 2251.5, 2252, 2260, 2261, 2262, 2262.2, 2262.3, 2262.4, 2262.5, 2262.6, 2262.7, 2263, 2264, 2266, 2267, 2268, 2269, 2270, and 2271) or federal requirements (Federal Clean Air Act, Title II, Part A, Section 211; 42 U.S.C. Section 7545) may receive (an) increase(s) in his Allocations except to the extent that there is an increase in maximum rating of the new or modified equipment. Each facility requesting an increase to Allocations shall submit an application for permit amendment specifying the necessary modifications and tentative schedule for completion. The Facility Permit holder shall establish the amount of emission increases resulting from the reformulated gasoline modifications for each year in which the increase in Allocations is requested. The increase to its Allocations will be issued contemporaneously with the modification according to a schedule approved by the Executive Officer or designee (i.e., 1994 through 1997 depending on the refinery). Each increase to the Allocations shall be equal to the increased emissions resulting from the modifications solely to comply with the state or federal reformulated gasoline requirements at the refinery or facility producing hydrogen for reformulated gasoline production, and shall be established according to present and future compliance limits in current District rules or permits. Allocation increases for each refiner pursuant to this paragraph, shall not exceed 5 percent of the refiner's total starting Allocation, unless any refiner emits less than 0.0135 tons of NOx per thousand barrels of crude processed, in which case the Allocation increases for such refiner shall not exceed 20 percent of that refiner's starting Allocation. The emissions per amount of crude processed will be determined on the basis of information reported to the District pursuant to Rule 301 - Permit Fees, for the same calendar year as the facility's peak activity year for their NOx starting Allocation.

(d) Establishment of Year 2000 Allocations

  1. (A) The year 2000 Allocations for RECLAIM NOx and SOx facilities will be determined by the Executive Officer or designee utilizing the following methodology:
  2. Year 2000 Allocation = Undisplayed Graphic [A X B2] + RTCs created from ERCs + External Offsets, where

    A = the throughput for each NOx or SOx source or process unit in the facility for the maximum throughput year from 1987 to 1992, inclusive, as reported pursuant to Rule 301 - Permit Fees; and

    B2 = the applicable Tier I year Allocation emission factor for the subject source or process unit, as specified in Table 1 or Table 2.

    (B) The maximum throughput year will be determined by the Executive Officer or designee from throughput data reported through annual emissions reports pursuant to Rule 301 - Permit Fees, or may be designated by the permit holder prior to issuance of the Facility Permit.

    (C) To determine the applicable emission factor in Table 1 or Table 2, the Executive Officer or designee will categorize the equipment at each facility based on information on hours of operation, equipment size, heating capacity, and permit information submitted pursuant to Rule 201 - Permit to Construct, and other parameters as determined by the Executive Officer or designee. No information used for purposes of this subparagraph may be inconsistent with any information or statement previously submitted on behalf of the facility to the District including but not limited to information and statements previously submitted pursuant to Rule 301 - Permit Fees, unless the facility can demonstrate, by clear and convincing documentation, that such information or statement was inaccurate.

    (D) Throughput associated with each piece of combustion equipment or NOx or SOx source will be multiplied by the Tier I emission factor specified in Table 1 or Table 2. If a factor lower than the factor in Table 1 or Table 2 was utilized for a given piece of equipment or NOx or SOx source pursuant to Rule 301, the lower factor will be used for determining that portion of the Allocation.

    (E) The fuel heating value may be considered in determining Allocations and will be set to 1.0 unless the Facility Permit holder demonstrates that it should receive a different value.

    (F) The year 2000 Allocation is the sum of the resulting products for each piece of equipment or NOx or SOx source multiplied by any inventory adjustment pursuant to paragraph (d)(4) of this rule.

  3. For facilities existing prior to October 15, 1993 which enter RECLAIM after October 15, 1993, the year 2000 Allocation will be determined according to paragraph (d)(1). The most recent two years reported emission fee data filed pursuant to Rule 301 - Permit Fees, may be used if 1989 through 1992 emission fee data is not available. For facilities lacking reported emission fee data, the Allocation shall be equal to their external offsets provided pursuant to Regulation XIII - New Source Review, not including any offsets in excess of a 1 to 1 ratio.
  4. No facility shall have a year 2000 Allocation [calculated pursuant to subdivision (d)] greater than the starting Allocation [calculated pursuant to subdivision (c)].
  5. If the sum of all RECLAIM facilities' year 2000 Allocations differs from the year 2000 projected inventory for these sources under the 1991 AQMP, the Executive Officer or designee will establish a percentage inventory adjustment factor that will be applied to adjust each facility's year 2000 Allocation. The inventory adjustment will not apply to RTCs generated from ERCs or external offsets.

(e) Allocations for the Year 2003

  1. The 2003 Allocations will be determined by the Executive Officer or designee applying a percentage inventory adjustment to reduce each facility's unadjusted year 2000 Allocation so that the sum of all RECLAIM facilities' 2003 Allocations will equal the 1991 AQMP projected inventory for RECLAIM sources for the year 2003, corrected based on actual facility data reviewed for purposes of issuing Facility Permits and to reflect the highest year of actual Basin-wide economic activity for RECLAIM sources considered as a whole during the years 1987 through 1992.
  2. No facility shall have a 2003 Allocation (calculated pursuant this subdivision) greater than the year 2000 Allocation [calculated pursuant to subdivision (d)].

(f) Annual Allocations for NOx and SOx

  1. Allocations for the years between 1994 and 2000, for RECLAIM NOx and SOx facilities shall be determined by a straight line rate of reduction between the starting Allocation and the year 2000 Allocation. For the years 2001 and 2002, the Allocations shall be determined by a straight line rate of reduction between the year 2000 and year 2003 Allocations. Allocations for each year after 2003 are equal to the facility's ending Allocation, as determined pursuant to subdivision (e) , unless as part of the AQMP process, and pursuant to Rule 2015 (b)(1), (b)(3), (b)(4), or (c), the District Governing Board determines that additional reductions are necessary to meet air quality standards, taking into consideration the current and projected state of technology available and cost-effectiveness to achieve further emission reductions.
  2. New facilities initially totally permitted, on and after October 15, 1993, shall not have a rate of reduction. The Facility Permit for such facilities will require the Facility Permit holder to, at the commencement of each compliance year, hold RTCs equal to the amount of RTCs provided as offsets pursuant to Rule 2005.
  3. Increases to Allocations for permits issued for Clean Fuel adjustments pursuant to paragraph (c)(12), shall be added to each year's Allocation.

(g) High Employment/Low Emissions (HILO) Facility
The Executive Officer or designee will establish a HILO bank funded with the following maximum total annual emission Allocations:

  1. 91 tons per year of NOx
  2. 91 tons per year of SOx
  3. After January 1, 1997, new facilities may apply to the HILO bank in order to obtain non-tradeable RTCs. Requests will be processed on a first-come, first-served basis, pending qualification.
  4. When credits are available, annual Allocations will be granted for the year of application and all subsequent years.
  5. HILO facilities receiving such Allocations from the HILO bank must verify their HILO status on an annual basis through their APEP report.
  6. Failure to qualify will result in all subsequent years' credits being returned to the HILO bank.
  7. Facilities failing to qualify for the HILO bank Allocations may reapply at any time during the next or subsequent compliance year when credits are available.

(h) Non-Tradeable Allocation Credits

  1. Any existing RECLAIM facility with reported emissions pursuant to Rule 301 - Permit Fees, in either 1987, 1988, or 1993, greater than its starting Allocation, shall be assigned non-tradeable credits for the first three years of the program which shall be determined according to the following methodology:
  2. Non-tradeable credit for NOx and SOx:

    Year 1 = ( Undisplayed Graphic [A X B1]) - 1994 Allocation;

    Where:

    A = the throughput for each NOx or SOx source or process unit in the facility from the single maximum throughput year from 1987, 1988, or 1993; and

    B1 = the applicable starting emission factor, as specified in Table 1 or Table 2.

    Year 2 = Year 1 non-tradeable credits X 0.667
    Year 3 = Year 1 non-tradeable credits X 0.333
    Year 4 and subsequent years = Zero non-tradeable credit.

  3. The use of non-tradeable credits shall be subject to the following requirements:
  4. (A) Non-tradeable credits may only be used for an increase in throughput over that used to determine the facility's starting Allocation. Non-tradeable credits may not be used for emissions increases associated with equipment modifications, change in feedstock or raw materials, or any other changes except increases in throughput. The Executive Officer or designee may impose Facility Permit conditions necessary to ensure compliance with this subparagraph.

    (B) The use of activated non-tradeable credits shall be subject to a non-tradeable RTC mitigation fee, as specified in Rule 301 subdivision (n).

    (C) In order to utilize non-tradeable credits, the Facility Permit holder shall submit a request to the Executive Officer or designee in writing, including a demonstration that the use of the non-tradeable credits complies with all requirements of this paragraph, pay any fees required pursuant to Rule 301 - Fees, and have received written approval from the Executive Officer or designee for their use. The Executive Officer or designee shall deny the request unless the Facility Permit holder demonstrates compliance with all requirements of this paragraph. The Executive Officer or designee shall, in writing, approve or deny the request within three business days of submittal of a complete request and notify the Facility Permit holder of the decision. If the request is denied, the Executive Officer or designee will refund the mitigation fee.

    (D) In the event that a facility transfers any RTCs for the year in which non-tradeable credits have been issued, the non-tradeable credit Allocation shall be invalid, and is no longer available to the facility.

Table 1

RECLAIM NOx Emission Factors

Nitrogen Oxides


Basic Equipment


Fuel

"Throughput" Units Starting Ems Factor * Ending Ems Factor *
Afterburner (Direct Flame and Catalytic) Natural Gas mmcf 130.000 39.000
Afterburner (Direct Flame and Catalytic) LPG, Propane, Butane 1000 Gal RV 3.840
Afterburner (Direct Flame and Catalytic) Diesel 1000 Gal RV 5.700
Agr Chem-Nitric Acid Process-Absrbr Tailgas/Nw tons pure acid produced RV 1.440
Agricultural Chem - Ammonia Process tons produced RV 1.650
Air Ground Turbines Air Ground Turbines (unknown process units) RV 1.860
Ammonia Plant Neutralizer Fert, Ammon Nit tons produced RV 2.500
Asphalt Heater, Concrete Natural Gas mmcf 130.000 65.000
Asphalt Heater, Concrete Fuel Oil 1000 gals RV 9.500
Asphalt Heater, Concrete LPG 1000 gals RV 6.400
Boiler, Heater R1109 (Petr Refin) Natural Gas mmbtu 0.100 0.030
Boiler, Heater R1109 (Petr Refin) Fuel Oil mmbtu 0.100 0.030
Boiler, Heater R1146 (Petr Refin) Natural Gas mmbtu 0.045 0.045
Boiler, Heater R1146 (Petr Refin) Fuel Oil mmbtu 0.045 0.045
Boiler, Heater R1146 (Petr Refin) Refinery Gas mmbtu 0.045 0.045
Boilers, Heaters, Steam Gens Rule 1146 and 1146.1 Natural Gas mmcf 49.180 47.570

* RV = Reported Value
** Does not include ceramic, clay, cement or brick kilns or metal melting, heat treating or glass melting furnaces.

Nitrogen Oxides


Basic Equipment


Fuel

"Throughput" Units Starting Ems Factor * Ending Ems Factor *
Boilers, Heaters, Steam Gens Rule 1146 and 1146.1 LPG, Propane, Butane 1000 gals 4.400 4.260
Boilers, Heaters, Steam Gens Rule 1146 and 1146.1 Diesel Light Dist. (0.05% S) 1000 gals 6.420 6.210
Boilers, Heaters, Steam Gens Rule 1146 and 1146.1 Refinery Gas mmcf 51.520 49.840
Boilers, Heaters, Steam Gens Bituminous Coal tons burned RV 4.800
Boiler, Heater, Steam Gen (Rule 1146.1) Natural Gas mmcf 130.000 39.460
Boiler, Heater, Steam Gen (Rule 1146.1) Refinery Gas mmcf RV 41.340
Boiler, Heater, Steam Gen (Rule 1146.1) LPG, Propane, Butane 1000 gallons RV 3.530
Boiler, Heater, Steam Gen (Rule 1146.1) Diesel Light Dist (0.05%) 1000 gallons RV 5.150
Boiler, Heater, Steam Gen (Rule 1146) Natural Gas mmcf 47.750 47.750
Boiler, Heater, Steam Gen (Rule 1146) Refinery Gas mmcf 50.030 50.030
Boiler, Heater, Steam Gen (Rule 1146) LPG, Propane, Butane 1000 gallons 4.280 4.280
Boiler, Heater, Steam Gen (Rule 1146) Diesel Light Dist (0.05%) 1000 gallons 6.230 6.230
Boiler, Heater, Steam Gen (R1146, <90,000 Therms) Natural Gas mmcf RV 47.750
Boiler, Heater, Steam Gen (R1146, <90,000 Therms) Refinery Gas mmcf RV 50.030
Boiler, Heater, Steam Gen (R1146, <90,000 Therms) LPG, Propane, Butane 1000 gallons RV 4.280

* RV = Reported Value
** Does not include ceramic, clay, cement or brick kilns or metal melting, heat treating or glass melting furnaces.

Nitrogen Oxides


Basic Equipment


Fuel

"Throughput" Units Starting Ems Factor * Ending Ems Factor *
Boiler, Heater, Steam Gen (R1146, <90,000 Therms) Diesel Light Dist (0.05%) 1000 gallons RV 6.230
Boiler, Heater, Steam Gen (R1146.1, <18,000 Therms) Natural Gas mmcf RV 39.460
Boiler, Heater, Steam Gen (R1146.1, <18,000 Therms) Refinery Gas mmcf RV 41.340
Boiler, Heater, Steam Gen (R1146.1, <18,000 Therms) LPG, Propane, Butane 1000 gallons RV 3.530
Boiler, Heater, Steam Gen (R1146.1, <18,000 Therms) Diesel Light Dist (0.05%) 1000 gallons RV 5.150
Boiler, Heater R1109 (Petr Refin) Refinery Gas mmbtu 0.100 0.030
Boilers, Heaters, Steam Gens, (Petr Refin) Natural Gas mmcf 105.000 31.500
Boilers, Heaters, Steam Gens, (Petr Refin) Refinery Gas mmcf 110.000 33.000
Boilers, Heaters, Steam Gens, Unpermitted Natural Gas mmcf 130.000 32.500
Boilers, Heaters, Steam Gens, Unpermitted LPG, Propane, Butane 1000 gallons RV 3.200
Boilers, Heaters, Steam Gens (New or Modified, and subject to BACT, after the start year as determined pursuant to Rule 2002(c)(1)) Natural Gas mmcf 38.460 38.460

* RV = Reported Value
** Does not include ceramic, clay, cement or brick kilns or metal melting, heat treating or glass melting furnaces.

Nitrogen Oxides

Basic Equipment


Fuel

"Throughput" Units Starting Ems Factor * Ending Ems Factor *
Boilers, Heaters, Steam Gens (New or Modified, and subject to BACT, after the start year as determined pursuant to Rule 2002(c)(1)) Refinery Gas mmbtu 0.035 0.035
Boilers, Heaters, Steam Gens (New or Modified, and subject to BACT, after the start year as determined pursuant to Rule 2002(c)(1)) LPG, Propane, Butane 1000 gallons 3.55 3.55
Boilers, Heaters, Steam Gens (New or Modified, and subject to BACT, after the start year as determined pursuant to Rule 2002(c)(1)) Diesel Light Dist (0.05%) 1000 gallons 5.26 5.26
Boilers, Heaters, Steam Gens, Unpermitted Diesel Light Dist (0.05%) 1000 gallons RV 4.750
Catalyst Manufacturing Catalyst Mfg tons of catalyst produced RV 1.660
Catalyst Manufacturing Catalyst Mfg tons of catalyst produced RV 2.090
Cement Kilns Natural Gas mmcf 130.000 19.500
Cement Kilns Diesel Light Dist. (0.05% S) 1000 gals RV 2.850
Cement Kilns Kilns-Dry Process tons cement produced RV 0.750
Cement Kilns Bituminous Coal tons burned RV 4.800
Cement Kilns Tons Clinker tons clinker RV 2.73

* RV = Reported Value
** Does not include ceramic, clay, cement or brickkilns or metal melting, heat treating or glass melting furnaces.

Nitrogen Oxides Basic Equipment

Fuel

"Throughput" Units Starting Ems Factor * Ending Ems Factor *
Ceramic and Brick Kilns (Preheated Combustion Air) Natural Gas mmcf 213.000 170.400
Ceramic and Brick Kilns (Preheated Combustion Air) Diesel Light Distillate (.05%) 1000 gallons RV 24.905
Ceramic and Brick Kilns (Preheated Combustion Air) LPG 1000 gallons RV 16.778
Ceramic Clay Mfg Drying tons input to process RV 1.114
CO Boiler Refinery Gas mmbtu 0.030
Cogen, Industr Coke tons burned RV 3.682
Electric Generation, Commercial Institutional Boiler Distillate Oil 1000 gallons 6.420 6.210
Composite Internal Combustion Waste Fuel Oil 1000 gals burned RV 31.340
Curing and Drying Ovens Natural Gas mmcf 130.000 32.500
Curing and Drying Ovens LPG, Propane, Butane 1000 gals RV 3.200
Delacquering Furnace Natural Gas mmcf 182.2 182.2
Fiberglass Textile-Type Fibr tons of material processed RV 1.860
Fluid Catalytic Cracking Unit Fresh Feed 1000 BBLS fresh feed RV 6.040
Fugitive Emission Not Classified tons product RV 0.087
Furnace Process Carbon Black tons produced RV 38.850
Furnace Suppressor Furnace Suppressor unknown RV 0.800

* RV = Reported Value
** Does not include ceramic, clay, cement or brick kilns or metal melting, heat treating or glass melting furnaces.

Nitrogen Oxides Basic Equipment Fuel "Throughput" Units Starting Ems Factor * Ending Ems Factor *
Glass Fiber Furnace Mineral Products tons product produced RV 4.000
Glass Melting Furnace Flat Glass tons of glass pulled RV 4.000
Glass Melting Furnace Tableware Glass tons of glass pulled RV 5.680
Glass Melting Furnaces Container Glass tons of glass produced 4.000 1.2
ICEs, Permitted (Rule 1110.1 and 1110.2) Natural Gas mmcf 2192.450 217.360
ICEs Permitted (Rule 1110.2) Natural Gas mmcf RV 217.360
ICEs, Permitted (Rule 1110.1 and 1110.2) LPG, Propane, Butane 1000 gals RV 19.460
ICEs, Permitted (Rule 1110.1 and 1110.2) Gasoline 1000 gals RV 20.130
ICEs, Permitted (Rule 1110.1 and 1110.2) Diesel Oil 1000 gals RV 31.340
ICEs, Exempted per Rule 1110.2 All Fuels RV RV
ICEs, Exempted per Rule 1110.2 and subject to Rule 1110.1 All Fuels RV RV

* RV = Reported Value
** Does not include ceramic, clay, cement or brick kilns or metal melting, heat treating or glass melting furnaces.

Nitrogen Oxides Basic Equipment

Fuel

"Throughput" Units Starting Ems Factor * Ending Ems Factor *
ICEs, Unpermitted All Fuels RV RV
In Process Fuel Coke tons burned RV 24.593
Incinerators Natural Gas mmcf 130.000 104.000
Industrial Propane 1000 gallons RV 20.890
Industrial Gasoline 1000 gallons RV 21.620
Industrial Dist.Oil/Diesel 1000 gallons RV 33.650
Inorganic Chemicals, H2SO4 Chamber General tons pure acid produced RV 0.266
Inorganic Chemicals, H2SO4 Contact Absrbr 98.0% Conv tons 100% H2S04 RV 0.376
Iron/Steel Foundry Steel Foundry, Elec Arc Furn tons metal processed RV 0.045
Metal Heat Treating Furnace Natural Gas mmcf 130.000 104.000
Metal Heat Treating Furnace Diesel Light Distillate (.05%) 1000 gallons RV 15.200
Metal Heat Treating Furnace LPG 1000 gallons RV 10.240
Metal Forging Furnace (Preheated Combustion Air) Natural Gas mmcf 213.000 170.400
Metal Forging Furnace (Preheated Combustion Air) Diesel Light Distillate (.05%) 1000 gallons RV 24.905
Metal Forging Furnace (Preheated Combustion Air) LPG 1000 gallons RV 16.778
Metal Melting Furnaces Natural Gas mmcf 130.000 65.000
Metal Melting Furnaces LPG, Propane, Butane 1000 gals RV 6.400

* RV = Reported Value
** Does not include ceramic, clay, cement or brick kilns or metal melting, heat treating or glass melting furnaces.

Nitrogen Oxides Basic Equipment

Fuel

"Throughput" Units Starting Ems Factor * Ending Ems Factor *
Miscellaneous bbls-processed RV 1.240
Natural Gas Production Not Classified mmcf gas RV 6.320
Nonmetallic Mineral Sand/Gravel tons product RV 0.030
NSPS Refinery Gas mmbtu RV 0.030
Other Bact Heater (24F-1) Natural Gas mmcf RV RV
Other Heater (24F-1) Pressure Swing Absorber Gas mmcf RV RV
Ovens, Kilns, Calciners, Dryers, Furnaces** Natural Gas mmcf 130.000 65.000
Ovens, Kilns, Calciners, Dryers, Furnaces** Diesel Light Dist. (0.05% S) 1000 gals RV 9.500
Paint Mfg, Solvent Loss Mixing/Blending tons solvent RV 45.600
Petroleum Refining Asphalt Blowing tons of asphalt produced RV 45.600
Petroleum Refining, Calciner Petroleum Coke Calcined Coke RV 0.971
Plastics Prodn Polyester Resins tons product RV 106.500
Pot Furnace Lead Battery lbs Niter 0.077 0.062
Process Specific ID# 012183 (unknown process units) RV 240.000
Process Specific SCC 30500311 tons produced RV 0.140
Process Specific ID 14944 (unknown process units) RV 0.512

* RV = Reported Value
** Does not include ceramic, clay, cement or brick kilns or metal melting, heat treating or glass melting furnaces.

Nitrogen Oxides Basic Equipment

Fuel

"Throughput" Units Starting Ems Factor * Ending Ems Factor *
SCC 39090003 RV 170.400
Sec. Aluminum Sweating Furnace tons produced RV 0.300
Sec. Aluminum Smelting Furnace tons metal produced RV 0.323
Sec. Aluminum Annealing Furnace mmcf 130.000 65.000
Sec. Aluminum Boring Dryer tons produced RV 0.057
Sec. Lead Smelting Furnace tons metal charged RV 0.110
Sec. Lead Smelting Furnace tons metal charged RV 0.060
Sodium Silicate Furnace Water Glass Tons Glass Pulled RV 6.400
Steel Hot Plate Furnace Natural Gas mmcf 213.000 106.500
Steel Hot Plate Furnace Diesel Light Distillate (.05%) 1000 gallons 31.131 10.486
Steel Hot Plate Furnace LPG, Propane, Butane 1000 gallons 20.970 10.486
Surface Coal Mine Haul Road tons coal RV 62.140
Tail Gas Unit hours of operation RV RV
Turbines Butane 1000 Gallons RV 5.700
Turbines Diesel Oil 1000 gals RV 8.814
Turbines Refinery Gas mmcf RV 62.275
Turbines Natural Gas mmcf RV 61.450
Turbines - Peaking Unit Natural Gas mmcf RV RV
Turbines - Peaking Unit Dist. Oil/Diesel 1000 gallons RV RV
Utility Boiler Digester/Landfill Gas mmcf 52.350 10.080
Turbine Natural Gas mmcf RV 61.450
Turbine Fuel Oil 1000 gallons RV 8.810

* RV = Reported Value
** Does not include ceramic, clay, cement or brick kilns or metal melting, heat treating or glass melting furnaces.

Nitrogen Oxides Basic Equipment

Fuel

"Throughput" Units Starting Ems Factor * Ending Ems Factor *
Turbine Dist.Oil/Diesel 1000 gallons RV 3.000
Utility Boiler Burbank Natural Gas mmcf 148.670 17.200
Utility Boiler Burbank Residual Oil 1000 gallons 20.170 2.330
Utility Boiler, Glendale Natural Gas mmcf 140.430 16.000
Utility Boiler, Glendale Residual Oil 1000 gallons 20.160 2.290
Utility Boiler, LADWP Natural Gas mmcf 86.560 15.830
Utility Boiler, LADWP Residual Oil 1000 gallons 12.370 2.260
Utility Boiler, LADWP Digester Gas mmcf 52.350 10.080
Utility Boiler, LADWP Landfill Gas mmcf 37.760 6.910
Utility Boiler, Pasadena Natural Gas mmcf 195.640 18.500
Utility Boiler, Pasadena Residual Oil 1000 gallons 28.290 2.670
Utility Boiler, SCE Natural Gas mmcf 74.860 15.600
Utility Boiler, SCE Residual Oil 1000 gallons 10.750 2.240

* RV = Reported Value
** Does not include ceramic, clay, cement or brick kilns or metal melting, heat treating or glass melting furnaces.

Table 2
RECLAIM SOx Emission Factors

Sulfur Oxides


Basic Equipment


Fuel

"Throughput" Units Starting Emission Factor * Ending Emission Factor *
Air Blown Asphalt hours of operation RV RV
Asphalt Concrete Cold Ag Handling tons produced RV 0.032
Calciner Petroleum Coke Calcined Coke RV 0.000
Catalyst Regeneration hours of operation RV RV
Cement Kiln Distillate Oil 1000 gallons RV RV
Cement Mfg Kilns, Dry Process tons produced RV RV
Claus Unit pounds RV RV
Cogen Coke pounds per ton RV RV
Non Fuel Use hours of operation RV RV
External Combustion Equipment / Incinerator Natural Gas mmcf RV 0.830
External Combustion Equip/Incinerator LPG, Propane, Butane 1000 gallons RV 4.600
External Combustion Equip/Incinerator Diesel Light Dist. (0.05% S) 1000 gallons 7.00 5.600
External Combustion Equip/Incinerator Residual Oil 1000 gallons 8.00 6.400
External Combustion Equip/Incinerator Refinery Gas mmcf RV 6.760
Fiberglass Recuperative Furn, Textile-Type Fiber tons produced RV 2.145
Fluid Catalytic Cracking Units 1000 bbls refinery feed RV 13.700
Glass Mfg, Forming/Fin Container Glass RV RV

* RV = Reported Value

Sulfur Oxides


Basic Equipment

Fuel "Throughput" Units Starting Emission Factor * Ending Emission Factor *
Grain Milling Flour Mill tons Grain Processed RV RV
ICEs Natural Gas mmcf RV 0.600
ICEs LPG, Propane, Butane 1000 gallons RV 0.350
ICEs Gasoline 1000 gallons RV 4.240
ICEs Diesel Oil 1000 gallons 6.24 4.990
Industrial Cogeneration, Bituminous Coal tons produced RV RV
Industrial (scc 10200804) Cogeneration, Coke tons produced RV RV
Inorganic Chemcals General, H2SO4 Chamber tons produced RV RV
Inorganic Chemcals Absrbr 98.0% Conv, H2SO4 Contact tons produced RV RV
Inprocess Fuel Cement Kiln/Dryer, Bituminous Coal tons produced RV RV
Iron/Steel Foundry Cupola, Gray Iron Foundry tons produced RV 0.720
Melting Furnace, Container Glass tons produced RV RV
Mericher Alkyd Feed hours of operation RV RV
Miscellaneous Not Classified tons produced RV 0.080
Miscellaneous Not Classified tons produced RV 0.399
Natural Gas Production Not Classified mmcf RV 527.641
Organic Chemical (scc 30100601) tons produced RV RV
Petoluem Refin (scc30600602) Column Condenser RV 1.557
Petoluem Refin (scc30600603) Column Condenser RV 1.176

* RV = Reported Value

Sulfur Oxides


Basic Equipment


Fuel

"Throughput" Units Starting Emission Factor * Ending Emission Factor *
Refinery Process Heaters LPG fired 1000 gal RV 2.259
Pot Furnace Lead Battery lbs Sulfur 0.133 0.106
Sec. Lead Reverberatory, Smelting Furnace tons produced RV RV
Sec. Lead Smelting Furnace, Fugitiv tons produced RV 0.648
Sour Water Oxidizer hours of operation RV RV
Sulfur Loading 1000 bbls RV RV
Sour Water Oxidizer 1000 bbls fresh feed RV RV
Sour Water Coker 1000 bbls fresh feed RV RV
Sodium Silicate Furnace tons of glass pulled RV RV
Sulfur Plant hours of operation RV RV
Tail gas unit hours of operation RV RV
Turbines Refinery Gas mmcf RV 6.760
Turbines Natural Gas mmcf RV 0.600
Turbines Diesel Oil 1000 gal 6.24 4.990
Other Heater ( 24F-1) Pressure Swing Absorber Gas mmcf RV RV

* RV = Reported Value


SCAQMD RULE 2002 ALLOCA FOR OXID OF NITRO (NOx) & OXID OF SULF (SOx)               
LAST REVISED 12/07/95               
               
               
                        (Adopted October 15, 1993) (Amended March 10, 1995) 
                                                 (Amended December 7, 1995)

          
          RULE 2002.  ALLOCATIONS FOR OXIDES OF NITROGEN (NOx) AND OXIDES
                      OF SULFUR (SOx)

          (a) Purpose

              The purpose of this rule is to establish the methodology for
              calculating facility Allocations for Oxides of Nitrogen (NOx) 
              and Oxides of Sulfur (SOx).

          (b) RECLAIM Allocations

              (1) RECLAIM Allocations will begin in 1994.

              (2) An annual Allocation will be issued to each facility for
                  each compliance year from 1994 to 2010, inclusive.  All
                  Allocations will be established by the Facility Permit 
                  issued pursuant to Rule 2006 - Permits.

              (3) Allocations for each year after 2003 are equal to the
                  facility's ending Allocation, as referenced on the initial
                  Facility Permit unless, as part of the AQMP process, and 
                  pursuant to Rule 2015 (b)(1), (b)(3), (b)(4), or (c), the 
                  District Governing Board determines that additional 
                  reductions are necessary to meet air quality standards, 
                  taking into consideration the current and projected state 
                  of technology available and cost-effectiveness to achieve 
                  further emission reductions.

          (c) Establishment of Starting Allocations

              ( 1) The starting Allocation for RECLAIM NOx and SOx 
                   facilities initially permitted by the District prior to 
                   October 15, 1993, shall be determined by the Executive 
                   Officer utilizing the following methodology:

                   Starting Allocation  =  ä[A X B1]  +  ERCs +  External
                   Offsets, where

                   A =  the throughput for each NOx and SOx source or process 
                        unit in the facility for the maximum throughput year 
                        from 1989 to 1992, inclusive; and

                   B1 = the applicable starting emission factor for the 
                        subject source or process unit, as specified in 
                        Table 1 or Table 2.

              ( 2) (A) Use of 1992 data is subject to verification and
                       revision by the Executive Officer or designee to 
                       assure validity and accuracy.

                   (B) The maximum throughput year will be determined by 
                       the Executive Officer or designee from throughput 
                       data reported through annual emissions reports 
                       submitted pursuant to Rule 301 - Permit Fees, or may 
                       be designated by the permit holder prior to issuance 
                       of the Facility Permit.
                 
                   (C) To determine the applicable starting emission factor 
                       in Table 1 or Table 2, the Executive Officer or 
                       designee will categorize the equipment at each 
                       facility based on information relative to hours of 
                       operation, equipment size, heating capacity, and 
                       permit information submitted pursuant to Rule 201 - 
                       Permit to Construct, and other relevant parameters 
                       as determined by the Executive Officer or designee.  
                       No information used for purposes of this subparagraph 
                       may be inconsistent with any information or statement 
                       previously submitted on behalf of the facility to the
                       District, including but not limited to information 
                       and statements previously submitted pursuant to 
                       Rule 301 - Permit Fees, unless the facility can 
                       demonstrate, by clear and convincing documentation, 
                       that such information or statement was inaccurate.

                   (D) Throughput associated with each piece of equipment 
                       or NOx or SOx source will be multiplied by the 
                       starting emission factors specified in Table 1 or 
                       Table 2.  If a lower emission factor was utilized for 
                       a given piece of equipment or NOx or SOx source 
                       pursuant to Rule 301 - Permit Fees, than the factor 
                       in Table 1 or Table 2, the lower factor will be used 
                       for determining that portion of the Allocation.

                   (E) The fuel heating value may be considered in 
                       determining Allocations and will be set to 1.0 
                       unless the Facility Permit holder demonstrates that 
                       it should receive a different value.

              ( 3) All NOx and SOx ERCs held by a RECLAIM Facility Permit
                   holder shall be reissued as RTCs.  RECLAIM facilities 
                   will have these RTCs added to their starting Allocations.  
                   RTCs generated from the conversion of ERCs shall have a 
                   zero rate of reduction for the year 1994 through the 
                   year 2000.  Such RTCs shall have a cumulative rate of 
                   reduction for the years 2001, 2002, and 2003, equal to 
                   the percentage inventory adjustment factor applied to
                   2003 Allocations pursuant to paragraph (e)(1) of this 
                   rule.

              ( 4) Non-RECLAIM facilities may elect to have their ERCs
                   converted to RTCs and listed on the RTC Listing 
                   maintained by the Executive Officer or designee pursuant 
                   to Rule 2007 - Trading Requirements, so long as the 
                   written request is filed before July 1, 1994.  Such RTCs 
                   will be assigned to the trading zone in which the 
                   generating facility is located.  RTCs generated from the
                   conversion of ERCs shall have a zero rate of reduction 
                   for the year 1994 through the year 2000.  Such RTCs shall 
                   have a cumulative rate of reduction for the years, 2001, 
                   2002, and 2003, equal to the percentage inventory 
                   adjustment factor applied to 2003 Allocations pursuant to 
                   paragraph (e)(1) of this rule.

              ( 5) External offsets provided pursuant to Regulation XIII -
                   New Source Review, not including any offsets in excess 
                   of a 1 to 1 ratio, will be added to the starting 
                   Allocation pursuant to paragraph (c)(1) provided:

                   (A) The offsets were not received from either the 
                       Community Bank or the Priority Reserve.

                   (B) External offsets will only be added to the starting
                       Allocation to the extent that the Facility Permit 
                       holder demonstrates that they have not already been 
                       included in the starting Allocation or as an ERC.  
                       RTCs issued for external offsets shall not include 
                       any offsets in excess of a 1 to 1 ratio required 
                       under Regulation XIII - New Source Review.

                   (C) RTCs generated from the conversion of external 
                       offsets shall have a zero rate of reduction for 
                       the year 1994 through the year 2000.  These RTCs 
                       shall have a cumulative rate of reduction for the 
                       years 2001, 2002, and 2003, equal to the percentage
                       inventory adjustment factor applied to 
                       2003 Allocations pursuant to paragraph (e)(1) of 
                       this rule.

                   (D) Existing facilities with units that have Permits to
                       Construct issued pursuant to Regulation II - Permits, 
                       dated on or after January 1, 1992, or existing 
                       facilities which have, between January 1, 1992 and 
                       October 15, 1993, installed air pollution control 
                       equipment that was exempt from offset requirements
                       pursuant to Rule 1304 (a)(5), shall have their 
                       starting Allocations increased by the total external 
                       offsets provided, or the amount that would have been 
                       offset if the exemption had not applied.

                   (E) Existing facilities with units whose reported 
                       emissions are below capacity due to phased 
                       construction, and/or where the Permit to Operate 
                       issued pursuant to Regulation II - Permits, was
                       issued after January 1, 1992, shall have their 
                       starting Allocations increased by the total external 
                       offsets provided.

              ( 6) If a Facility Permit holder can demonstrate that its 
                   1994 Allocation is less than the 1992 emissions reported 
                   pursuant to Rule 301 - Permit Fees, and that the facility 
                   was, in 1992, operating in compliance with all applicable 
                   District rules in effect as of December 31, 1993, the 
                   facility's starting Allocation will be equal to the 1992 
                   reported emissions.

              ( 7) For new facilities initially totally permitted on or 
                   after January 1, 1993 but prior to October 15, 1993, the 
                   starting Allocation shall be equal to the external 
                   offsets provided by the facility to offset emission 
                   increases at the facility pursuant to Regulation XIII - 
                   New Source Review, not including any offsets in excess of 
                   a 1 to 1 ratio.

              ( 8) The Allocation for new facilities initially totally
                   permitted on and after October 15, 1993, shall be equal 
                   to the total RTCs provided by the facility to offset 
                   emission increases at the facility pursuant to Rule 2005 
                   - New Source Review for RECLAIM.

              ( 9) The starting Allocation for facilities which enter the
                   RECLAIM program pursuant to Rule 2001 - Applicability, 
                   shall be determined by the methodology in 
                   paragraph (c)(1) of this rule.  The most recent two years 
                   reported emission fee data filed pursuant to  Rule 301 
                   - Permit Fees, may be used if 1989 through 1992 emission 
                   fee data is not available.  For facilities lacking 
                   reported emission fee data, the Allocation shall be equal 
                   to the external offsets provided pursuant to 
                   Regulation XIII - New Source Review, not including any 
                   offsets in excess of a 1 to 1 ratio.  The Allocation 
                   shall not include any emission offsets received from 
                   either the Community Bank or the Priority Reserve.

              (10) A facility may not receive more than one set of
                   Allocations.

              (11) A facility that is no longer holding a valid District
                   permit on January 1, 1994 will not receive an Allocation, 
                   but may, if authorized by Regulation XIII, apply for ERCs.

              (12) Clean Fuel Adjustment to Starting Allocation

                   Any refiner who is required to make modifications to 
                   comply with CARB Phase II reformulated gasoline 
                   production (California Code of Regulations, Title 13, 
                   Sections 2250, 2251.5, 2252, 2260, 2261, 2262, 2262.2, 
                   2262.3, 2262.4, 2262.5, 2262.6, 2262.7, 2263, 2264, 
                   2266, 2267, 2268, 2269, 2270, and 2271) or federal
                   requirements (Federal Clean Air Act, Title II, Part A, 
                   Section 211; 42 U.S.C. Section 7545) may receive (an) 
                   increase(s) in his Allocations except to the extent that 
                   there is an increase in maximum rating of the new or 
                   modified equipment.  Each facility requesting an increase 
                   to Allocations shall submit an application for permit 
                   amendment specifying the necessary modifications and
                   tentative schedule for completion.  The Facility Permit 
                   holder shall establish the amount of emission increases 
                   resulting from the reformulated gasoline modifications 
                   for each year in which the increase in Allocations is 
                   requested.  The increase to its Allocations will be 
                   issued contemporaneously with the modification according 
                   to a schedule approved by the Executive Officer or 
                   designee (i.e., 1994 through 1997 depending on the 
                   refinery).  Each increase to the Allocations shall be 
                   equal to the increased emissions resulting from the 
                   modifications solely to comply with the state or federal 
                   reformulated gasoline requirements at the refinery or 
                   facility producing hydrogen for reformulated gasoline 
                   production, and shall be established according to 
                   present and future compliance limits in current District 
                   rules or permits.  Allocation increases for each refiner
                   pursuant to this paragraph, shall not exceed 5 percent 
                   of the refiner's total starting Allocation, unless any 
                   refiner emits less than 0.0135 tons of NOx per thousand 
                   barrels of crude processed, in which case the Allocation 
                   increases for such refiner shall not exceed 20 percent of 
                   that refiner's starting Allocation.  The emissions per 
                   amount of crude processed will be determined on the basis 
                   of information reported to the District pursuant to 
                   Rule 301 - Permit Fees, for the same calendar year as
                   the facility's peak activity year for their NOx starting
                   Allocation.

          (d) Establishment of Year 2000 Allocations

              (1) (A) The year 2000 Allocations for RECLAIM NOx and SOx
                      facilities will be determined by the Executive Officer 
                      or designee utilizing the following methodology:

                      Year 2000 Allocation = ä [A X B2] + RTCs created from 
                      ERCs + External Offsets, where

                      A =  the throughput for each NOx or SOx source or 
                           process unit in the facility for the maximum 
                           throughput year from 1987 to 1992, inclusive, as 
                           reported pursuant to Rule 301 - Permit Fees; and

                      B2 = the applicable Tier I year Allocation emission
                           factor for the subject source or process unit, as 
                           specified in Table 1 or Table 2.

                  (B) The maximum throughput year will be determined by the
                      Executive Officer or designee from throughput data 
                      reported through annual emissions reports pursuant to 
                      Rule 301 - Permit Fees, or may be designated by the 
                      permit holder prior to issuance of the Facility 
                      Permit.

                  (C) To determine the applicable emission factor in Table 1
                      or Table 2, the Executive Officer or designee will 
                      categorize the equipment at each facility based on 
                      information on hours of operation, equipment size, 
                      heating capacity, and permit information submitted 
                      pursuant to Rule 201 - Permit to Construct, and other 
                      parameters as determined by the Executive Officer or
                      designee.  No information used for purposes of this 
                      subparagraph may be inconsistent with any information 
                      or statement previously submitted on behalf of the 
                      facility to the District including but not limited to 
                      information and statements previously submitted
                      pursuant to Rule 301 - Permit Fees, unless the 
                      facility can demonstrate, by clear and convincing 
                      documentation, that such information or statement was 
                      inaccurate.

                  (D) Throughput associated with each piece of combustion
                      equipment or NOx or SOx source will be multiplied by 
                      the Tier I emission factor specified in Table 1 or 
                      Table 2.  If a factor lower than the factor in Table 1 
                      or Table 2 was utilized for a given piece of equipment 
                      or NOx or SOx source pursuant to Rule 301, the lower 
                      factor will be used for determining that portion of 
                      the Allocation.

                  (E) The fuel heating value may be considered in 
                      determining Allocations and will be set to 1.0 unless 
                      the Facility Permit holder demonstrates that it should 
                      receive a different value.

                  (F) The year 2000 Allocation is the sum of the resulting
                      products for each piece of equipment or NOx or SOx 
                      source multiplied by any inventory adjustment pursuant 
                      to paragraph (d)(4) of this rule.

              (2) For facilities existing prior to October 15, 1993 which
                  enter RECLAIM after October 15, 1993, the year 2000 
                  Allocation will be determined according to 
                  paragraph (d)(1).  The most recent two years reported 
                  emission fee data filed pursuant to Rule 301 - Permit 
                  Fees, may be used if 1989 through 1992 emission fee data 
                  is not available.  For facilities lacking reported
                  emission fee data, the Allocation shall be equal to their
                  external offsets provided pursuant to Regulation XIII - 
                  New Source Review, not including any offsets in excess of 
                  a 1 to 1 ratio.

              (3) No facility shall have a year 2000 Allocation [calculated
                  pursuant to subdivision (d)] greater than the starting 
                  Allocation [calculated pursuant to subdivision (c)].

              (4) If the sum of all RECLAIM facilities' year 2000 
                  Allocations differs from the year 2000 projected inventory 
                  for these sources under the 1991 AQMP, the Executive 
                  Officer or designee will establish a percentage inventory 
                  adjustment factor that will be applied to adjust each 
                  facility's year 2000 Allocation.  The inventory adjustment 
                  will not apply to RTCs generated from ERCs or external 
                  offsets.

          (e) Allocations for the Year 2003

              (1) The 2003 Allocations will be determined by the Executive
                  Officer or designee applying a percentage inventory 
                  adjustment to reduce each facility's unadjusted year 2000 
                  Allocation so that the sum of all RECLAIM facilities' 2003 
                  Allocations will equal the 1991 AQMP projected inventory 
                  for RECLAIM sources for the year 2003, corrected based on 
                  actual facility data reviewed for purposes of issuing 
                  Facility Permits and to reflect the highest year of actual 
                  Basin-wide economic activity for RECLAIM sources 
                  considered as a whole during the years 1987 through 1992.

              (2) No facility shall have a 2003 Allocation (calculated
                  pursuant this subdivision) greater than the year 2000 
                  Allocation [calculated pursuant to subdivision (d)].

          (f) Annual Allocations for NOx and SOx

              (1) Allocations for the years between 1994 and 2000, for
                  RECLAIM NOx and SOx facilities shall be determined by a 
                  straight line rate of reduction between the starting 
                  Allocation and the year 2000 Allocation.  For the years 
                  2001 and 2002, the Allocations shall be determined by a 
                  straight line rate of reduction between the year 2000 and 
                  year 2003 Allocations.  Allocations for each year after 
                  2003 are equal to the facility's ending Allocation, as 
                  referenced on the initial Facility Permit, unless as part 
                  of the AQMP process, and pursuant to Rule 2015 (b)(1), 
                  (b)(3), (b)(4), or (c), the District Governing Board
                  determines that additional reductions are necessary to 
                  meet air quality standards, taking into consideration the 
                  current and projected state of technology available and 
                  cost-effectiveness to achieve further emission reductions.

              (2) New facilities initially totally permitted, on and after
                  October 15, 1993, shall not have a rate of reduction.  The
                  Facility Permit for such facilities will require the 
                  Facility Permit holder to, at the commencement of each 
                  compliance year, hold RTCs equal to the amount of RTCs 
                  provided as offsets pursuant to Rule 2005.

              (3) Increases to Allocations for permits issued for Clean Fuel
                  adjustments pursuant to paragraph (c)(12), shall be added 
                  to each year's Allocation.

          (g) High Employment/Low Emissions (HILO) Facility

              The Executive Officer or designee will establish a HILO bank
              funded with the following maximum total annual emission
              Allocations:

              (1) 91 tons per year of NOx

              (2) 91 tons per year of SOx

              (3) After January 1, 1997, new facilities may apply to the 
                  HILO bank in order to obtain non-tradeable RTCs.  Requests 
                  will be processed on a first-come, first-served basis, 
                  pending qualification.

              (4) When credits are available, annual Allocations will be
                  granted for the year of application and all subsequent 
                  years until the year 2010.

              (5) HILO facilities receiving such Allocations from the HILO
                  bank must verify their HILO status on an annual basis 
                  through their APEP report.

              (6) Failure to qualify will result in all subsequent years'
                  credits being returned to the HILO bank.

              (7) Facilities failing to qualify for the HILO bank 
                  Allocations may reapply at any time during the next or 
                  subsequent compliance year when credits are available.

          (h) Non-Tradeable Allocation Credits

              (1) Any existing RECLAIM facility with reported emissions
                  pursuant to Rule 301 - Permit Fees, in either 1987, 1988, 
                  or 1993, greater than its starting Allocation, shall be 
                  assigned non-tradeable credits for the first three years 
                  of the program which shall be determined according to the 
                  following methodology:

                  Non-tradeable credit for NOx and SOx:

                          Year 1  =  (ä [A X B1])  -  1994 Allocation;

                  Where:

                          A  =  the throughput for each NOx or SOx source 
                                or process unit in the facility from the 
                                single maximum throughput year from 1987, 
                                1988, or 1993; and

                          B1  = the applicable starting emission factor, 
                                as specified in Table 1 or Table 2.

                  Year 2  =  Year 1 non-tradeable credits X  0.667

                  Year 3  =  Year 1 non-tradeable credits X  0.333

                  Year 4 and subsequent years  =  Zero non-tradeable credit.

              (2) The use of non-tradeable credits shall be subject to the
                  following requirements:

                  (A) Non-tradeable credits may only be used for an increase
                      in throughput over that used to determine the 
                      facility's starting Allocation.  Non-tradeable credits 
                      may not be used for emissions increases associated 
                      with equipment modifications, change in feedstock or 
                      raw materials, or any other changes except increases
                      in throughput.  The Executive Officer or designee may 
                      impose Facility Permit conditions necessary to ensure 
                      compliance with this subparagraph.

                  (B) The use of activated non-tradeable credits shall be
                      subject to a non-tradeable RTC mitigation fee, as 
                      specified in Rule 301 subdivision (n).

                  (C) In order to utilize non-tradeable credits, the 
                      Facility Permit holder shall submit a request to the 
                      Executive Officer or designee in writing, including a 
                      demonstration that the use of the non-tradeable 
                      credits complies with all requirements of this
                      paragraph, pay any fees required pursuant to Rule 301 
                      - Fees, and have received written approval from the 
                      Executive Officer or designee for their use.  The 
                      Executive Officer or designee shall deny the request 
                      unless the Facility Permit holder demonstrates
                      compliance with all requirements of this paragraph.  
                      The Executive Officer or designee shall, in writing, 
                      approve or deny the request within three business days 
                      of submittal of a complete request and notify the 
                      Facility Permit holder of the decision.  If the 
                      request is denied, the Executive Officer or designee 
                      will refund the mitigation fee.

                  (D) In the event that a facility transfers any RTCs for 
                      the year in which non-tradeable credits have been 
                      issued, the non-tradeable credit Allocation shall be 
                      invalid, and is no longer available to the facility.
                                       
                                       
                                   Table 1

                         RECLAIM NOx Emission Factors
                                                        
                                    
                                   Fuel      "Through"    Starting  Ending
       Nitrogen Oxides                          put"      Emission  Emission 
       Basic Equipment                         Units      Factor*   Factor*
   
   Afterburner (Direct Flame    Natural Gas    mmcf       130.000   39.000
   and Catalytic)

   Afterburner (Direct Flame    LPG, Propane   1000 gals     RV      3.840
   and Catalytic)               Butane

   Afterburner (Direct Flame    Diesel         1000 gals     RV      5.700
   and Catalytic)

   Agr Chem-Nitric Acid         Process-       tons pure     RV      1.440
                                Absrbr         acid 
                                Tailgas/Nw     produced

   Agricultural Chem -          Process        tons          RV      1.650
   Ammonia                                     produced
   
   Air Ground Turbines          Air Ground     (unknown      RV      1.860
                                Turbines       process
                                               units)
   
   Ammonia Plant                Neutralizer    tons          RV      2.500
                                Fert, Ammon    produced
                                Nit

   Asphalt Heater, Concrete     Natural Gas    mmcf       130.000    65.000
   
   Asphalt Heater, Concrete     Fuel Oil       1000 gals     RV       9.500
                                                    
   Asphalt Heater, Concrete     LPG            1000 gals     RV       6.400
                                                                                         
   Boiler, Heater, R1109        Natural Gas    mmbtu        0.100     0.030
   (Petr Refin)

   Boiler, Heater, R1109        Fuel Oil       mmbtu        0.100     0.030
   (Petr Refin)

   Boiler, Heater, R1146        Natural Gas    mmbtu        0.045     0.045
   (Petr Refin)

   Boiler, Heater, R1146        Fuel Oil       mmbtu        0.045     0.045
   (Petr Refin)

   Boiler, Heater, R1146        Refinery Gas   mmbtu        0.045     0.045
   (Petr Refin)

   Boilers, Heaters, Steam      Natural Gas    mmcf        49.180    47.570
   Gens Rule 1146 and
   1146.1

   Boilers, Heaters, Steam      LPG, Propane,  1000 gals    4.400     4.260
   Gens Rule 1146 and           Butane
   1146.1

   Boilers, Heaters, Steam      Diesel Light   1000 gals    6.420     6.210
   Gens Rule 1146 and           Dist. 
   1146.1                       (0.05% S)
   
   Boilers, Heaters, Steam      Refinery Gas   mmcf        51.520    49.840
   Gens Rule 1146 and
   1146.1

   Boilers, Heaters, Steam      Bituminous     tons          RV       4.800
   Gens                         Coal           burned
   
   Boiler, Heater, Steam        Natural Gas    mmcf       130.000    39.460
   Gen (Rule 1146.1)                                                                                                                             mmcf
                                                                                                                                
   Boiler, Heater, Steam        Refinery Gas   mmcf          RV      41.340
   Gen (Rule 1146.1)

   Boiler, Heater, Steam        LPG, Propane,  1000 gals     RV       3.530
   Gen (Rule 1146.1)            Butane

   Boiler, Heater, Steam        Diesel Light   1000 gals     RV       5.150
   Gen (Rule 1146.1)            Dist. 
                                (0.05% S)                                               
   
   Boiler, Heater, Steam        Natural Gas    mmcf        47.750    47.750
   Gen (Rule 1146)

   Boiler, Heater, Steam        Refinery Gas   mmcf        50.030    50.030
   Gen (Rule 1146)

   Boiler, Heater, Steam        LPG, Propane   1000 gals    4.280     4.280
   Gen (Rule 1146)              Butane
                                                                                                            
   Boiler, Heater, Steam        Diesel Light   1000 gals    6.230     6.230
   Gen (Rule 1146)              Dist.
                                (0.05%)
                                                                                
   Boiler, Heater, Steam        Natural Gas    mmcf          RV      47.750
   Gen (Rule 1146, 
   <90,000 Therms)

   Boiler, Heater, Steam        Refinery Gas   mmcf          RV      50.030
   Gen (Rule 1146,
   <90,000 Therms)

   Boiler,  Heater, Steam       LPG, Propane,  1000 gals     RV       4.280
   Gen (Rule 1146,              Butane
   <90,000 Therms)

   Boiler,  Heater, Steam       Diesel Light   1000 gals     RV       6.230
   Gen (Rule 1146,              Dist.
   <90,000 Therms)              (0.05%)
                                                                                
   Boiler, Heater, Steam        Natural Gas    mmcf          RV      39.460
   Gen (Rule 1146.1,
   <18,000 Therms)

   Boiler, Heater, Steam        Refinery Gas   mmcf          RV      41.340
   Gen (Rule 1146.1,
   <18,000 Therms)

   Boiler, Heater, Steam        LPG, Propane,  1000 gals     RV       3.530
   Gen (Rule 1146.1,            Butane
   <18,000 Therms)

   Boiler, Heater, Steam        Diesel Light   1000 gals     RV       5.150
   Gen (Rule 1146.1,            Dist.
   <18,000 Therms)              (0.05%)
                                                                                
   Boiler, Heater Rule 1109     Refinery Gas   mmbtu        0.100     0.030
   (Petr Refin)

   Boilers, Heaters, Steam      Natural Gas    mmcf       105.000    31.500
   Gens (Petr Refin)

   Boilers, Heaters, Steam      Refinery Gas   mmcf       110.000    33.000
   Gens (Petr Refin)

   Boilers, Heaters, Steam      Natural Gas    mmcf       130.000    32.500
   Gens Unpermitted

   Boilers, Heaters, Steam      LPG, Propane,  1000 gals     RV       3.200
   Gens Unpermitted             Butane

   Boilers, Heaters, Steam      Natural Gas    mmcf        38.460    38.460
   Gens (New or Modified,
   and subject to BACT, after
   the start year as
   determined pursuant to
   Rule 2002(c)(1))
   
   Boilers, Heaters, Steam      Refinery Gas    mmbtu       0.035     0.035
   Gens (New or Modified,
   and subject to BACT, after
   the start year as
   determined pursuant to
   Rule 2002(c)(1))
   
   Boilers, Heaters, Steam      LPG, Propane    1000 gals   3.55      3.55
   Gens (New or Modified,       Butane
   and subject to BACT, after
   the start year as
   determined pursuant to
   Rule 2002(c)(1))
   
   Boilers, Heaters, Steam      Diesel Light    1000 gals   5.26      5.26
   Gens (New or Modified,       Dist.
   and subject to BACT, after   (0.05%)
   the start year as
   determined pursuant to
   Rule 2002(c)(1))
   
   Boilers, Heaters, Steam      Diesel Light    1000 gals    RV       4.750 
   Gens, Unpermitted            Dist.
                                (0.05%)                                         

   Catalyst Manufacturing       Catalyst Mfg.   tons of      RV       1.660
                                                catalyst
                                                produced

   Catalyst Manufacturing       Catalyst Mfg.   tons of      RV       2.090
                                                catalyst
                                                produced

   Cement Kilns                 Natural Gas     mmcf      130.000    19.500
   
   Cement Kilns                 Diesel Light    1000 gals    RV       2.850
                                Dist.
                                (0.05% S)

   Cement Kilns                 Kilns-Dry       tons         RV       0.750
                                Process         cement
                                                produced

   Cement Kilns                 Bituminous      tons         RV       4.800
                                Coal            burned

   Cement Kilns                 Tons Clinker    tons         RV       2.73
                                                clinker

   Ceramic and Brick Kilns      Natural Gas     mmcf      213.000   170.400
   (Preheated Combustion
    Air)

   Ceramic and Brick Kilns      Diesel Light    1000 gals    RV      24.905
   (Preheated Combustion        Distillate
    Air)                        (.05%)                                          
                                                                                
   Ceramic and Brick Kilns      LPG             1000 gals    RV      16.778
   (Preheated Combustion
    Air)

   Ceramic Clay Mfg.            Drying          tons input   RV       1.114
                                                to process

   CO Boiler                    Refinery Gas    mmbtu                 0.030
                              
   Cogen, Industr               Coke            tons         RV       3.682
                                                burned
                                                                                
   Electric Generation,         Distillate Oil  1000 gals   6.420     6.210
   Commercial Institutional
   Boiler

   Composite Internal           Waste Fuel Oil  1000 gals    RV      31.340
   Combustion                                   burned

   Curing and Drying Ovens      Natural Gas     mmcf      130.000    32.500
                                                                                
   Curing and Drying Ovens      LPG, Propane    1000 gals    RV       3.200
                                Butane
                                                                                
   Delacquering Furnace         Natural Gas     mmcf      182.2     182.2
   
   Fiberglass                   Textile-Type    tons of      RV       1.860
                                Fibr            material
                                                processed

   Fluid Catalytic Cracking     Fresh Feed      1000 BBLS    RV       6.040
   Unit                                         fresh feed
                                                    
   Fugitive Emission            Not Classified  tons         RV       0.087
                                                product

   Furnace Process              Carbon Black    tons         RV      38.850
                                                produced
                                                 
   Furnace Suppressor           Furnace         unknown      RV       0.800
                                Suppressor
                                                                                
   Glass Fiber Furnace          Mineral         tons         RV       4.000
                                Products        product
                                                produced

   Glass Melting Furnace        Flat Glass      tons of      RV       4.000
                                                glass
                                                pulled

   Glass Melting Furnace        Tableware       tons of      RV       5.680
                                Glass           glass
                                                pulled

   Glass Melting Furnaces       Container       tons of     4.000     1.2
                                Glass           glass
                                                produced

   ICE - Large Bore Engine      Diesel          1000 gals    RV      31.340
   
   ICEs, Permitted (Rule        Natural Gas     mmcf     2192.450   217.360
   1110.1 and 1110.2)
                                
   ICEs, Permitted              Natural Gas     mmcf         RV     217.360
   (Rule 1110.2)
   
   ICEs, Permitted (Rule        LPG, Propane,   1000 gals    RV      19.460
   1110.1 and 1110.2)           Butane                   
                                                    
   ICEs, Permitted (Rule        Gasoline        1000 gals    RV     20.130                                
   1110.1 and 1110.2)                                                 
                                                    
   ICEs, Permitted (Rule        Diesel Oil      1000 gals    RV     31.340                                  
   1110.1 and 1110.2)

   ICEs, Emergency Standby      Natural Gas     mmcf         RV       RV

   ICEs, Emergency Standby      LPG, Propane,   1000 gals    RV       RV 
                                Butane

   ICEs, Emergency Standby      Gasoline        1000 gals    RV       RV
   
   ICEs, Emergency Standby      Diesel Oil      1000 gals    RV       RV
   
   ICEs, Exempted per           All Fuels                    RV       RV
   Rule 1110.2

   ICEs, Exempted per           All Fuels                    RV       RV
   Rule 1110.2 and subject 
   to Rule 1110.1
   
   ICEs, Unpermitted            All Fuels                    RV       RV
   
   In Process Fuel              Coke            tons         RV     24.593
                                                burned
                                                                                
   Incinerators                 Natural Gas     mmcf      130.000  104.000
                                                                                
   Industrial                   Propane         1000 gals    RV     20.890
                                                                 
   Industrial                   Gasoline        1000 gals    RV     21.620
   
   Industrial                   Dist.Oil/       1000 gals    RV     33.650
                                Diesel
                                                                                
   Inorganic Chemicals,         General         tons pure    RV      0.266
   H2SO4 Chamber                                acid
                                                produced

   Inorganic Chemicals,         Absrbr 98.0%    tons 100%    RV      0.376
   H2SO4 Contact                Conv            H2S04
   
   Iron/Steel Foundry           Steel Foundry,  tons metal   RV      0.045
                                Elec Arc Furn   processed
   
   Metal Heat Treating          Natural Gas     mmcf      130.000  104.000
   Furnace
                                                                                
   Metal Heat Treating          Diesel Light    1000 gals    RV     15.200
   Furnace                      Distillate
                                (.05%)

   Metal Heat Treating          LPG             1000 gals    RV     10.240
   Furnace

   Metal Forging Furnace        Natural Gas     mmcf      213.000  170.400
   (Preheated Combustion
    Air)

   Metal Forging Furnace        Diesel Light    1000 gals    RV     24.905
   (Preheated Combustion        Distillate
    Air)                        (.05%)
                                                                                
   Metal Forging Furnace        LPG             1000 gals    RV     16.778
   (Preheated Combustion
    Air)

   Metal Melting Furnaces       Natural Gas     mmcf      130.000   65.000
   
   Metal Melting Furnaces       LPG, Propane,   1000 gals    RV      6.400
                                Butane

   Miscellaneous                                bbls-        RV      1.240
                                                processed

   Natural Gas Production       Not Classified  mmcf gas     RV      6.320
                                                                                
   Nonmetallic Mineral          Sand/Gravel     tons         RV      0.030
                                                product

   NSPS                         Refinery Gas    mmbtu        RV      0.030
   
   Other Bact Heater (24F-1)    Natural Gas     mmcf         RV       RV
   
   Other Heater (24F-1)         Pressure        mmcf         RV       RV
                                Swing    
                                Absorber Gas
                                                                                
   Ovens, Kilns, Calciners,     Natural Gas     mmcf      130.000   65.000
   Dryers, Furnaces**

   Ovens, Kilns, Calciners,     Diesel Light    1000 gals    RV      9.500
   Dryers, Furnaces**           Dist.
                                (0.05% S)

   Paint Mfg. Solvent Loss      Mixing/         tons         RV     45.600
                                Blending        solvent
                                                                                                       
   Petroleum Refining           Natural Gas,    1000 bbls    RV       RV    
                                                crude
                                                processed
   
   Petroleum Refinery           Asphalt         tons of      RV     45.600
                                Blowing         asphalt
                                                produced
   
   Petroleum Refinery,          Petroleum       Calcined     RV      0.971
   Calciner                     Coke            Coke
                                                                                
   Plastics Prodn               Polyester       tons         RV    106.500
                                Resins          product

   Pot Furnace                  Lead Battery    lbs Niter   0.077    0.062
   
   Process Specific             ID #012183      (unknown     RV    240.000
                                                 process
                                                 units)
                                                 
   Process Specific             SCC 30500311    tons         RV      0.140
                                                produced

   Process Specific             ID 14944        (unknown     RV      0.512
                                                 process
                                                 units)

   Reported Vale                                             RV       RV
   
   SCC 39090003                                              RV    170.400
                                                                                
   Sec. Aluminum                Sweating        tons         RV      0.300
                                Furnace         produced

   Sec. Aluminum                Smelting        tons metal   RV      0.323
                                Furnace         produced

   Sec. Aluminum                Annealing       mmcf      130.000   65.000
                                Furnace
   
   Sec. Aluminum                Boring Dryer    tons         RV      0.057
                                                produced

   Sec. Lead                    Smelting        tons metal   RV      0.110
                                Furnace         charged

   Sec. Lead                    Smelting        tons metal   RV      0.060
                                Furnace         charged

   Sodium Silicate Furnace      Water Glass     tons         RV      6.400
                                                glass
                                                pulled

   Steel Hot Plate Furnace      Natural Gas     mmcf      213.000  106.500
                                                                                
   Steel Hot Plate Furnace      Diesel Light    1000 gals  31.131   10.486
                                Distillate
                                (.05%)

   Steel Hot Plate Furnace      LPG, Propane    1000 gals  20.970   10.486
                                Butane

   Surface Coal Mine            Haul Road       tons coal    RV     62.140

   Tail Gas Unit                                hours of     RV       RV
                                                operation

   Turbines                     Butane          1000 gals    RV      5.700
                                                                  
   Turbines                     Diesel Oil      1000 gals    RV      8.814
                           
   Turbines                     Refinery Gas    mmcf         RV     62.275

   Turbines                     Natural Gas     mmcf         RV     61.450
                                                                                
   Turbines - Peaking Unit      Natural Gas     mmcf         RV       RV
                                                    
   Turbines - Peaking Unit      Dist. Oil/      1000 gals    RV       RV
                                Diesel
                                                                                
   Utility Boiler               Digester/       mmcf       52.350   10.080
                                Landfill Gas

   Turbine                      Natural Gas     mmcf         RV     61.450
                                                                                
   Turbine                      Fuel Oil        1000 gals    RV      8.810
                                                           
   Turbine                      Dist.Oil/       1000 gals    RV      3.000
                                Diesel    

   Utility Boiler, Burbank      Natural Gas     mmcf      148.670   17.200

   Utility Boiler, Burbank      Residual Oil    1000 gals  20.170    2.330
                                                                                
   Utility Boiler, Glendale     Natural Gas     mmcf      140.430   16.000
                                                    
   Utility Boiler, Glendale     Residual Oil    1000 gals  20.160    2.290
                                                                                
   Utility Boiler, LADWP        Natural Gas     mmcf       86.560   15.830

   Utility Boiler, LADWP        Residual Oil    1000 gals  12.370    2.260
                                                                                
   Utility Boiler, LADWP        Digester Gas    mmcf       52.350   10.080
                                                    
   Utility Boiler, LADWP        LPG             mmcf       37.760    6.910
                                                                                
   Utility Boiler, Pasadena     Natural Gas     mmcf      195.640   18.500
                             
   Utility Boiler, Pasadena     Residual Oil    1000 gals  28.290    2.670
                                                                                
   Utility Boiler, SCE          Natural Gas     mmcf       74.860   15.600
                                                    
   Utility Boiler, SCE          Residual Oil    1000 gals  10.750    2.240
                                                                                
   Waste Gas Flare              Landfill Dump   mmcf gas     RV       RV
   
   
   *  RV - Reported Value                                                                                                                             
   
   ** Does not include ceramic, clay, cement or brick kilns or metal melting,
      heat treating or glass melting furnaces.
   
   
                                   
                                   Table 2

                         RECLAIM SOx Emission Factors

                                                      
       Sufur Oxides                Fuel      "Through     Starting  Ending
       Basic Equipment                          put"      Emission  Emission
                                               Units      Factor*   Factor*
      
      Air Blown Asphalt                        hours of      RV       RV
                                               operation                                        
      
      Asphalt Concrete          Cold Ag        tons          RV      0.032
                                Handling       produced

      Calciner                  Petroleum      Calcined      RV      0.000
                                Coke           Coke

      Catalyst Regeneration                    hours of      RV       RV
                                               operation

      Cement Kiln               Distillate     1000 gals     RV       RV
                                Oil       

      Cement Mfg.               Kilns, Dry     tons          RV       RV
                                Process        produced
                          
      Claus Unit                               pounds        RV       RV
                                               per ton
      
      Cogen                                    hours of      RV       RV
                                               operation
      
      Non-Fuel Use                             hours of      RV       RV
                                               operation

      External Combustion       Natural Gas    mmcf          RV      0.830
      Equipment/Incinerator

      External Combustion       LPG, Propane   1000 gals     RV      4.600
      Equipment/Incinerator     Butane

      External Combustion       Diesel Light   1000 gals    7.00      5.600
      Equipment/Incinerator     Dist.
                                (0.05% S)

      External Combustion       Residual Oil   1000 gals    8.00      6.400
      Equipment/Incinerator

      External Combustion       Refinery Gas   mmcf          RV       6.760
      Equipment/Incinerator

      Facility Surveyed                        lbs           RV        RV
      Emissions Inventory

      Fiberglass                Recuperative   tons          RV       2.145
                                Furn, Textile- produced
                                Type Fiber

      Fluid Catalytic                          1000 bbls     RV      13.700
      Cracking Units                           refinery
                                               feed

      Glass Mfg.                Container                    RV        RV
      Forming/Fin               Glass

      Grain Milling             Flour Mill     tons grain    RV        RV
                                               processed
      
      ICEs                      Natural Gas    mmcf          RV       0.600
                          
      ICEs                      LPG, Propane,  1000 gals     RV       0.350
                                Butane
          
      ICEs                      Gasoline       1000 gals     RV       4.240
                                    
      ICEs                      Diesel Oil     1000 gals    6.24      4.990
                          
      Industrial                Cogeneration,  tons          RV        RV
                                Bituminous     produced
                                Coal

      Industrial                Cogeneration,  tons           RV       RV
      (scc 10200804)            Coke           produced

      Inorganic Chemicals       General,       tons           RV       RV
                                H2SO4          produced
                                Chamber

      Inorganic Chemicals       Absrbr 98.0%   tons           RV       RV
                                Conv, H2SO4    produced
                                Contact

      Inprocess Fuel            Cement         tons           RV       RV
                                Kiln/Dryer,    produced
                                Bituminous
                                Coal

      Iron/Steel Foundry        Cupola, Gray   tons           RV      0.720
                                Iron Foundry   produced
                          
      Melting Furnace,                         tons           RV       RV
      Container Glass                          produced
                                                      
      Mericher Alkyd Feed                      hours of       RV       RV
                                               operation

      Miscellaneous             Not            tons           RV      0.080
                                Classified     produced

      Miscellaneous             Not            tons           RV      0.399
                                Classified     produced

      Natural Gas Production    Not            mmcf           RV    527.641
                                Classified

      Organic Chemical                         tons           RV       RV
      (scc 30100601)                           produced
                                                      
      Petroleum Refin           Column                        RV      1.557
      (scc 30600602)            Condenser

      Petroleum Refin           Column                        RV      1.176
      (scc 30600603)            Condenser

      Petroleum Refng           Vapor          1000 bbls      RV       RV
                                                      
      Pot Furnace               Lead Battery   lbs sulfur    0.133   0.106
      
      Refinery Process          LPG fired      1000 gals      RV      2.259
      Heaters

      Sec. Lead                 Reverberatory, tons           RV      RV
                                Smelting       produced
                                Furnace

      Sec. Lead                 Smelting       tons           RV     0.648
                                Furnace,       produced
                                Fugitive

      Sodium Silicate                          tons of       RV      RV
      Furnace                                  glass  
                                               pulled
      
      Sour Water Oxidizer                      hours of       RV      RV
                                               operation

      Sour Water Oxidizer                      1000 bbls      RV      RV
                                               fresh feed

      Sour Water Coker                         1000 bbls      RV      RV
                                               fresh feed

      Sulfur Loading                           1000 bbls      RV      RV
      
      Sulfur Plant                             hours of      RV      RV
                                               operation

      Tail gas unit                            hours of      RV      RV
                                               operation

      Turbines                  Refinery Gas   mmcf          RV     6.760
                          
      Turbines                  Natural Gas    mmcf          RV     0.600
                          
      Turbines                  Diesel Oil     1000 gals    6.24    4.990
                          
      Unit 24 PSA                              pounds        RV      RV

      Other Heater (24F-1)      Pressure       mmcf          RV      RV
                                Swing
                                Absorber Gas


      * RV = Reported Value