Compilation of Rules and Regulations of the State of Georgia
Department 391 - RULES OF GEORGIA DEPARTMENT OF NATURAL RESOURCES
Chapter 391-3 - ENVIRONMENTAL PROTECTION
Subject 391-3-1 - AIR QUALITY CONTROL
Rule 391-3-1-.03 - Permits. Amended

Universal Citation: GA Rules and Regs r 391-3-1-.03

Current through Rules and Regulations filed through September 23, 2024

(1) Construction (SIP) Permit.

(a) Any person prior to beginning the construction or modification of any facility which may result in air pollution shall obtain a permit for the construction or modification of such facility from the Director.

(b) The application for a construction permit shall be made on forms supplied by the Director, and shall be signed by the applicant. Said application shall be filed with the Director well in advance of any critical date involved in the construction or modification of such facility, so that adequate time will be available for review, discussion, and revision where necessary. Said application shall include and/or be accompanied by all pertinent information as the Director may require for a full evaluation of the proposed construction or modification of the facility, such as: process flow diagrams; plot plans; description of control devices; description of the proposed new or modified operation; type of operation; raw materials and chemicals to be used, the finished products; type, quantity and peak output of fuels to be used; the amount of combustible waste that will be generated and the method of disposing of same; characteristics and amounts of emissions into the atmosphere; engineering reports; plans and specifications; time schedules and reports of progress; records; and related information.

(c) The permit for the construction or modification of any facility shall be issued upon a determination by the Director that the facility can reasonably be expected to comply with all the provisions of the Act and the rules and regulations promulgated thereunder.

(2) Operating (SIP) Permit.

(a) Any person operating a facility or performing an activity which is not exempted under 391-3-1-.03(6) from which air contaminants are or may be emitted shall obtain an Operating (SIP) Permit from the Director.

(b) Application for an operating permit must be made within thirty (30) days after commencement of normal operations. Said application for an operating permit shall be accompanied by such plans, specifications, and other information deemed necessary by the Director to make full evaluation of the performance of the facility. If any of the necessary information cannot be provided within the required time, the application shall include a schedule, subject to the approval of the Director, for submission of all such information as soon as practicable.

(c) An operating permit will be issued upon evidence satisfactory to the Director of compliance with the provisions of the Act and the rules and regulations promulgated thereunder. Said permit shall specify the conditions under which the facility shall be operated in order to comply with the Act and rules and regulations. As a condition for the issuance of an operating permit, the Director may require the applicant to conduct performance tests and monitoring and provide reports concerning operations, to demonstrate compliance with the Act and the rules and regulations. Such tests and monitoring shall be conducted, and such required reports submitted, in accordance with methods and procedures approved by the Director.

(d) The Director may grant a temporary operating permit for such period of time and under such conditions as he shall specify in the permit, in order to allow the applicant a reasonable period of time in which to correct deficiencies in any existing facility. The temporary operating permit shall specify a schedule for bringing the existing facility into compliance with the Act and rules and regulations in the shortest practical time period.

(e) The requirements of this section (2) shall not apply to any emissions unit as defined in 40 CFR 70.2 which has been issued a part 70 permit under the requirements of section (10), unless there is a modification to such unit.

(f) Any person operating a facility or performing an activity from which air contaminants are or may be emitted, may be required to obtain a Permit by Rule, a Generic Permit or a Part 70 Permit from the Director in addition to an Operating (SIP) Permit.

(g) Under penalty of law, the holder of any Air Quality Permit must adhere to the terms, limitations, and conditions of that permit and subsequent revisions of that permit.

(h) The limitations, controls, and requirements in federally enforceable operating permits are permanent, quantifiable, and otherwise enforceable as a practical matter.

(i) Prior to the issuance of any federally enforceable operating permit, EPA and the public will be notified and given a chance for comment on the draft permit.

(3) Revocation, Suspension, Modification or Amendment of Permits.

(a) Any permit issued by the Director shall be subject to periodic review and the Director may revoke, suspend, modify or amend any permit issued, for cause, including but not limited to, the following:

1. Violation of any condition of said permit, or failure to comply with a final order of the Director;

2. Failure to comply with any applicable rules or regulations in effect pursuant to this Chapter;

3. Obtaining a permit by misrepresentation, or failure to disclose fully all relevant facts, or failure to inform the Division of modifications affecting emissions;

4. Modifications which affect emissions. In the event of modification, amendment, suspension or revocation of a permit, the Director shall serve written notice of such action on the permit holder and shall set forth in such notice the reason for the action.

5. The Director may amend any permit to establish an emission limitation based on existing equipment design and reasonable operation and maintenance practices. Such limitation shall not allow emissions greater than those allowed by other provisions and emission limits specified elsewhere in the Rules, Chapter 391-3-1.

(4) Permits Not Transferable.

A permit is not transferable from one person to another nor from one facility to another facility.

(5) Permits Public Records.

Except as to information required to be kept confidential by O.C.G.A. Section 12-9-19, as amended all applications for construction permits and operating permits shall be public record.

(6) Exemptions.

Unless otherwise required by the Director, SIP permits shall not be required for the following source activities. These exemptions may not be used to avoid any emission limitations or standards of the Rules for Air Quality Control Chapter 391-3-1-.02, lower the potential to emit below "major source" thresholds or to avoid any "applicable requirement" (i.e., NSPS, NESHAP, etc.) as defined in 40 CFR Part 70.2.

(a) Mobile Sources.

Mobile sources, such as automobiles, trucks, buses, locomotives, airplanes, boats and ships, whether or not designated as subject to mandatory inspection, maintenance, or emission requirements pursuant O.C.G.A. Section 12-9-40, et seq., as amended, the Georgia Motor Vehicle Emission Inspection and Maintenance Act. This exemption relates only to the requirement for a permit issued under the Act, not to any other requirement under the Act, and in no way affects any requirement for a permit, license, or a certificate under any other law. This limited exemption from the permit requirements of the Act shall in no way affect the applicability of any other requirement related to mobile sources, or any other requirement or limitation which may affect mobile sources.

(b) Combustion Equipment.

1. Fuel-burning equipment having a total heat input capacity of less than 10 MMBtu/hr burning only natural gas, LPG and/or distillate fuel oil containing 0.50% sulfur by weight or less.

2. Fuel-burning equipment rated at less than 5 MMBtu/hr burning a wood or fossil fuel.

3. Any fuel-burning equipment with a rated input capacity of 2.5 MMBtu/hr or less.

4. Equipment used for cooking food for immediate human consumption.

5. Blacksmith forges.

6. Clean steam condensate and steam relief vents.

7. Funeral homes and crematories of any size.

8. Air curtain destructor used for land clearing at a construction site.

9. Open burning.

10. Small incinerators operating as follows:

(i) less than 8 MMBtu/hr input, firing types 0, 1, 2 and/or 3 waste; or

(ii) less than 8 MMBtu/hr input with no more than 10% pathological (type 4) waste by weight combined with types 0, 1, 2 and/or 3 waste; or

(iii) less than 4 MMBtu/hr heat input firing Type 4 waste.

11. Stationary engines.

(i) Burning natural gas, LPG, gasoline, dual fuel, or diesel fuel which are used exclusively as emergency generators;

(ii) Burning natural gas, LPG, and/or diesel fuel and used for peaking power (including emergency generators used for peaking power) where the peaking power use does not exceed 200 hours-per-year except in the counties of Banks, Barrow, Bartow, Butts, Carroll, Chattooga, Cherokee, Clarke, Clayton, Cobb, Coweta, Dawson, DeKalb, Douglas, Fayette, Floyd, Forsyth, Fulton, Gordon, Gwinnett, Hall, Haralson, Heard, Henry, Jackson, Jasper, Jones, Lamar, Lumpkin, Madison, Meriwether, Monroe, Morgan, Newton, Oconee, Paulding, Pickens, Pike, Polk, Putnam, Rockdale, Spalding, Troup, Upson, and Walton where such engines with a rated capacity equal to or greater than 100 kilowatts are not exempt; or

(iii) Used for other purposes provided that the total horsepower of all non-gasoline burning engines combined are less than 1500 engine horsepower and no individual engine operates for more than 1000 hours-per-year; or

(iv) Used for other purposes provided that the total horsepower of all gasoline burning engines combined are less than 225 horsepower and no individual engine operates for more than 1000 hours-per-year.

(v) For the purpose of this subsection, the following definitions shall apply:

(I) An "emergency generator" means a generator whose function is to provide back-up power when electric power from the local utility is interrupted and which operates for less than 500 hours-per-year, except in the counties of Banks, Barrow, Bartow, Butts, Carroll, Chattooga, Cherokee, Clarke, Clayton, Cobb, Coweta, Dawson, DeKalb, Douglas, Fayette, Floyd, Forsyth, Fulton, Gordon, Gwinnett, Hall, Haralson, Heard, Henry, Jackson, Jasper, Jones, Lamar, Lumpkin, Madison, Meriwether, Monroe, Morgan, Newton, Oconee, Paulding, Pickens, Pike, Polk, Putnam, Rockdale, Spalding, Troup, Upson, and Walton where such generator operates less than 200 hours-per-year.

(II) "Used for peaking power" means used to reduce the electrical power requirements on the local utility grid. This could be for supplying power during the local utility's peak demand periods, or for peak shaving by the facility.

12. Boiler water treatment operations.

13. Firefighting equipment, including fire pumps or other emergency/safety equipment used to fight fires or train firefighters or other emergency personnel.

14. Temporary stationary engines used to generate electricity that are used to replace main stationary engines during periods of maintenance or repair (provided the actual and potential emissions of the temporary sources do not exceed that of the main sources).

15. Temporary fuel-burning equipment (i.e., boilers) that are used to replace main fuel-burning equipment during periods of maintenance or repair (provided the actual and potential emissions of the temporary sources do not exceed that of the main sources.) Temporary fuel-burning equipment that remains at a location for more than 180 consecutive days is no longer considered to be a temporary boiler. Temporary fuel-burning equipment that replaces temporary fuel-burning equipment at a location and is intended to perform the same or similar function will be included in calculating the consecutive time period.

16. Onsite air curtain incinerators with mist controls used for the purpose of decontamination and disposal of livestock and materials contaminated with the avian flu virus where on-site composting and burial are not viable methods of disposal.

1. All petroleum liquid storage tanks storing a liquid with a true vapor pressure of equal to or less than 0.50 psia as stored.

2. All petroleum liquid storage tanks with a capacity of less than 40,000 gallons storing a liquid with a true vapor pressure of equal to or less than 2.0 psia as stored.

3. All petroleum liquid storage tanks with a capacity of less than 10,000 gallons storing a petroleum liquid.

4. Pressurized vessels designed to operate in excess of 30 psig storing a petroleum fuel.

5. Gasoline storage and handling equipment at loading facilities handling less than 20,000 gallons per day or at vehicle dispensing facilities.

6. Portable drums and barrels provided that the volume of each container does not exceed 550 gal.

7. All chemical storage tanks used to store a chemical with a true vapor pressure of less than or equal to 10 millimeters of mercury.

(d) Agricultural Operations.

1. Farm equipment used for soil preparation, livestock handling, crop tending and harvesting and for other farm related activities.

2. Herbicide and pesticide mixing and application activities for on site use.

(e) Maintenance, Cleaning & Housekeeping.

1. Heating, air conditioning and ventilation systems not designed to remove air contaminants generated by or released from process or fuel-burning equipment.

2. Routine housekeeping activities such as painting buildings, roofing or paving parking lots, all clerical activities and all janitorial activities.

3. Maintenance activities such as: vehicle repair shops, brazing, soldering and welding equipment, carpenter shops, electrical charging stations, grinding and polishing operations maintenance shop vents, miscellaneous non-production surface cleaning, preparation and painting operations.

4. Miscellaneous activities such as: aerosol spray cans; air compressors; cafeteria vents; copying, photographic and blueprint machines; decommissioned equipment; dumpsters; fire training activities; fork lifts; railroad flares; refrigerators; space heaters.

5. Cold storage refrigeration equipment.

6. Vacuum-cleaning systems used exclusively for industrial, commercial, or residential housekeeping purposes.

7. Equipment used for portable steam cleaning.

8. Blast-cleaning equipment using a suspension of abrasive in water and any exhaust system or collector serving them exclusively.

9. Portable blast-cleaning equipment.

10. Laundry dryers, extractors, or tumblers for fabric cleaned with only water solutions of bleach or detergents.

11. Non-Perchloroethylene Dry-cleaning equipment with a capacity of 100 pounds per hour or less of clothes.

12. Cold cleaners having an air/vapor interface of not more than 10 square feet and that do not use a halogenated solvent.

13. Steam sterilizers.

14. Portable equipment used for the on site painting of buildings, towers, bridges and roads.

15. Non-routine clean out of tanks and equipment for the purposes of worker entry or in preparation for maintenance or decommissioning.

16. Equipment used for the washing or drying of fabricated products provided that no VOCs are used in the process and that no oil or solid fuels are burned.

17. Devices used exclusively for cleaning metal parts or surfaces by burning off residual amounts of paint, varnish, or other foreign material, provided that such devices are equipped with afterburners.

18. Fresh water cooling towers provided that the total potential emissions from the entire source remain below 10 tons per year of any single hazardous air pollutant and below 25 tons per year of any combination of hazardous air pollutants.

(f) Laboratories and Testing.

1. Laboratory equipment used exclusively for chemical or physical analyses;

2. Sampling connections used exclusively to withdraw materials for testing and analysis, including air contaminant detectors and vent lines;

3. Vacuum producing devices;

4. Research and development facilities, quality control testing facilities and/or small pilot projects, where combined daily emissions from all operations are below all of the following thresholds:

(i) Less than 125 pounds per day of carbon monoxide;

(ii) Less than 0.8 pounds per day of lead;

(iii) Less than 50 pounds per day of particulate matter, PM10, or sulfur dioxide;

(iv) Less than 50 pounds per day of nitrogen oxides or VOCs except in the Counties of Cherokee, Clayton, Cobb, Coweta, DeKalb, Douglas, Fayette, Forsyth, Fulton, Gwinnett, Henry, Paulding, or Rockdale, where less than 15 pounds per day of nitrogen oxides; or VOCs; and

(v) Less than 5 pounds per day of any single hazardous air pollutant and less than 12.5 pounds per day of any combination of hazardous air pollutants.

(g) Pollution Control.

1. Sanitary wastewater collection and treatment systems, except incineration equipment, that are not subject to any standard, limitation or other requirement under section 111 or section 112 (excluding section 112(r)) of the federal Clean Air Act.

2. On site soil or groundwater decontamination units that are not subject to any standard, limitation or other requirement under Section 111 or 112 [excluding 112(r)] of the Federal Act.

3. Bioremediation operations.

4. Garbage compactors and garbage handling equipment.

5. Municipal Solid Waste Landfills which meet the following criteria:

(i) The total design capacity of the landfill is less than or equal to 2.756 million tons (2.5 million megagrams) or 3.27 million cubic yards (2.5 million cubic meters) of solid waste; and

(ii) The emissions of VOC are less than 25 tons per year for landfills located within Cherokee, Clayton, Cobb, Coweta, DeKalb, Douglas, Fayette, Forsyth, Fulton, Gwinnett, Henry, Paulding, or Rockdale counties; and

(iii) The emissions of nitrogen oxides (NOx) from operations other than the final control device are less than 25 tons per year for landfills located within Cherokee, Clayton, Cobb, Coweta, DeKalb, Douglas, Fayette, Forsyth, Fulton, Gwinnett, Henry, Paulding, or Rockdale counties.

(h) Industrial Operations.

1. Concrete block, brick plants, concrete products plants, and ready mix concrete plants producing less than 125,000 tons per year of product.

2. Small aluminum scrap metal reclaimers (non-smelters).

3. Any of the following processes or process equipment which are electrically heated or which fire natural gas, LPG or distillate (#2) fuel oil at a maximum total heat input rate of not more than 10 MMBtu/hr.

(i) Furnaces for heat treating glass or metals, the use of which does not involve molten materials, oil-coated parts, or oil quenching.

(ii) Porcelain enameling furnaces or porcelain enameling drying ovens.

(iii) Kilns for firing ceramic ware.

(iv) Crucible furnaces, pot furnaces, or induction melting and holding furnaces with a capacity of 1,000 pounds or less each, in which sweating or distilling is not conducted and in which fluxing is not conducted utilizing free chlorine, chloride or fluoride derivatives, or ammonium compounds.

(v) Bakery ovens and confection cookers.

(vi) Feed mill or grain mill ovens.

(vii) Surface coating drying ovens.

4. Grain, metal, or mineral extrusion process.

5. Equipment used exclusively for rolling, forging, pressing, stamping, spinning, or extruding either hot or cold metals or plastic such as drop hammers or hydraulic presses for forging or metalworking.

6. Die casting machines.

7. Equipment used exclusively for sintering of glass or metals, but not exempting equipment used for sintering metal-bearing ores, metal scale, clay, fly ash, or metal compounds.

8. Equipment for the mining and screening of uncrushed native sand and gravel.

9. Ozonization process or process equipment.

10. Electrostatic powder coating booths with an appropriately designed and operated particulate control system.

11. Equipment used for the application of a hot melt adhesive.

12. Equipment used exclusively for mixing and blending water-based adhesives and coating at ambient temperatures.

13. Equipment used for compression, molding and injection of plastics.

14. Wood products operations in the following SIC categories (combustion equipment and coatings operations are not included in this exemption):

(i) 2426 Dimensional Hardwood Lumber Mills,

(ii) 2431 Lumber Millwork,

(iii) 2434 Wood Kitchen Cabinets,

(iv) 2439 Structural Wood Trusses,

(v) 2441 Wood Boxes,

(vi) 2448 Wood Pallets,

(vii) 2449 Wood Containers, and

(viii) 2499 Miscellaneous Wood Products.

15. Industrial process equipment used exclusively for educational purposes at educational institutions.

(i) Other.

1. Facilities where the combined emissions from all non-exempt source activities [i.e., not listed in 391-3-1-.03(6)(a)-(h)] are below the following for all pollutants:

(i) 50 tons per year of carbon monoxide;

(ii) 300 pounds per year of lead total; with a 3.0 pound per day maximum emission;

(iii) 20 tons per year of particulate matter, PM10, or sulfur dioxide;

(iv) 20 tons per year of nitrogen oxides or VOCs except in the counties of Cherokee, Clayton, Cobb, Coweta, DeKalb, Douglas, Fayette, Forsyth, Fulton, Gwinnett, Henry, Paulding, or Rockdale, where less than 5 tons per year of nitrogen oxides or VOCs is exempted; and

(v) 2 tons per year total with a 15 pound per day maximum emission of any single hazardous air pollutant and less than 5 tons per year of any combination of hazardous air pollutants.

2. Facilities where the combined emissions from all source activities are below the thresholds in "1" above for one or more pollutants, are not required to list those pollutants in the permit application.

3. Cumulative modifications not covered in an existing permit to an existing permitted facility where the combined emission increases (excluding any contemporaneous emission decreases, i.e., "netting" is not allowed) from all nonexempt modified activities are below the following thresholds for all pollutants:

(i) 25 tons per year of carbon monoxide;

(ii) 150 pounds-per-year total with a 1.5 pound-per-day maximum emission of lead;

(iii) 10 tons per year of particulate matter, PM10 or sulfur dioxide;

(iv) 10 tons per year of nitrogen oxides or VOCs except in the counties of Cherokee, Clayton, Cobb, Coweta, DeKalb, Douglas, Fayette, Forsyth, Fulton, Gwinnett, Henry, Paulding, or Rockdale, where less than 2.5 tons per year of nitrogen oxides or VOCs is exempted; and

(v) 2 tons per year total with a 15 pound per day maximum emission of any single hazardous air pollutant and less than 5 tons per year of any combination of hazardous air pollutants.

4. As an alternative to subparagraph 3, cumulative modifications not covered in an existing permit to an existing permitted facility where the combined emissions increases, including any contemporaneous emission decreases (i.e., "netting is allowed") from all nonexempt modified activities are less than 10 tons per year of particulate matter and PM10. For the purpose of this subparagraph, "contemporaneous" means within that period beginning on the date of issuance of the most recent permit through the date of reissuance of such permit. This shall exclude any amendment to such permit unless such amendment incorporates the previously exempted modification(s) in which case the amendment shall be considered a reissuance of such permit for the purpose of this subparagraph. Facilities using this exemption shall maintain records of all emissions increases and decreases and shall notify the Division, in writing, within 7 days after making any modification covered by this subparagraph. The Division may require the use of a Division approved form for tracking the emissions increases and decreases. If a facility elects to use this subparagraph in lieu of subparagraph 3, it shall not use subparagraph 3 with respect to particulate matter and PM10 until such time that all modifications exempted from SIP permitting under subparagraph 4 have been incorporated into the permit. A facility may use subparagraph 3 with respect to any pollutant other than particulate matter and PM10 while using this subparagraph. Only the following facilities are eligible for this exemption:

(i) Facilities with an SIC code of 1422 or 1423 that are not a major source subject to the provisions of 391-3-1-.03(10) (i.e., a minor or synthetic minor source).

5. Changes in a process or process equipment which do not involve installing, constructing, or reconstructing an emission unit or the primary air cleaning device of an air pollution control system provided that such changes do not result in the increase of emissions from any emission unit or the emissions of a pollutant not previously emitted. Examples of such changes in a process or process equipment include the following:

(i) Change in the supplier or formulation of similar raw materials, fuels, or paints and other coatings;

(ii) Changes in product formulations;

(iii) Change in the sequence of the process;

(iv) Change in the method of raw material addition;

(v) Change in the method of product packaging;

(vi) Change in process operating parameters;

(vii) Replacement of a fuel burner in a boiler with a more efficient burner; or

(viii) Lengthening a paint drying oven to provide additional curing time.

6. Sources of minor significance as specified by the Director.

7. Sources for which there is no applicable emission limit, standard or other emission requirement established under, by, or pursuant to the Act.

(j) Construction Permit Exemption for Pollution Control Projects.

Projects listed in subparagraphs 391-3-1-.01(qqqq)1. and 2. of these rules are exempt from the requirement to obtain a construction (SIP) permit as specified in paragraph 391-3-1-.03(1) of this rule provided that the project is not subject to the provisions of paragraph 391-3-1-.02(7), Prevention of Significant Deterioration of Air Quality. The Director has the authority to rebut the presumption that projects listed in subparagraphs (qqqq)1. and 2. are environmentally beneficial in accordance with the criteria specified in subparagraph (qqqq) and thus exempt from the requirement to obtain a construction (SIP) permit. Owners and operators of projects exempt from the requirement to obtain a construction (SIP) permit under this subparagraph (6)(j) shall obtain an operating permit or amendment under either paragraph 391-3-1-.03(2) or 391-3-1-.03(10) of this rule, whichever is applicable, prior to commencement of operation of the project.

(7) Combined Permits and Applications.

The Director may combine the requirements of and the permits for construction and operation (temporary or otherwise) into one permit. He may likewise combine the requirements of and applications for construction and operating permits into one application.

(8) Permit Requirements.

(a) Each application for a permit to construct a new stationary source or modify an existing stationary source shall be subjected to a preconstruction or premodification review by the Director. The Director shall determine prior to issuing any permit that the proposed construction or modification will not cause or contribute to a failure to maintain any ambient air quality standard, a significant deterioration of air quality, or a violation of any applicable emission limitation or standard of performance or other requirement under the Act or this Chapter (391-3-1). Each person applying to the Director for a permit to construct a new stationary source or modify an existing stationary source shall provide information required by the Director to make such determination.

(b) In addition to any other requirement under the Act, or this Chapter (391-3-1), no permit to construct a new stationary source or modify an existing stationary source shall be issued unless such proposed source meets all the requirements for review and for obtaining a permit prescribed in Title I, Part C of the Federal Act, and paragraph 391-3-1-.02(7) of these Rules.

(c) In addition to any other requirement under the Act, or this Chapter 391-3-1, no permit to construct a new stationary source or modify an existing stationary source shall be issued unless such proposed source or modification meets all the requirements for review and for obtaining a permit prescribed in subparagraph 391-3-1-.02(9)(b)16. of this Rule.

(9) Permit Fees.

(a) The owner or operator of any stationary source subject to the provisions of Georgia Air Quality Rule 391-3-1-.03"Permits. Amended" shall pay to the Division an annual fee or its equivalent (e.g., quarterly payments).

(b) The dollar-per-ton fee rate for each calendar year is specified in the table below. Each calendar year's emissions and annual permit fees shall be determined and submitted in accordance with the Georgia Department of Natural Resources' Fee Manual specified below.

Calendar Year	$/Ton Rate	Fee Manual
1991	$25/Ton	"Procedures for Calculating Air Permit Fees" dated July 1, 1992.
1992	$25/Ton	"Procedures for Calculating 1992 Air Permit Fees" dated May 1, 1993.
1993	$25/Ton	"Procedures for Calculating Air Permit Fees for Calendar Year 1993" dated February 1, 1994.
1994	$25/Ton	"Procedures for Calculating Air Permit Fees for Calendar Year 1994" dated May 1, 1995.
1995	$25/Ton	"Procedures for Calculating Air Permit Fees for Calendar Year 1995" dated April 2, 1996.
1996	$25/Ton	"Procedures for Calculating Air Permit Fees for Calendar Years 1996 and 1997" dated August 1, 1997.
1997	$28/Ton	"Procedures for Calculating Air Permit Fees for Calendar Years 1996 and 1997" dated August 1, 1997.
1998	$28/Ton	"Procedures for Calculating Air Permit Fees for Calendar Years 1998 and 1999" dated January 19, 1999.
1999	$28/Ton	"Procedures for Calculating Air Permit Fees for Calendar Years 1998 and 1999" dated January 19, 1999.
2000	$31/Ton	"Procedures for Calculating Air Permit Fees for Calendar Year 2000" dated April 30, 2001.
2001	$31/Ton	"Procedures for Calculating Air Permit Fees for Calendar Year 2001" dated February 26, 2002.
2002	$32.50/Ton	"Procedures for Calculating Air Permit Fees for Calendar Year 2002" dated March 25, 2003.
2003	$32.50/Ton	"Procedures for Calculating Air Permit Fees for Calendar Year 2003" dated April 20, 2004.
2004	$32.50/Ton	"Procedures for Calculating Air Permit Fees for Calendar Year 2004" dated March 22, 2005.
2005	$33.00/Ton	"Procedures for Calculating Air Permit Fees for Calendar Year 2005" dated March 15, 2006.
2006	$28.50/Ton	"Procedures for Calculating Air Permit Fees for Calendar Year 2006" dated February 7, 2007.
2007	$34.00/Ton	"Procedures for Calculating Air Permit Fees for Calendar Year 2007" dated April 2, 2008.
2008	$34.00/Ton	"Procedures for Calculating Air Permit Fees for Calendar Year 2008" dated February 12, 2009.
2009	$34.00/Ton	"Procedures for Calculating Air Permit Fees for Calendar Year 2009" dated January 26, 2010.
2010	$35.84/Ton for coal-fired electric generating units; $34/Ton for all other sources	"Procedures for Calculating Air Permit Fees for Calendar Year 2010" dated January 31, 2011.
2011	$35.84/Ton for coal-fired electric generating units; $34/Ton for all other sources	"Procedures for Calculating Air Permit Fees for Calendar Year 2011" dated March 2, 2012.
2012	$37.34/Ton for coal-fired electric generating units; $35.50/Ton for all other sources	"Procedures for Calculating Air Permit Fees for Calendar Year 2012" dated February 5, 2013.
2013	$37.34/Ton for coal-fired electric generating units; $35.50/Ton for all other sources	"Procedures for Calculating Air Permit Fees for Calendar Year 2013" dated January 14, 2014.
2014	$37.34/Ton for coal-fired electric generating units; $35.50/Ton for all other sources	"Procedures for Calculating Air Permit Fees for Calendar Year 2014" dated January 12, 2015.
2015	$37.34/Ton for coal-fired electric generating units; $35.50/Ton for all other sources	"Procedures for Calculating Air Permit Fees for Calendar Year 2015" dated February 22, 2016.
2016	$37.34/Ton for coal-fired electric generating units; $35.50/Ton for all other sources	"Procedures for Calculating Air Permit Fees for Calendar Year 2016" dated February 8, 2017.
2017	$37.34/Ton for coal-fired electric generating units; $35.50/Ton for all other sources	"Procedures for Calculating Air Permit Application & Annual Permit Fees for Calendar Year 2017" dated February 8, 2018.
2018	$37.34/Ton for coal-fired electric generating units; $35.50/Ton for all other sources	"Procedures for Calculating Air Permit Application & Annual Permit Fees for Fees Due Between July 1, 2019 and June 30, 2020" dated December 26, 2018.
2019	$37.34/Ton for coal-fired electric generating units; $35.50/Ton for all other sources	"Procedures for Calculating Air Permit Application & Annual Permit Fees for Fees Due Between July 1, 2020 and June 30, 2021" dated February 3, 2020.
2020	$37.34/Ton for coal-fired electric generating units; $35.50/Ton for all other sources	"Procedures for Calculating Air Permit Application & Annual Permit Fees for Fees Due Between July 1, 2021 and June 30, 2022" dated February 3, 2021.
2021	$37.34/Ton for coal-fired electric generating units; $35.50/Ton for all other sources	"Procedures for Calculating Air Permit Application & Annual Permit Fees for Fees Due Between July 1, 2022 and June 30, 2023" dated February 3, 2022.
2022	$37.34/Ton for coal-fired electric generating units; $35.50/Ton for all other sources	"Procedures for Calculating Air Permit Application & Annual Permit Fees for Fees Due Between July 1, 2023 and June 30, 2024" dated February 3, 2023.
2023	$37.34/Ton for coal-fired electric generating units; $35.50/Ton for all other sources	"Procedures for Calculating Air Permit Application & Annual Permit Fees for Fees Due Between July 1, 2024 and June 30, 2025" dated February 2, 2024.

When no applicable calculation method or procedure is published therein, the Director may specify or approve an applicable method or procedure prior to its use.

1. "Criteria Pollutant" means volatile organic compounds, sulfur dioxide, particulate matter, and nitrogen oxides.

2. "Stationary source" means all of the pollutant-emitting activities which belong to the same industrial grouping, are located on one or more contiguous or adjacent properties, and are under the control of the same person (or persons under common control) except the activities of any vessel. Pollutant-emitting activities shall be considered as part of the same industrial grouping if they belong to the same "Major Group" (i.e., which have the same first two digit code) as described in the most recent Standard Industrial Classification Manual, published by the U.S. Government Printing Office.

(d) No annual fee shall be collected for more than 4,000 tons per year per stationary source of any individual criteria pollutant as calculated in accordance with the Fee Manual.

(e) The Director may reduce any permit fee required under this Chapter to take into the account the financial resources of small businesses stationary sources.

(f) The collection of fees pursuant to this Chapter shall preclude collection of any air quality control permit fee by any other state or local government authority.

(g) The collection of annual fees pursuant to this section shall begin on or after July 1, 1995, and shall be for the calendar year ending December 31, 1994. Thereafter, annual permit fees for each calendar year are due no later than September 1 of the following calendar year. Fees shall be paid in accordance with the procedures specified in the Fee Manual.

(h) The owner of a stationary source subject to this paragraph (9), "Permit Fees" shall make a one-time payment on or before April 30, 2001, in accordance with the following schedule. This one-time payment shall serve as a credit toward the calendar year 2000 permit fees (which are to be adopted at a later date). The procedures and methods contained in the Georgia Department of Natural Resources Procedures for Calculating Air Permit Fees for Calendar Years 1998 and 1999 dated January 19, 1999 (1998/1999 Fee Manual), which is hereby incorporated by reference, along with calendar year 2000 activities and emissions shall be used to determine which, if any, of the following one-time payments are applicable to each stationary source.

1. Any Stationary Source subject to one or more Federal Standard of Performance for New Stationary Sources (NSPS) that is not classified as a Part 70 major source is defined in 40 CFR 70.2 shall pay a one-time payment of $400 unless ALL of the equipment at the stationary source that is subject to an NSPS standard is listed in the exception list found in section 2.0(a) of the 1998/1999 Fee Manual and/or did not operate during calendar year 2000.

2. Any Stationary Source that is classified as a Part 70 major source, as defined in 40 CFR 70.2, that operated for any period of time in calendar year 2000, and whose calculated emissions (calculated using the Methods of Calculation contained in section 3.2 of the 1998/1999 Fee Manual and calendar year 2000 activities) of EACH OF THE FOUR criteria pollutants (as defined in section 1.0 of the 1998/1999 Fee Manual: particulate matter, sulfur dioxide, volatile organic compounds, and nitrogen oxides) are less than or equal to the threshold values listed in section 3.16 of the 1998/1999 Fee Manual shall pay a one-time payment of $600.

3. Any Stationary Source that is classified as a Part 70 major source, as defined in 40 CFR 70.2, that operated for any period of time in calendar year 2000, whose calculated emissions (calculated using the Methods of Calculation contained in section 3.2 of the 1998/1999 Fee Manual and calendar year 2000 activities) of AT LEAST ONE of the four criteria pollutants (as defined in section 1.0 of the 1998/1999 Fee Manual: particulate matter, sulfur dioxide, volatile organic compounds, and nitrogen oxides) are above the applicable threshold value listed in section 3.16 of the 1998/1999 Fee Manual, and whose COMBINED calculated emissions (calculated using the Methods of Calculation contained in section 3.2 of the 1998/1999 Fee Manual and calendar year 2000 activities) is less than 700 tons shall pay a one-time payment of $1150. For the purpose of determining this one-time payment, the calculated emissions of any single criteria pollutant shall not be considered when determining if the calculated emissions are less than 700 tons if the calculated emissions for that criteria pollutant are less than or equal to the applicable threshold value listed in section 3.16 of the 1998/1999 Fee Manual.

4. Any Stationary Source that is classified as a Part 70 major source, as defined in 40 CFR 70.2, that operated for any period of time in calendar year 2000, whose total calculated emissions (calculated using the Methods of Calculation contained in section 3.2 of the 1998/1999 Fee Manual and calendar 2000 activities) of AT LEAST ONE of the four criteria pollutants (as defined in section 1.0 of the 1998/1999 Fee Manual: particulate matter, sulfur dioxide, volatile organic compounds, and nitrogen oxides) is above the applicable threshold value listed in section 3.16 of the 1998/1999 Fee Manual, and whose COMBINED calculated emissions (calculated using the Methods of Calculation contained in section 3.2 of the 1998/1999 Fee Manual and calendar year 2000 activities) are greater than or equal to 700 tons shall pay a one-time payment of $3000. For the purpose of determining this one-time payment, the calculated emissions of any single criteria pollutant shall not be considered when determining if the calculated emissions are greater than or equal to 700 tons if the calculated emissions for that criteria pollutant are less than or equal to the applicable threshold value listed in section 3.16 of the 1998/1999 Fee Manual.

(i) As part of the annual permit fees required under this paragraph, the owner or operator of any stationary source shall also pay administrative fees in accordance with the following subparagraphs in addition to the permit fees determined in accordance with the Fee Manual(s) specified in Subparagraph (b) of this paragraph.

1. The owner or operator shall pay an administrative fee of 0.05 percent of the total fee due determined in accordance with the Fee Manual(s) specified in Subparagraph (b) of this paragraph for each calendar day in which the air permit fee form is submitted to the Division following the first business day of September of the calendar year in which the fee was due or October 1, 2010, whichever is later.

2. For air permit fee forms submitted using the online Georgia air emissions fee reporting form, that date on which the air permit fee form is submitted to the Division shall be the date in which the owner or operator completes a final submittal on the online reporting form. For air permit fee forms that were submitted using a hard-copy paper form, the date on which the air permit fee form is submitted to the Division shall be the date on which the permit fee form and required payment are received at the address specified in the Fee Manual or at the office of the Division's Air Protection Branch.

(j) Beginning with calendar year 2009 fees, when the ownership of any stationary source is transferred to a new owner or operator, the new owner or operator of the stationary source shall be responsible for paying any past due fees.

(k) Beginning on March 1, 2019, the owner or operator of any stationary source subject to the provisions of Georgia Air Quality Rule 391-3-1-.03"Permits. Amended" shall pay to the Division a processing fee when submitting an application for the following permit application types:

Permit Type

Minor Source Permit or Amendment

Synthetic Minor Source Permit or Amendment

Major Source Permit or Amendment (but not subject to PSD or 112(g))

Name Change

Permit-by-Rule

Title V 502(b)(10) Permit Amendment

Title V Minor Modification with Construction

Title V Minor Modification without Construction

Title V Significant Modification with Construction

Title V Significant Modification without Construction

PSD Permit per 391-3-1-.02(7)

112(g) permit per 391-3-1-.02(9)(b)16.

1. Fees shall be paid in accordance with the procedures specified in the Fee Manual.

2. No final action of the Director shall occur until complete fee payment is received, unless the fee payment is waived or partially waived in accordance with subparagraph 391-3-1-.03(9)(e).

3. Application fees shall not be refunded as the fee is used to cover application processing labor.

4. Title V modification application fees are waived for applicants submitting PSD/112(g) permit applications via Title V permit applications. The PSD/112(g) fee still applies.

(l) Beginning on July 1, 2020, the owner or operator of any stationary source subject to the provisions of Georgia Air Quality Rule 391-3-1-.03(10)"Title V Operating Permits" shall pay to the Division an annual maintenance fee for Title V sources. Fees shall be paid in accordance with the procedures specified in the Fee Manual.

(10) Title V Operating Permits.

(a) General Requirements.

1. The provisions of this paragraph (10) shall apply to any source and the owner and operator of any such source subject to any requirements under 40 Code of Federal Regulations (hereinafter, 40 CFR), Part 70.

2. All sources subject to this paragraph (10) shall have a Part 70 Permit to operate that assures compliance by the source with all applicable requirements. Such Part 70 Permits will be issued consistent with the timing established in subparagraph (10)(c).

3. The requirements of this paragraph (10), including provisions regarding schedules for submission and approval or disapproval of permit applications, shall apply to the permitting of affected sources under the federal acid rain program except as provided herein or modified in federal regulations promulgated under Title IV of the federal Clean Air Act.

4. Definitions: For the purpose of this paragraph (10), 40 CFR Part 70.2 is hereby incorporated and adopted by reference, with the following exception(s):

(i) "Potential to emit" shall have the meaning ascribed in subparagraph (ddd) of rule 391-3-1-.01.

(ii) [Reserved.]

(iii) The definition and use of the term "subject to regulation" in 40 CFR, Part 70.2 is hereby incorporated by reference; provided, however, that in the event all or any portion of 40 CFR, Part 70.2 containing that term is:

(I) declared or adjudged to be invalid or unconstitutional or stayed by the United States Court of Appeals for the Eleventh Circuit or for the District of Columbia Circuit; or

(II) withdrawn, repealed, revoked, or otherwise rendered of no force and effect by the United States Environmental Protection Agency, Congress, or Presidential Executive Order.

Such action shall render the regulation as incorporated herein, or that portion thereof that may be affected by such action as invalid, void, stayed, or otherwise without force and effect for purposes of this rule upon the date such action becomes final and effective; provided, further, that such declaration, adjudication, stay, or other action described herein, shall not affect the remaining portions, if any, of the regulation as incorporated herein, which shall remain of full force and effect as if such portion so declared or adjudged invalid or unconstitutional or stayed or otherwise invalidated or effected were not originally a part of this rule. The Board declares that it would have incorporated the remaining parts of the federal regulation if it had known that such portion hereof would be declared or adjudged invalid or unconstitutional or stayed or otherwise rendered of no force and effect.

5. The subparagraphs of paragraph (10) that incorporate by reference portions of 40 CFR, Part 70 are as promulgated and published in the Federal Register through October 18, 2016, unless otherwise specified.

(b) Applicability.

1. The following sources shall be subject to this paragraph (10):

(i) Any major source as defined in 40 CFR 70.2, which is incorporated by reference in subparagraph (a)4;

(ii) Any source, including an area source, subject to a standard, limitation, or other requirement under Section 111 of the federal Act;

(iii) Any source, including an area source, subject to a standard or other requirement under Section 112 of the federal Act, except that a source is not required to obtain a permit solely because it is subject to regulations or requirements under Section 112(r) of the federal Act;

(iv) Any affected source as defined in 40 CFR 70.2, which is incorporated by reference in subparagraph (a)4; and

(v) Any source in a source category designated by the EPA Administrator pursuant to 40 CFR 70.3.

2. The following sources shall not be subject to this paragraph (10):

(i) Any source listed in subparagraph 10(b)1.(ii) that is not a major source;

(ii) Any source required to obtain a permit solely because they are subject to 40 CFR Part 61, Subpart M, National Emission Standard for Hazardous Air Pollutants for Asbestos, 61.145, Standard for Demolition and Renovation, or solely because they are subject to 40 CFR Part 60, Subpart AAA Standards of Performance for New Residential Wood Heaters; and

(iii) Any source listed in subparagraph (10)(b)1.(iii) that is an area source except those subject to an Emission Standard for Hazardous Air Pollutants under 40 CFR Part 63 that does not exempt the owner or operator from the obligation to obtain a Part 70 permit.

3. Emission units and Part 70 permits.

(i) For major sources, Part 70 permits shall include all applicable requirements for all relevant emission units in the major source.

(ii) For any non-major source subject to the requirements of this paragraph (10), Part 70 permits shall include all applicable requirements applicable to emission units that cause the source to be subject to this paragraph (10).

4. Fugitive emissions from a source subject to the requirements of this paragraph (10) shall be included in the permit application and the Part 70 permit in the same manner as stack emissions, regardless of whether the source category in question is included in the list of sources contained in the definition of major source.

5. Any Part 70 source may make Section 502(b)(10) changes as defined in 40 CFR 70.2, which is incorporated by reference in subparagraph (a)4, without requiring a Part 70 permit revision, if the changes are not modifications under any provisions of Title I of the federal Act and the changes do not exceed the emissions allowable under the permit (whether expressed therein as a rate of emissions or in terms of total emissions). For each such change, the source shall provide the Director and the EPA Administrator with written notification as required below in advance of the proposed changes and shall obtain any permits required under Rules 391-3-1-.03(1) and (2). The source and the Director shall attach each such notice to their copy of the relevant permit.

(i) For each such change, the source's written notification and application for a construction permit shall be submitted well in advance of any critical date (construction date, permit issuance date, etc.) involved in the change, but no less than seven days in advance of such change and shall include a brief description of the change within the permitted facility, the date on which the change is proposed to occur, any change in emissions, and any permit term or condition that is no longer applicable as a result of the change.

(ii) The permit shield described in subparagraph (d)6. shall not apply to any change made pursuant to this paragraph.

6. Off-permit Changes: Any Part 70 source may make changes that are not addressed or prohibited by the permit, other than those described in subparagraph 7., without a Part 70 permit revision, provided the following requirements are met:

(i) Each such change shall meet all applicable requirements and shall not violate any existing permit term or condition.

(ii) Sources must provide contemporaneous written notice to the Director and EPA Administrator of each such change, except for changes that qualify as insignificant as specified in subparagraph (g). Such written notice shall describe each such change, including the date, any change in emissions, pollutants emitted, and any applicable requirement that would apply as a result of the change.

(iii) The change shall not qualify for the shield under subparagraph (10)(d)6.

(iv) The permittee shall keep a record describing changes made at the source that result in emissions of a regulated air pollutant subject to an applicable requirement, but not otherwise regulated under the permit, and the emissions resulting from those changes.

(v) The source shall obtain any permits required under Rules 391-3-1-.03(1) and (2).

7. No Part 70 source may make, without a permit revision, any changes that are not addressed or prohibited by the Part 70 permit, if such changes are subject to any requirements under Title IV of the federal Act or are modifications under any provision of Title I of the federal Act.

1. For each Part 70 source, the owner or operator shall submit a complete application:

(i) Within 12 months after the U.S. EPA grants approval of this paragraph (10) or on or before such earlier date as the Director may establish, for a source applying for the first time;

(ii) Within 12 months after commencing operation, for a source required to meet the requirements under Section 112(g) of the federal Clean Air Act or to have a permit under the preconstruction review program requirements of Rule 391-3-1-.03(8)(b). Where an existing Part 70 permit would prohibit such construction or change in operation, the source must obtain a permit revision before commencing operation;

(iii) At least six months, but not more than 18 months prior to the date of permit expiration, for a source subject to permit renewal; or

(iv) By January 1, 1996, for initial Phase II sulfur dioxide acid rain permits and by January 1,1998, for initial Phase II nitrogen oxide acid rain permits.

(v) within 12 months after commencing operation for a major source which commences operation after the date specified in subparagraph (10)(c)1.(i).

2. Standard Permit Application and Required Information. The application shall be made in a format specified by the Director. It shall be signed by a responsible official, as defined in 40 CFR 70.2, which is incorporated by reference in subparagraph (a)4, certifying its truthfulness, accuracy and completeness. For the purpose of this paragraph (10), 40 CFR 70.5(c) and 40 CFR 70.5(d) are hereby incorporated and adopted by reference. The application may require additional pertinent information which is not specified in 40 CFR 70.5(c), as incorporated by reference in this subparagraph, as the Director may require. To be deemed complete, an application must provide all information required pursuant to this subparagraph and subparagraph (g), except that applications for permit revision need supply such information only if it is related to the proposed change.

3. Unless the Director determines that an application, including renewal applications, is not complete within 60 days of receipt of the application, such application shall be deemed to be complete, except as otherwise provided in 40 CFR 70.7(a)(4) which is hereby incorporated by reference.

4. If, while processing an application that has been determined or deemed to be complete, the Director determines that additional information is necessary to evaluate or take final action on that application the Director may request such information in writing and set a reasonable deadline for a response. The source's ability to operate without a Part 70 permit shall be in effect from the date the application is determined or deemed to be complete until the final permit is issued, provided that the applicant submits any requested additional information by the deadline specified by the Director.

5. Any applicant who fails to submit any relevant facts or who has submitted incorrect information in a permit application shall, upon becoming aware of such failure or incorrect submittal, promptly submit such supplementary facts or corrected information. In addition, an applicant shall provide additional information as necessary to address any requirements that become applicable to the source after the date it filed a complete application but prior to release of a draft permit.

(d) Permit Content.

1. Standard Permit Requirements.

(i) For the purposes of this paragraph (10), 40 CFR 70.6(a) and 40 CFR 70.7(f) are hereby incorporated and adopted by reference.

(ii) The permit may include terms and conditions allowing for the trading of emissions changes in the permitted facility solely for the purpose of complying with a federally enforceable emissions cap that is established in the permit independent of otherwise applicable requirements. The permit applicant shall include in its application proposed replicable procedures and permit terms that ensure that the emissions trades are quantifiable and enforceable. The Director shall not be required to include in the emissions trading provisions any emissions units for which emissions are not quantifiable or for which there are no replicable procedures to enforce the emissions trades. The following conditions apply to the emissions trades:

(I) The permittee shall provide written notification to the Director and EPA no less than seven days in advance of any change made pursuant to this subparagraph. The written notification shall state when the change will occur and shall describe the changes in emissions that will result and how these increases and decreases in emissions will comply with the terms and conditions of the permit.

(II) The permit shield described in subparagraph (d)6. may extend to the permit terms and conditions that allow for the emissions increases and decreases described in this subparagraph.

(iii) The permit may include additional elements not specified in 40 CFR 70.6(a), which is incorporated by reference in subparagraph (d)1.(i), as required by the Director.

2. The Director shall specifically designate as not being federally enforceable under the federal Clean Air Act any terms and conditions included in the permit that are not required under the federal Clean Air Act or under any of its applicable requirements. If the Director does not so designate a term or condition, it shall be deemed federally enforceable.

3. Compliance Requirements. For the purposes of this paragraph (10), 40 CFR 70.6(c) is hereby incorporated and adopted by reference.

4. General Permits: For the purpose of this paragraph (10), 40 CFR 70.6(d) is hereby incorporated and adopted by reference.

5. The Director may issue a single permit authorizing emissions from similar operations by the same source owner or operator at multiple temporary locations. The operation must be temporary and involve at least one chance of location during the term of the permit. No affected source shall be permitted as a temporary source. Permits for temporary sources shall include:

(i) Conditions that will assure compliance with all applicable requirements at all authorized locations;

(ii) Requirements that the owner or operator notify the Director at least 30 days in advance of each change in location; and

(iii) Conditions that assure compliance with all of the provisions of this paragraph.

6. Permit Shield.

(i) Except as provided in this paragraph (10), the Director may expressly include in a Part 70 permit a provision stating that a source which is in compliance with the conditions of the permit shall be deemed to be in compliance with any applicable requirements as of the date of the permit issuance, provided that:

(I) Such applicable requirements are included and are specifically identified in the permit; or

(II) The Director, in acting on the permit application or revision, determines in writing that other requirements specifically identified are not applicable to the source, and the permit includes the determination or a concise summary thereof.

(ii) A Part 70 permit that does not expressly state that a permit shield exists shall be presumed not to provide such a shield.

(iii) Nothing in this paragraph or in any Part 70 permit shall alter or affect the following:

(I) The provisions of Section 303 of the federal Clean Air Act (emergency orders), including the authority of the Administrator under that section or the provisions of O.C.G.A. Section 12-9-14;

(II) The liability of an owner or operator of a source for any violation of applicable requirements prior to or at the time of permit issuance; or

(III) The applicable requirements of the acid rain program, consistent with Section 408(a) of the federal Clean Air Act; or

(IV) The ability of EPA to obtain information from a source pursuant to Section 114 of the federal Clean Air Act or of the Director to obtain information from a source pursuant to paragraph 391-3-1-.02(6).

7. Emergency Provision: For the purpose of subparagraph (d)7., 40 CFR Part 70.6(g) is hereby incorporated and adopted by reference.

(e) Permit Issuance, Renewal, Reopenings and Revisions.

1. Action on application.

(i) A permit, permit modification, or renewal may be issued only if all of the following conditions have been met:

(I) The Director has received a complete application, except that a complete application need not be received before issuance of a general permit under subparagraph (d);

(II) Except for modifications qualifying for minor permit modification procedures under subparagraphs (e)5.(i) or (e)5.(ii), the Director has complied with the requirements for public participation under subparagraph (e)8.;

(III) The Director has complied with the requirements for notifying and responding to affected States under subparagraph (f);

(IV) The conditions of the permit provide for compliance with all applicable requirements; and

(V) The EPA Administrator has received a copy of the proposed permit and any notices required under subparagraph (f) and has not objected to issuance of the permit under subparagraph (f) within the time period specified therein.

(ii) Except as provided under the initial transition plan or under regulations promulgated under Title IV of the federal Clean Air Act, the Director shall take final action on each permit application (including request for permit modification or renewal) within 18 months after receiving a complete application.

(iii) The Director shall provide a statement that sets forth the legal and factual basis for the draft permit conditions (including references to the applicable statutory or regulatory provisions). The Director shall send this statement to EPA and to any other person who requests it.

(iv) The submittal of a complete application shall not affect the requirement that any source have a preconstruction permit under paragraph 391-3-1-.03(8).

2. Requirement for a permit.

Except as provided in subparagraphs (b)5., (e)5.(i)(V) and (e)5.(ii)(V), no Part 70 source may operate after the time that it is required to submit a timely and complete application, except in compliance with a permit issued under this paragraph (10). If a Part 70 source submits a timely and complete application for permit issuance (including for renewal), the source's failure to have a Part 70 permit is not a violation until the Director takes final action on the permit application. This protection shall cease to apply if, subsequent to the completeness determination, the applicant fails to submit by the deadline specified in writing by the Director any additional information identified as being needed to process the application.

3. Permit renewal and expiration.

(i) Permits being renewed are subject to the same procedural requirements, including those for public participation, affected State and EPA review, that apply to initial permit issuance.

(ii) Permit expiration terminates the source's right to operate unless a timely and complete renewal application has been submitted.

(iii) If a timely and complete application for permit renewal is submitted, but the Director has failed to issue or deny the renewal permit before the end of the term of the previous permit, then the permit shall not expire until the renewal permit has been issued or denied and any permit shield that may be granted pursuant to subparagraph (d)6. shall extend beyond the original permit term until renewal.

4. Administrative permit amendments.

(i) Definitions: For the purpose of this paragraph, 40 CFR, 70.7(d)(1) is incorporated and adopted by reference.

(ii) Administrative permit amendments for purposes of the acid rain portion of the permit shall be governed by regulations promulgated under Title IV of the federal Clean Air Act.

(iii) An administrative permit amendment may be made by the Director consistent with the following:

(I) The Director shall take no more than 60 days from receipt of a request for an administrative permit amendment to take final action on such request, and may incorporate such changes without providing notice to the public or affected States provided that it designates any such permit revisions as having been made pursuant to this subparagraph.

(II) The Director shall submit a copy of the revised permit to the EPA Administrator.

(III) The source may implement the changes addressed in the request for an administrative amendment immediately upon submittal of the request.

(iv) The Director may, upon taking final action granting a request for an administrative permit amendment, allow coverage by the permit shield for administrative permit amendments made pursuant to 40 CFR 70.7(d)(1)(v), which is incorporated by reference in subparagraph (e)4.(i) of this rule, which meet the requirements for significant permit modifications.

5. Permit modification.

A permit modification is any revision to a Part 70 permit that cannot be accomplished under subparagraph 4. A permit modification for purposes of the acid rain program shall be governed by regulations promulgated under Title IV of the federal Clean Air Act.

(i) Minor permit modification procedures.

(I) Minor permit modification procedures may be used only for those permit modifications that:

I. Do not violate any applicable requirement;

II. Do not involve significant changes to existing monitoring, reporting, or recordkeeping requirements in the permit;

III. Do not require or change a case-by-case determination of an emission limitation or other standard, or a source specific determination for temporary sources of ambient impacts, or a visibility or increment analysis;

IV. Do not seek to establish or change a permit term or condition for which there is no corresponding underlying applicable requirement and that the source has assumed to avoid an applicable requirement to which the source would otherwise be subject, including a federally enforceable emissions cap assumed to avoid classification as a modification under any provision of 391-3-1-.03(8), and an alternative emissions limit approved pursuant to regulations promulgated under Section 112(j)(5) of the federal Clean Air Act;

V. Are not modifications under any provision of 391-3-1-.03(8); and

VI. Are not required by this paragraph (10) to be processed as a significant modification.

(II) An application requesting the use of minor permit modification procedures shall meet the requirements of paragraph (8) and shall include the following:

I. A description of the change, the emissions resulting from the change, and any new applicable requirements that will apply if the change occurs;

II. The source's suggested draft permit;

III. Certification by a responsible official, consistent with subparagraph (c), that the proposed modification meets the criteria for use of minor modification procedures and a request that such procedures be used; and

IV. Completed forms for the Director to use to notify the EPA Administrator and affected States as required under subparagraph (f).

(III) Within five working days of receipt of a complete minor permit modification application, the Director shall meet his obligation under subparagraph (f)(1) and subparagraph (f)(2)(i) to notify the EPA Administrator and affected States of the requested permit modification. The Director shall promptly send any notice required under subparagraph (f)(2)(ii) to the EPA Administrator.

(IV) The Director may not issue a final permit modification until after EPA's 45-day review period or until EPA has notified the Director that EPA will not object to issuance of the permit modification, whichever is first, although the Director can approve the permit modification prior to that time. Within 90 days of the Director's receipt of an application under minor permit modification procedures or 15 days after the end of the EPA Administrator's 45-day review period under subparagraph (f)(3), whichever is later, the Director shall:

I. Issue the permit modification as proposed;

II. Deny the permit modification application;

III. Determine that the requested modification does not meet the minor permit modification criteria and should be reviewed under the significant modification procedures; or

IV. Revise the draft permit modification and transmit to the EPA Administrator the new proposed permit modification as required by subparagraph (f).

(V) The source may make changes proposed in its minor permit modification application as follows:

I. For proposed changes that require a permit in accordance with 391-3-1-.03(1), the source may make the change proposed in its minor permit modification application immediately after obtaining a permit for the modification pursuant to the requirements of 391-3-1-.03(1). After the source makes such change and until the Director takes any of the actions specified in subparagraph (IV), the source must comply with the applicable requirements governing the change, the proposed permit terms and conditions, and requirements of the construction permit issued under 391-3-1-.03(1). During this time period, the source need not comply with the existing permit terms and conditions it seeks to modify. However, if the source fails to comply with its proposed permit terms and conditions and the requirements of the construction permit issued under 391-3-1-.03(1) during this time period, the existing permit terms and conditions it seeks to modify and the requirements of the construction permit issued under 391-3-1-.03(1) may be enforced against it.

II. For proposed changes that do not require a permit in accordance with 391-3-1-.03(1), the source may make the change proposed in its minor permit modification application upon receipt of a letter from the Division acknowledging receipt of said application. If the Director denies the permit modification application in accordance with subparagraph (IV)II, the existing terms and conditions that the applicant seeks to modify may be enforced by the Division.

(VI) The permit shield may not extend to minor permit modifications.

(ii) Group processing of minor permit modifications. The Director may modify the procedure outlined in subparagraph (e)5.(i) to process groups of a source's applications for certain modifications eligible for minor permit modification processing.

(I) Group processing of modifications may be used only for those permit modifications:

I. That meet the criteria for minor permit modification procedures under subparagraph (e)5.(i); and

II. That collectively are below 10 percent of the emissions allowed by the permit for the emissions unit for which the change is requested, 20 percent of the applicable definition of major source in subparagraph (a)4., or 5 tons per year, whichever is least.

(II) An application requesting the use of group processing procedures shall meet the requirements of subparagraph (c)2. and shall include the following:

I. A description of the change, the emissions resulting from the change, and any new applicable requirements that will apply if the change occurs.

II. The source's suggested draft permit.

III. Certification by a responsible official that the proposed modification meets the criteria for use of group processing procedures under a request that such procedures be used.

IV. A list of the source's other pending applications awaiting group processing, and determination of whether the requested modification, aggregated with these other applications, equals or exceeds the threshold set under subparagraph (e)5.(ii)(I)II.

V. Certification that the source has notified EPA of the proposed modification. Such notification need only contain a brief description of the proposed modification.

VI. Completed forms for the Director to use to notify the EPA Administrator and affected States as required under subparagraph (f).

(III) On a quarterly basis or within five business days of receipt of an application demonstrating that the aggregate of a source's pending applications equals or exceeds the threshold level set in subparagraph (e)5.(ii)(I)II., whichever is earlier, the Director promptly shall comply with subparagraphs (f)(1) and (f)(2). The Director shall send any notice required under subparagraph (f)(2)(ii) to the EPA Administrator.

(IV) The provisions of subparagraph (e)5.(i)(IV) shall apply to modifications eligible for group processing, except that the Director shall take one of the actions specified in subparagraphs (e)5.(i)(IV)I. through IV. within 180 days of receipt of the application or 15 days after the end of the EPA Administrator's 45-day review period under subparagraph (f)(3), whichever is later.

(V) The provisions of subparagraph 5.(i)(V) shall apply to modifications eligible for group processing.

(VI) The provisions of subparagraph 5.(i)(VI) shall also apply to modifications eligible for group processing.

(iii) Significant modification procedures.

(I) Significant modification procedures shall be used for applications requesting permit modifications that do not qualify as minor permit modifications or as administrative amendments. At a minimum, every significant change in existing monitoring permit terms or conditions and every relaxation of reporting or recordkeeping permit terms or conditions shall be considered significant. Nothing herein shall be construed to preclude the permittee from making changes consistent with this paragraph (10) that would render existing permit compliance terms and conditions irrelevant.

(II) Significant permit modifications shall meet all requirements of this paragraph (10), including those for applications, public participation, review by affected States, and review by EPA, as they apply to permit issuance and permit renewal.

6. Reopening for cause.

(i) A permit shall be reopened and revised under any of the following circumstances:

(I) Additional applicable requirements become applicable to a major Part 70 source with a remaining permit term of three or more years. Such a reopening shall be completed not later than 18 months after promulgation of the applicable requirement. No such reopening is required if the effective date of the requirement is later than the date on which the permit is due to expire, unless the original permit or any of its terms and conditions has been extended under subparagraph (e)3.(iii).

(II) Additional requirements (including excess emissions requirements) become applicable to an affected source under the acid rain program. Upon approval by the Administrator, excess emissions offset plans shall be deemed to be incorporated into the permit.

(III) The Director determines that the permit contains a material mistake or that inaccurate statements were made in establishing the emissions standards or other terms or conditions of the permit.

(IV) The Director determines that the permit must be revised or revoked to assure compliance with the applicable requirements.

(ii) Proceedings to reopen and issue a permit shall follow the same procedures as apply to initial permit issuance and shall affect only those parts of the permit for which cause to reopen exists.

(i) Reopenings shall not be initiated before a notice of such intent is provided to the source by the Director at least 30 days in advance of the date that the permit is to be reopened, except that the Director may provide a shorter time period in the case of an emergency.

7. Reopenings for cause by EPA.

(i) If the EPA Administrator finds that cause exists to terminate, modify or revoke and reissue a permit pursuant to subparagraph 6. and notifies the Director of such finding in writing, the Director shall, within 90 days after receipt of such notification, forward to EPA a proposed determination of termination, modification, or revocation and reissuance, as appropriate. If the EPA Administrator finds that a new or revised permit application is necessary or that the Director must require the permittee to submit additional information and extends this 90 day period, the Director shall forward the subject determination within 180 days of receipt of EPA's notification.

(ii) Within 90 days from receipt of an EPA objection, the Director shall resolve such objection and terminate, modify, or revoke and reissue the permit in accordance with EPA's objection.

8. Public participation.

40 CFR Part 70.7(h) is hereby incorporated and adopted by reference.

(f) Permit review by EPA and affected states.

1. The Director shall provide the EPA Administrator a copy of each permit application (including any application for permit modification), each proposed permit, and each final Part 70 permit. The Director may require the applicant to provide a copy of the permit application (including the compliance plan) directly to the EPA Administrator. Upon approval by the EPA Administrator, the Director may submit to the EPA Administrator a permit application summary form and any relevant portion of the permit application and compliance plan, in place of the complete permit application and compliance plan.

2. Review by affected States.

(i) The Director shall give notice of each draft permit to any affected State on or before the time that the Director provides this notice to the public under subparagraph (e)8., except to the extent that subparagraphs (e)5.(i) or (e)5.(ii) require the timing of the notice to be different.

(ii) The Director, as part of the submittal of the proposed permit to the EPA Administrator [or as soon as possible after the submittal for minor permit procedures allowed under subparagraphs (e)5.(i) or (e)5.(ii)], shall notify the EPA Administrator and any affected State in writing of any refusal by the Director to accept all recommendations for the proposed permit that the affected State submitted during the public or affected State comment period. The notice shall include the Director's reasons for not accepting any such recommendation. The Director is not required to accept recommendations that are not based on applicable requirements or the requirements of this paragraph (10).

3. EPA objection.

(i) No permit for which an application must be transmitted to the EPA Administrator under subparagraph (f)1. shall be issued if the EPA Administrator objects to its issuance in writing within a timely manner pursuant to 40 CFR 70.8(c) and 40 CFR 70.8(d) which are hereby incorporated by reference.

(g) Insignificant Activities List.

Unless otherwise required by the Director, the following air pollutant sources/activities must be listed, but need not be described in detail, in the Part 70 permit application. Exclusion of these emissions from detailed reporting does not exclude them from inclusion in any applicability determination. Additionally, this insignificant listing may not be used to avoid any applicable requirement (i.e., NESHAP, NSPS, etc.) as defined in 40 CFR 70.2, which is incorporated by reference in subparagraph (a)4.

1. Mobile Sources.

(i) Cleaning and sweeping of streets and paved surfaces.

2. Combustion Equipment.

(i) Firefighting equipment, including fire pumps or other emergency/safety equipment used to fight fires or train firefighters or other emergency personnel.

(ii) Small incinerators that are not subject to any standard, limitation or other requirement under Section 111 or 112 [excluding 112(r)] of the Federal Act and are not considered a "designated facility" as specified in 40 CFR 60.32e of the Federal emissions guidelines for Hospital/Medical/ Infectious Waste Incinerators, that are operating as follows:

(I) Less than 8 million BTUs per hour heat input, firing types 0, 1, 2 and/or 3 waste; or

(II) Less than 8 million BTUs per hour heat input with no more than 10% pathological (Type-4) waste by weight combined with types 0, 1, 2 and/or 3 waste; or

(III) Less than 4 million BTUs per hour heat input firing Type 4 waste.

(IV) For the purpose of this subparagraph, the following definitions apply:

I. "Type 0 waste" means trash. This refers to a mixture of combustible waste such as paper, cardboard, wood and floor sweepings; which contains up to 10% petrochemical waste, 5% non-combustibles and 10% moisture, by weight; which is generated from commercial activities; and having a higher heat value (HHV) of approximately 8,500 BTU/lb.

II. "Type 1 waste" means rubbish. This refers to a mixture of combustible waste such as paper, cardboard, wood foliage and floor sweepings; which contains up to 10% petrochemical waste, 5% non-combustibles and 10% moisture, by weight; which is generated from domestic and commercial activities; and having a HHV of approximately 6,500 BTU/lb.

III. "Type 2 waste" means refuse. This refers to an evenly distributed mixture of rubbish and garbage as usually received in municipal waste; which contains up to 50% moisture content, by weight and 7% non-combustible solids; and having a HHV of approximately 4,300 BTU/lb.

IV. "Type 3 waste" means garbage. This refers to animal and vegetable wastes from restaurants, cafeterias, hotels, markets, and like installations; which contains up to 70% moisture, by weight, and 5% non-combustible solids; and having a HHV of approximately 2,500 BTU/lb.

V. "Type 4 waste" means human and animal remains. This refers to carcasses, organs, and solid organic wastes from hospitals, laboratories, abattoirs, animal pounds; and having a HHV of approximately 1,000 BTU/lb.

(iii) Open burning in compliance with Georgia Rule 391-3-1-.02(5).

(iv) Stationary Engines Burning:

(I) Natural gas, gasoline, diesel fuel, or dual fuels which are used exclusively as emergency generators; or

(II) Natural gas, LPG, and/or diesel fuel and used for peaking power (including emergency generators used for peaking power) where the peaking power use does not exceed 200 hours-per-year, except in the counties of Banks, Barrow, Bartow, Butts, Carroll, Chattooga, Cherokee, Clarke, Clayton, Cobb, Coweta, Dawson, DeKalb, Douglas, Fayette, Floyd, Forsyth, Fulton, Gordon, Gwinnett, Hall, Haralson, Heard, Henry, Jackson, Jasper, Jones, Lamar, Lumpkin, Madison, Meriwether, Monroe, Morgan, Newton, Oconee, Paulding, Pickens, Pike, Polk, Putnam, Rockdale, Spalding, Troup, Upson, and Walton where such engines with a rated capacity equal to and greater than 100 kilowatts are not insignificant activities; or

(III) Natural gas, LPG, and/or diesel fuel used for other purposes, provided that the output of each engine does not exceed 400 horsepower and that no individual engine operates for more than one thousand hours-per-year; or

(IV) Gasoline used for other purposes, provided that the output of each engine does not exceed 100 horsepower and that no individual engine operates for more than 500 hours-per-year except in the counties of Banks, Barrow, Bartow, Butts, Carroll, Chattooga, Cherokee, Clarke, Clayton, Cobb, Coweta, Dawson, DeKalb, Douglas, Fayette, Floyd, Forsyth, Fulton, Gordon, Gwinnett, Hall, Haralson, Heard, Henry, Jackson, Jasper, Jones, Lamar, Lumpkin, Madison, Meriwether, Monroe, Morgan, Newton, Oconee, Paulding, Pickens, Pike, Polk, Putnam, Rockdale, Spalding, Troup, Upson, and Walton where such engines with a rated capacity equal to and greater than 100 kilowatts used for peaking power are not insignificant activities.

(V) For the purpose of this subparagraph, the following definitions shall apply:

I. An "emergency generator" means a generator whose function is to provide back-up power when electric power from the local utility is interrupted and which operates for less than 500 hours-per-year, except in the counties of Banks, Barrow, Bartow, Butts, Carroll, Chattooga, Cherokee, Clarke, Clayton, Cobb, Coweta, Dawson, DeKalb, Douglas, Fayette, Floyd, Forsyth, Fulton, Gordon, Gwinnett, Hall, Haralson, Heard, Henry, Jackson, Jasper, Jones, Lamar, Lumpkin, Madison, Meriwether, Monroe, Morgan, Newton, Oconee, Paulding, Pickens, Pike, Polk, Putnam, Rockdale, Spalding, Troup, Upson, and Walton where such generator operates less than 200 hours-per-year.

II. "Used for peaking power" means used to reduce the electrical power requirements on the local utility grid. This could be for supplying power during the local utility's peak demand periods or for peak shaving by the facility.

3. Trade Operations.

(i) Brazing, soldering and welding equipment, and cutting torches related manufacturing and construction activities whose emissions of hazardous air pollutants (HAPs) fall below 1,000 pounds per year.

4. Maintenance, Cleaning, and Housekeeping.

(i) Blast-cleaning equipment using a suspension of abrasive in water and any exhaust system (or collector) serving them exclusively.

(ii) Portable blast-cleaning equipment.

(iii) Non-Perchloroethylene Dry-cleaning equipment with a capacity of 100 pounds per hour or less of clothes.

(iv) Cold cleaners having an air/vapor interface of not more than 10 square feet and that do not use a halogenated solvent.

(v) Non-routine clean out of tanks and equipment for the purposes of worker entry or in preparation for maintenance or decommissioning.

(vi) Devices used exclusively for cleaning metal parts or surfaces by burning off residual amounts of paint, varnish, or other foreign material, provided that such devices are equipped with afterburners.

(vii) Cleaning Operations: Alkaline/phosphate cleaners and associated cleaners and burners.

5. Laboratories and Testing.

(i) Laboratory fume hoods and vents associated with bench-scale laboratory equipment used for physical or chemical analysis.

(ii) Research and development facilities, quality control testing facilities and/or small pilot projects, where combined daily emissions from all operations are not individually major and are not support facilities making significant contributions to the product of a collocated major manufacturing facility.

6. Pollution Control.

(i) Sanitary wastewater collection and treatment systems, except incineration equipment or equipment subject to any standard, limitation or other requirement under Section 111 or 112 [excluding 112(r)] of the Federal Act.

(ii) On site soil or groundwater decontamination units that are not subject to any standard, limitation or other requirement under Section 111 or 112 [excluding 112(r)] of the Federal Act.

(iii) Bioremediation operations units that are not subject to any standard, limitation or other requirement under Section 111 or 112 [excluding 112(r)] of the Federal Act.

(iv) Landfills that are not subject to any standard, limitation or other requirement under Section 111 or 112 [excluding 112(r)] of the Federal Act.

7. Industrial Operations.

(i) Concrete block and brick plants, concrete products plants, and ready mix concrete plants producing less than 125,000 tons per year.

(ii) Any of the following processes or process equipment which are electrically heated or which fire natural gas, LPG or distillate fuel oil at a maximum total heat input rate of not more than five million BTUs per hour:

(I) Furnaces for heat treating glass or metals, the use of which do not involve molten materials or oil-coated parts.

(II) Porcelain enameling furnaces or porcelain enameling drying ovens.

(III) Kilns for firing ceramic ware.

(IV) Crucible furnaces, pot furnaces, or induction melting and holding furnaces with a capacity of 1,000 pounds or less each, in which sweating or distilling is not conducted and in which fluxing is not conducted utilizing free chlorine, chloride or fluoride derivatives, or ammonium compounds.

(V) Bakery ovens and confection cookers.

(VI) Feed mill or grain mill ovens.

(VII) Surface coating drying ovens.

(iii) Carving, cutting, routing, turning, drilling, machining, sawing, surface grinding, sanding, planing, buffing, shot blasting, shot peening, or polishing; ceramics, glass, leather, metals, plastics, rubber, concrete, paper stock or wood, also including roll grinding and ground wood pulping stone sharpening, provided that:

(I) The activity is performed indoors; and

(II) No significant fugitive particulate emissions enter the environment; and

(III) No visible emissions enter the outdoor atmosphere.

(iv) Photographic process equipment by which an image is reproduced upon material sensitized to radiant energy (e.g., blueprint activity, photographic developing and microfiche).

(v) Grain, food, or mineral extrusion processes.

(vi) Equipment used exclusively for sintering of glass or metals, but not including equipment used for sintering metal-bearing ores, metal scale, clay, fly ash, or metal compounds.

(vii) Equipment for the mining and screening of uncrushed native sand and gravel.

(viii) Ozonization process or process equipment.

(ix) Electrostatic powder coating booths with an appropriately designed and operated particulate control system.

(x) Activities involving the application of hot melt adhesives where VOC emissions are less than 5 tons per year and HAP emissions are less than 1,000 pounds per year.

(xi) Equipment used exclusively for mixing and blending water-based adhesives and coatings at ambient temperatures.

(xii) Equipment used for compression, molding and injection of plastics where VOC emissions are less than 5 tons per year and HAP emissions are less than 1,000 pounds per year.

(xiii) Ultraviolet curing processes where VOC emissions are less than five tons per year and HAP emissions are less than 1,000 pounds per year.

8. Storage Tanks and Equipment.

(i) All petroleum liquid storage tanks storing a liquid with a true vapor pressure of equal to or less than 0.50 psia as stored.

(ii) All petroleum liquid storage tanks with a capacity of less than 40,000 gallons storing a liquid with a true vapor pressure of equal to or less than 2.0 psia as stored that are not subject to any standard, limitation or other requirement under Section 111 or 112 [excluding 112(r)] of the Federal Act.

(iii) All petroleum liquid storage tanks with a capacity of less than 10,000 gallons storing a petroleum liquid.

(iv) All pressurized vessels designed to operate in excess of 30 psig storing petroleum fuels that are not subject to any standard, limitation or other requirement under Section 111 or 112 [excluding 112(r)] of the Federal Act.

(v) Gasoline storage and handling equipment at loading facilities handling less than 20,000 gallons per day or at vehicle dispensing facilities that are not subject to any standard, limitation or other requirement under Section 111 or 112 [excluding 112(r)] of the Federal Act.

(vi) Portable drums, barrels, and totes provided that the volume of each container does not exceed 550 gallons.

(vii) All chemical storage tanks used to store a chemical with a true vapor pressure of less than or equal to 10 millimeters of mercury (0.19 psia).

(11) Permit by Rule.

(a) General Requirements.

1. Accepting a Permit by Rule does not exempt that facility from the obligation to apply for and obtain a Construction (SIP) Permit and/or an Operating (SIP) Permit unless specifically exempted in the permit by rule. Complying with the requirements of a Permit by Rule does not relieve a facility of having to comply with other requirements of the Rules.

2. The permitting authority may, after notice and opportunity for public participation, issue a Permit by Rule covering numerous similar sources. Any Permit by Rule shall identify criteria and standards by which sources may qualify for the Permit by Rule. Any facility wishing to operate under a Permit by Rule shall certify that in writing to the permitting authority, unless specifically exempted from this requirement in the specific Permit by Rule. To sources that qualify, the permitting authority shall grant the conditions and terms of the Permit by Rule by Certification letter. Notwithstanding the shield provisions of 40 CFR 70.6(f), the source shall be subject to enforcement action for operation without a Part 70 Permit if the source is later determined not to qualify for the conditions and terms of the Permit by Rule.

3. It is the responsibility of any facility accepting a "Permit by Rule" to submit a report within 15 days following the last day of any month in which the facility exceeds the annual limit during the previous 12 months or monthly limit during the previous month. The report shall include the following:

(i) Facility name, ID, and location.

(ii) The "Permit by Rule" name, number and applicable limits.

(iii) A summary of the records showing the exceedance along with an explanation.

(iv) What the facility plans to do to prevent future occurrences.

(b) Permit by Rule Standards.

1. Fuel-Burning Equipment Burning Natural Gas/LPG and/or Distillate Oil.

(i) Notwithstanding any other provision of these Rules, this standard applies to facilities with external combustion fuel burning equipment rated at less than or equal to 100 million BTU per hour, with a potential to emit in excess of the Part 70 major source threshold, without existing permit conditions that are federally enforceable or enforceable as a practical matter limiting the source to below Part 70 major source thresholds. Facilities for which the only source of regulated air pollutants from external combustion fuel-burning equipment (excluding turbines) is from equipment permitted to burn natural gas/LPG and/or distillate oil exclusively shall be deemed to have a Permit by Rule if the conditions in paragraph (I) and (II) are met. Facilities that have potential emissions of greater than major source thresholds even after this rule is met or are not able to meet the conditions in paragraphs (I) and (II) shall obtain a Part 70 Permit. All facilities located in the counties of Cherokee, Clayton, Cobb, Coweta, DeKalb, Douglas, Fayette, Forsyth, Fulton, Gwinnett, Henry, Paulding, and Rockdale, which were granted a Permit by Rule by certification letter dated prior to January 1, 2004 and which seek to continue to operate under this Permit by Rule, shall submit a new written certification of compliance with revised paragraphs (I) and (II) by no later than October 31, 2004.

(I) Monitoring and Record keeping. A log of the monthly fuel use must be kept. The total fuel usage for the previous twelve consecutive months must be included in each month's log. Consumption of distillate oil shall be recorded in gallons, consumption of LPG shall be recorded in gallons and consumption of natural gas shall be recorded in cubic feet. This log shall be kept for five years from the date of last entry. The log shall be available for inspection or submittal to the Division.

(II) Fuel Usage. Facility fuel usage shall be limited to 900 million cubic feet of natural gas (or 7.0 million gallons of LPG) and 1.6 million gallons of distillate oil during any twelve consecutive months except in the counties of Cherokee, Clayton, Cobb, Coweta, DeKalb, Douglas, Fayette, Forsyth, Fulton, Gwinnett, Henry, Paulding, and Rockdale, where fuel usage shall be limited to 300 million cubic feet of natural gas (or 1.5 million gallons of LPG) and 500,000 gallons of distillate oil during any twelve consecutive months.

2. Fuel-Burning Equipment Burning Natural Gas/LPG and/or Residual Oil.

(i) Notwithstanding any other provision of these Rules, this standard applies to facilities with external combustion fuel burning equipment rated at less than or equal to 100 million BTU per hour, with a potential to emit in excess of the Part 70 major source threshold without existing permit conditions that are federally enforceable or enforceable as a practical matter limiting the source to below Part 70 major source thresholds. Facilities for which the only source of regulated air pollutants from external combustion fuel burning equipment is from equipment permitted to burn only natural gas/LPG and/or residual fuel oil exclusively shall be deemed to have a Permit by Rule if the conditions in paragraph (I) and (II) are met. Facilities that have potential emissions greater than major source thresholds even after this rule is met or are not able to meet the conditions in paragraphs (I) and (II) shall obtain a Part 70 Permit. All facilities located in the counties of Cherokee, Clayton, Cobb, Coweta, DeKalb, Douglas, Fayette, Forsyth, Fulton, Gwinnett, Henry, Paulding, and Rockdale, which were granted a Permit by Rule by certification letter dated prior to January 1, 2004 and which seek to continue to operate under this Permit by Rule, shall submit a new written certification of compliance with revised paragraphs (I) and (II) by no later than October 31, 2004.

(I) Monitoring and Recordkeeping. A log of the monthly fuel use must be kept. The total fuel usage for the previous twelve consecutive months must be included in each month's log. Consumption of residual fuel oil shall be recorded in gallons, consumption of LPG shall be recorded in gallons and consumption of natural gas shall be recorded in cubic feet. This log shall be kept for five years past the date of last entry. The log shall be available for inspection or submittal to the Division.

(II) Fuel Usage. Annual facility fuel usage shall be limited to 1,000 million cubic feet of natural gas (or 7.5 million gallons of LPG) and 400,000 gallons residual fuel oil during any twelve consecutive months except in the counties of Cherokee, Clayton, Cobb, Coweta, DeKalb, Douglas, Fayette, Forsyth, Fulton, Gwinnett, Henry, Paulding, or Rockdale, where fuel usage shall be limited to 300 million cubic feet of natural gas (or 1.5 million gallons of LPG) and 200,000 gallons of residual fuel oil.

3. On-Site Power Generation.

(i) Notwithstanding any other provision of these Rules, this standard applies to facilities with a potential to emit in excess of the Part 70 major source threshold without existing permit conditions that are federally enforceable or enforceable as a practical matter limiting the source to below Part 70 major source thresholds. Facilities that operate internal combustion engines for purposes of generating emergency power, peaking power, and/or temporary on-site power and where such equipment burns natural gas/LPG, #1 fuel oil (kerosene/JP4 or JP5) and/or #2 fuel oil/diesel exclusively shall be deemed to have a Permit by Rule if the conditions in paragraph (I) and (II) are met. Facilities that have potential emissions of greater than major source thresholds even after this rule is met or are not able to meet the conditions in paragraphs (I) and (II) shall obtain a Part 70 Permit. All facilities located in the counties of Cherokee, Clayton, Cobb, Coweta, DeKalb, Douglas, Fayette, Forsyth, Fulton, Gwinnett, Henry, Paulding, and Rockdale, which were granted a Permit by Rule by certification letter dated prior to January 1, 2004 and which seek to continue to operate under this Permit by Rule, shall submit a new written certification of compliance with revised paragraphs (I) and (II) by no later than October 31, 2004.

(I) Monitoring and Record Keeping. A log of the monthly total horsepower-hours for the facility based on the number of hours of operation of each unit per month times the maximum horsepower rating of that unit must be included in each month's log. The total horsepower-hours for the previous twelve consecutive months must be included in each month's log. This log shall be kept for five years from the date of last entry. The log shall be available for inspection or submittal to the Division.

(II) Power Production Limits. A facility's power generation is limited to a total of no more than 6.7 million horsepower-hours during any twelve consecutive months except in the counties of Cherokee, Clayton, Cobb, Coweta, DeKalb, Douglas, Fayette, Forsyth, Fulton, Gwinnett, Henry, Paulding, and Rockdale counties, where the total is no more than 1.675 million horsepower-hours during any twelve consecutive months.

4. Concrete Mixing Plants.

(I) Monitoring and Recordkeeping. A log of the monthly production must be kept. The total production for the previous twelve consecutive months must be included in each month's log. This log shall be kept for five years from the date of last entry. The log shall be available for inspection or submittal to the Division.

(II) Annual Production. Production on the plant site shall be limited to 600,000 cubic yards during any twelve consecutive months.

5. Hot Mix Asphalt Plants.

(i) Notwithstanding any other provision of these Rules, this standard applies to hot mix asphalt facilities with a potential to emit in excess of the Part 70 major source threshold without existing permit conditions that are federally enforceable or enforceable as a practical matter limiting the source to below Part 70 major source thresholds. Hot mix asphalt plants shall be deemed to have a Permit by Rule if the conditions in paragraph (I) and (II) are met. Facilities that would otherwise have potential emissions of greater than major source thresholds or are not able to meet the conditions in paragraphs (I) and (II) shall obtain a Part 70 Permit. All facilities located in the counties of Cherokee, Clayton, Cobb, Coweta, DeKalb, Douglas, Fayette, Forsyth, Fulton, Gwinnett, Henry, Paulding, and Rockdale, which were granted a Permit by Rule by certification letter dated prior to January 1, 2004 and which seek to continue to operate under this Permit by Rule, shall submit a new written certification of compliance with revised paragraphs (I) and (II) by no later than October 31, 2004.

(I) Monitoring and Record Keeping.

I. New asphalt plants (which commenced construction or modification after June 11, 1973) permitted to burn natural gas/LPG and/or distillate oil only shall maintain a monthly log of production and hours of operation. The total production and hours of operation for the previous twelve consecutive months must be included in each month's log. These logs shall be kept for five years from the date of last entry and shall be available for inspection and/or submittal to the Division.

II. New and existing asphalt plants permitted to burn natural gas/LPG, distillate oil, and residual oil in any combination shall maintain a monthly log of production, hours of operation and monthly fuel use. The total production, hours of operation and fuel oil usage for the previous twelve consecutive months must be included in each month's log. Fuel oil certifications showing sulfur content equal to or less than 1.5% shall also be maintained. These logs and certifications shall be kept for five years from the date of last entry and shall be available for inspection and/or submittal to the Division.

(II) Annual Production.

I. New asphalt plants (which commenced construction or modification after June 11, 1973) permitted to burn natural gas/LPG and/or distillate oil only shall limit:

A. Production to 400,000 tons during any twelve consecutive months; and

B. Operations to 3000 hours during any twelve consecutive months.

II. New and existing asphalt plants permitted to burn natural gas/LPG, distillate oil, and residual oil in any combination shall limit:

A. Production to 200,000 tons during any twelve consecutive months;

B. Fuel sulfur content to less than or equal to 1.5%;

C. Operation to 3000 hours during any twelve consecutive months; and

D. Fuel oil usage to 678,000 gallons during any twelve consecutive months.

III. New asphalt plants (which commenced construction or modification after June 11, 1973) permitted to burn natural gas/LPG and/or distillate oil only, which are located in the counties of Cherokee, Clayton, Cobb, Coweta, DeKalb, Douglas, Fayette, Forsyth, Fulton, Gwinnett, Henry, Paulding and Rockdale shall limit:

A. Production to 300,000 tons during any twelve consecutive months; and

B. Operations to 3000 hours during any twelve consecutive months.

IV. New and existing asphalt plants permitted to burn natural gas/LPG, distillate oil, and residual oil in any combination, which are located in the counties of Cherokee, Clayton, Cobb, Coweta, DeKalb, Douglas, Fayette, Forsyth, Fulton, Gwinnett, Henry, Paulding and Rockdale shall limit:

A. Production to 125,000 tons during any twelve consecutive months;

B. Fuel sulfur content to less than or equal to 1.5%;

C. Operation to 3000 hours during any twelve consecutive months; and

D. Fuel oil usage to 250,000 gallons during any twelve consecutive months.

6. Cotton Ginning Operations.

(I) Monitoring and Record keeping. A log of the monthly production must be kept. The total production for the previous twelve consecutive months must be included in each month's log. This log shall be kept for five years from the date of last entry. The log shall be available for inspection or submittal to the Division.

(II) Annual Production. Production shall be limited to 120,000 standard bales of cotton during any twelve consecutive months.

7. Coating and/or Gluing Operations.

(i) Notwithstanding any other provision of these Rules, this standard applies to facilities with a potential to emit in amounts equal to or exceeding the Part 70 and Part 63 major source thresholds without existing permit conditions that are federally enforceable or enforceable as a practical matter limiting the source to below Part 70 or Part 63 major source thresholds. This standard applies only to facilities:

(I) Where the actual VOC emissions from coating and/or gluing operations represent at least 90 percent of the plant wide actual VOC emissions; and

(II) Where the actual HAP emissions from coating and/or gluing operations represent at least 90 percent of the plant wide actual HAP emissions or where the actual HAP emissions from non-coating and non-gluing operations are less than 1.0 tons per year.

(ii) This standard establishes federally enforceable conditions limiting the potential to emit for VOC and HAPs. Coating and/or gluing operations shall be deemed to have a Permit by Rule if the conditions in one of the following subparagraphs (I), (II), (III) or (IV) are met. Facilities that have potential emissions of greater than major source thresholds even after this rule is met or are not able to meet the conditions in subparagraphs (I), (II), (III), or (IV) and the remainder of this subparagraph shall obtain a Part 70 Permit. In accordance with the General Requirements in subparagraph (11)(a)2., the owner or operator of a facility wishing to operate under this Permit-by-Rule must also declare which of the four options are going to be met.

(I) The owner or operator of the source shall consume less than 20,000 pounds of any VOC and/or HAP containing materials during any twelve consecutive months. A log of the monthly consumption of VOC and/or HAP containing material must be kept. The total consumption for the previous twelve consecutive months must be included in each month's log. Records for materials (including but not limited to coatings, thinners, and solvents) shall be recorded in pounds. These records shall be maintained and made readily available for inspection for a minimum of five years upon date of entry and shall be submitted to the Division upon request.

(II) The owner or operator of the facility shall use less than 250 total gallons each month, of coating, gluing, cleaning, and washoff materials at the facility. The owner or operator shall demonstrate compliance by maintaining records of the total gallons of coating, gluing, cleaning, and washoff materials used each month. These records shall be maintained and made readily available for inspection for a minimum of five years upon date of entry and shall be submitted to the Division upon request.

(III) The owner or operator of the source shall use less than 3,000 total gallons per rolling 12-month period, of coating, gluing, cleaning, and washoff materials at the facility. A rolling 12-month period includes the previous 12 months of operation. The owner or operator of the facility shall demonstrate compliance by maintaining records of the total gallons of coating, gluing, cleaning, and washoff materials used each month and the total gallons used each rolling 12-month period. These records shall be maintained and made readily available for inspection for a minimum of five years upon date of entry and shall be submitted to the Division upon request.

(IV) The owner or operator of the facility shall use materials containing less than 5 tons of any one HAP per rolling 12-month period, less than 12.5 tons of any combination of HAPs per rolling 12-month period, less than 25 tons of VOC per rolling 12-month period for sources located in Cherokee, Clayton, Cobb, Coweta, DeKalb, Douglas, Fayette, Forsyth, Fulton, Gwinnett, Henry, Paulding, and Rockdale counties, and less than 50 tons of VOC per rolling 12-month period for facilities not located in Cherokee, Clayton, Cobb, Coweta, DeKalb, Douglas, Fayette, Forsyth, Fulton, Gwinnett, Henry, Paulding, and Rockdale counties. The owner or operator shall demonstrate compliance by maintaining records that demonstrate that annual emissions do not exceed these levels, including monthly usage records for each finishing, gluing, cleaning, and washoff material used to include the VOC and individual HAP content of each material; certified product data sheets for these materials; summation of VOC and individual and total HAP usage on a monthly basis; and the total VOC and individual and total HAP usage each rolling 12-month period and any other records necessary to document emissions. These records shall be maintained and made readily available for inspection for a minimum of five years upon date of entry and shall be submitted to the Division upon request.

(iii) The owner or operator that chooses to comply with this Permit by Rule for Coating and/or Operations shall maintain all purchase orders and/or invoices of materials containing VOC's and HAP's for a minimum of five years. These purchase orders and/or invoices must be made available to the Division upon request for use in confirming the general accuracy of the records retained and reports submitted.

(iv) For the purpose of this paragraph, the following definitions apply:

(I) "Certified product data sheet (CPDS)" means documentation furnished by coating or adhesive suppliers or an outside laboratory that provides the Volatile Hazardous Air Pollutant (VHAP), as listed in Table 2 of 40 CFR Part 63, Subpart JJ, content of a finishing material, contact adhesive, or solvent, by percent weight, measured using Method 311 of the Georgia Department of Natural Resources Procedures for Testing and Monitoring Sources of Air Pollutants (PTM), or an equivalent or alternative method [or formulation data if the coating meets the criteria specified in 40 CFR 63.805(a)]; the solids content of a finishing material or contact adhesive by percent weight, determined using data from Method 24 of the Georgia PTM as referenced in this subparagraph, or an alternative or equivalent method [or formulation data if the coating meets the criteria specified in 40 CFR 63.805(a)]; and the density, measured by Method 24 of the Georgia PTM as referenced in this subparagraph or an alternative or equivalent method. Therefore, the reportable VHAP content shall represent the maximum aggregate emissions potential of the finishing material, adhesive, or solvent in concentrations greater than or equal to 1.0 percent by weight or 0.1 percent for VHAP that are carcinogens, must be reported on the CPDS. The purpose of the CPDS is to assist the affected source in demonstrating compliance with the emission limitations presented in subparagraph (11)(b)7.(ii)(IV).

(Note: Because the optimum analytical conditions under Method 311 vary by coating, the coating or adhesive supplier may also choose to include on the CPDS the optimum analytical conditions for analysis of the coating, adhesive, or solvent using Method 311. Such information may include, but not be limited to, separation column, oven temperature, carrier gas, injection port temperature, extraction solvent, and internal standard.)

(II) "Coating" means a protective, decorative, or functional film applied in a thin layer to a surface. Such materials include, but are not limited to, paints, topcoats, varnishes, sealers, stains, washcoats, basecoats, enamels, inks, and temporary protective coatings. Aerosol spray paints used for touch-up and repair are not considered coatings under this subparagraph of the rule.

(III) "Gluing" means those operations in which adhesives are used to join components, for example, to apply a laminate to a wood substrate or foam to fabric.

8. Printing Operations.

(I) Monitoring and Record keeping. A log of the monthly consumption of VOC and/or Hazardous Air Pollutant containing material must be kept. The total consumption for the previous twelve consecutive months must be included in each month's log. Records for materials (including but not limited to inks, thinners, and solvents) shall be recorded in pounds. This log shall be kept for five years from the date of last entry. The log shall be available for inspection or submittal to the Division.

(II) Annual consumption. The consumption of any VOC and/or Hazardous Air Pollutant emitting materials (including but not limited to inks, thinners, and solvents) by the facility shall be limited to 20,000 pounds during any twelve consecutive months.

9. Non-Reactive Mixing Operations.

(I) Monitoring and Record keeping. A monthly log of materials mixed must be kept. The mixing total for the previous twelve consecutive months must be included in each month's log. Records for materials (including but not limited to coatings, thinners, and solvents) shall be recorded in pounds. This log shall be kept for five years from the date of last entry. The log shall be available for inspection or submittal to the Division.

(II) Annual mixing limit. Materials mixed shall be limited to 500 tons during any twelve consecutive months.

(III) Mixing/blending tanks shall be equipped with lids.

(IV) Tank lids must be closed at all times during operation except when charging raw materials, retrieving samples, or discharging finished product.

(V) Mixing tanks must be maintained at a temperature of less than 150°F.

10. Fiberglass Molding and Forming Operations.

(I) Monitoring and Record keeping. A log of the combined monthly usage of polyester resin and gel coat must be kept. The previous twelve consecutive month material usage total must be included in each month's log. Records for the combined weight of polyester resin and gel coat shall be recorded in pounds. This log shall be kept for five years from the date of last entry. The log shall be available for inspection or submittal to the Division.

(II) Material Usage. Annual facility material usage shall be limited to 89,000 pounds during any twelve consecutive months for any combination of hand and spray lay-up operations. Annual facility material usage shall be limited to 120,000 pounds during any twelve consecutive months for spray lay-up operations only. This material input must represent the combined weight of polyester resin and gel coat used during any twelve consecutive months.

11. Peanut/Nut Shelling Operation.

(I) Monitoring and Recordkeeping. A log of the monthly unshelled peanuts/nuts processed must be kept. The total amount of unshelled peanuts/nuts processed for the previous 12 consecutive months must be included in each month's log. This log shall be kept for five years from the date of last entry. The log shall be available for inspection or submittal to the Division.

(II) Annual Process input: Facility process input shall be limited to 130,000 tons of unshelled nuts during any twelve consecutive months.

(III) Annual hours of operation shall not exceed 5000 hours during any twelve consecutive months.

(ii) For the purposes of this standard, the term process, as it applies to peanut/nut shelling facilities, shall include all of the activities associated with the nut shelling process from nut drying, cleaning, shelling, to and including product and waste material handling at the facility.

(12) Generic Permit.

(a) Under penalty of law, the holder of any Air Quality General Generic Permit must adhere to the terms, limitations, and conditions of that permit and subsequent revisions of that permit.

(b) The limitations, controls, and requirements in federally enforceable operating permits are permanent, quantifiable, and otherwise enforceable as a practical matter.

(c) Prior to the issuance of any federally enforceable operating permit, EPA and the public will be notified and given a chance for comment on the draft permit.

(13) Emission Reduction Credits.

(a) Applicability.

This paragraph provides for the creation, banking, and transfer of nitrogen oxides and VOC Emission Reduction Credits in Federally designated ozone non-attainment areas in Georgia and any areas designated by the Director as contributing to the ambient air level of ozone in Federally designated ozone non-attainment areas in Georgia. The following sources are eligible to create and bank nitrogen oxides and VOC Emission Reduction Credits:

1. [reserved]

2. Any stationary source located within the counties of Bartow, Cherokee, Clayton, Cobb, Coweta, DeKalb, Douglas, Fayette, Forsyth, Fulton, Gwinnett, Henry, Newton, Paulding, and Rockdale and which has the potential to emit nitrogen oxides or VOCs in amounts greater than 100 tons-per-year.

3. Electrical Generating Units located at any stationary source within the counties of Banks, Barrow, Butts, Carroll, Chattooga, Clarke, Dawson, Floyd, Gordon, Hall, Haralson, Heard, Jackson, Jasper, Jones, Lamar, Lumpkin, Madison, Meriwether, Monroe, Morgan, Oconee, Pickens, Pike, Polk, Putnam, Spalding, Troup, Upson, and Walton and which has the potential to emit nitrogen oxides in amounts greater than 100 tons-per-year.

(b) Eligibility of Emission Reductions.

1. In order to be approved by the Division as an Emission Reduction Credit, a reduction in emissions must be real, permanent, quantifiable, enforceable, and surplus and shall have occurred after December 31, 1996.

2. To be eligible for consideration as Emission Reduction Credits, emission reductions may be created by any of the following methods:

(i) Installation of control equipment;

(ii) A change in process inputs, formulations, products or product mix, or raw materials;

(iii) A reduction in actual emission rate;

(iv) A reduction in operating hours;

(v) Production curtailment;

(vi) Shutdown of emitting sources or facilities; or

(vii) Any other enforceable method as determined by the Division.

1. For purposes of calculating the amount of emission reduction that can be quantified as an Emission Reduction Credit, the following procedures must be followed:

(i) The source must calculate its average actual annual emissions prior to the emission reduction. Actual emissions prior to the reduction shall be calculated in tons per year. In calculating average actual annual emissions prior to the emission reduction, the source shall use data from the 24-month period immediately preceding the reduction in emissions. The Division may allow the use of a different time period upon determination that such period is more representative of normal source operation.

(ii) The Emission Reduction Credit generated by the emission reduction shall be calculated by subtracting the allowable annual emissions rate following the reduction from the average actual annual emissions prior to the reduction.

(d) Discounting and Revocation of Emission Reduction Credits.

1. Except as provided below, the Director shall not discount or otherwise reduce the value of Emission Reduction Credits banked under this paragraph.

(i) [reserved]

(ii) Discounting Based on Time Banked.

Emission Reduction Credits banked under this paragraph will not expire at any time. However, Emission Reduction Credits will be discounted at a rate of 10 percent of the original Emission Reduction Credit value per year beginning on the 11th anniversary of the date on which the reduction in emissions initially occurred, up to a maximum total discount of 50 percent of the original Emission Reduction Credit value on the 15th anniversary of the date on which the reduction in emissions initially occurred. Annual discounting under this subparagraph (ii) shall not occur if the affected Emission Reduction Credits have already been discounted by 50% or more under the following subparagraph (iii) due to the promulgation of more stringent regulations affecting the source category that created the Emission Reduction Credits.

(iii) Discounting for More Stringent Regulations.

If any State or Federal statute, rule, or regulation decreases an allowable emission rate or otherwise requires a reduction in nitrogen oxides or VOC from a particular source category or categories, any banked nitrogen oxides or VOC Emission Reduction Credits created by that source category or categories shall be reduced to reflect the new more stringent allowable emission limit or required reduction.

(iv) Discounting or Revocation for Cause.

The Director may revoke, suspend, or reduce the value of Emission Reduction Credits for cause, including evidence of noncompliance with permit conditions imposed to make the emission reductions permanent and enforceable; failure to achieve in practice the emission reductions on which the Emission Reduction Credits are based; or misrepresentations made in the Emission Reduction Credit application or any other applications on which the Emission Reduction Credits are based, supporting data entered therein or attached thereto, or any subsequent submittal or supporting data.

2. The owner of a Certificate of Emissions Reduction Credit may submit an application to re-evaluate a Certificate of Emission Reduction Credit to determine whether the amount of credits specified in the Certificate of Emission Reduction Credit has been discounted or revoked in accordance with subparagraph 1., above. Such application shall be submitted on forms and contain information specified by the Division.

(e) Creation and Banking of Emission Reduction Credits.

1. Sources seeking to create and bank Emission Reduction Credits must submit an application on forms supplied by the Division and signed by the applicant. The application shall include, at a minimum, the following information:

(i) The company name, contact person and phone number, and street address of the source seeking the Emission Reduction Credit;

(ii) A description of the type of source, including SIC code, where the proposed emission reduction shall occur;

(iii) A detailed description of the method or methods to be employed by the source to create the emission reduction;

(iv) The date the emission reduction occurred or is to occur;

(v) Quantification of the Emission Reduction Credit, as required under subparagraph (c);

(vi) The proposed method for ensuring the reductions are permanent and enforceable, including any necessary application to amend the source's operating permit or, in the case of a shutdown of process equipment or an entire source, request for permit revocation;

(vii) Whether any portion of the reduction in emissions to be used to create the Emission Reduction Credit has previously been used to avoid New Source Review through a "netting demonstration;" and

(viii) Any other information that may be required to demonstrate that the reduction in emissions is real, permanent, quantifiable, enforceable, and surplus, as defined in subparagraph (b).

2. The Division will determine whether the application is complete and will notify the source seeking the Emission Reduction Credit of its determination. A Certificate of Emission Reduction Credit will be issued to the source upon a determination by the Director that the emission reduction meets the requirements of this paragraph. Upon issuance of the Certificate, the Division will simultaneously take any action required to ensure the reduction is permanent and enforceable, including issuance of a revised permit or revocation of a permit.

3. Certificates of Emission Reduction Credit shall be issued by the Director and shall contain the following information:

(i) The amount of the credit, in tons per year;

(ii) The pollutant reduced (nitrogen oxides or VOC);

(iii) The date the reduction occurred;

(iv) The street address and county of the source where the reduction occurred; and

(v) The date of issuance of the Certificate.

4. The Division shall maintain an Emission Reduction Credit registry that constitutes the official record of all Certificates of Emission Reduction Credit issued and all withdrawals made. The registry shall be available for public review. For each certificate issued, the registry will indicate the amount of the Emission Reduction Credit, the pollutant reduced, the location of the facility generating the Emission Reduction Credit, and the facility contact person.

(f) [reserved]

(g) Transfer of Certificates of Emission Reduction Credit.

1. If the owner of a Certificate of Emission Reduction Credit transfers the Certificate to a new owner, the Division shall issue a Certificate of Emission Reduction Credit to the new owner and shall revoke the certificate held by the current owner of record.

2. If the owner of a Certificate of Emission Reduction Credit transfers part of the Emission Reduction Credits represented by the Certificate to a new owner, the Division shall issue a Certificate of Emission Reduction Credit to the new owner reflecting the transferred amount and shall issue a Certificate of Emission Reduction Credit to the current owner of record reflecting the amount of Emission Reduction Credit remaining after the transfer. The original Certificate of Emission Reduction credit shall be revoked.

(h) Administrative Fees.

1. Any Source or person seeking to create, certify, bank, transfer, or re-evaluate Emission Reduction Credits shall pay fees to the Division in accordance with the following schedule:

(i) $6000 per application to create, certify and bank emission credits in accordance with subparagraph (e) of this paragraph.

(ii) [reserved]

(iii) $3000 per application to transfer a Certificate of Emission Reductions Credit as per subparagraph (g) of this paragraph. If a re-evaluation of the Certificate of Emission Reduction Credit has been completed by the Division in accordance with subparagraph (d)2. of this paragraph within 12 months prior to submission of an application to transfer the Certificate of Emission Reduction Credit, the administrative fee to transfer the Certificate of Emission Reduction Credit shall be reduced by the amount administrative fee paid for re-evaluation. The 12-month period shall be based on the date of written notification of the owner of the results of the re-evaluation by the Division.

(iv) $2500 per application to re-evaluate a Certificate of Emission Reduction Credit as per subparagraph (d)2. of this paragraph.

2. Payment of administrative fees required by this subparagraph shall be submitted along with an application to create, certify, bank, transfer, or re-evaluate Emission Reduction Credits.

(i) Definitions.

For the purposes of this paragraph, the following definitions shall apply:

1. "Electrical Generating Unit" means a fossil fuel fired stationary boiler, combustion turbine, or combined cycle system that serves a generator that produces electricity for sale.

2. "Enforceable" means enforceable by the Division. Methods for ensuring that Emission Reduction Credits are enforceable shall include, but not be limited to, conditions in air quality construction or operating permits issued by the Division.

3. "Netting Demonstration" means the act of calculating a "net emissions increase" under the preconstruction review requirements of Title I, Part D of the Federal Act and the regulations promulgated thereunder.

4. "Permanent" means assured for the life of the corresponding Emission Reduction Credit through an enforceable mechanism such as a permit condition or revocation.

5. "Quantifiable" means that the amount, rate and characteristics of the Emission Reduction Credit can be estimated through a reliable method and are approved by the Division.

6. "Real" means a reduction in actual emissions emitted into the air.

7. "Surplus" means not required by any local, state, or federal law, regulation, order, or requirement and in excess of reductions used by the Division in issuing any other permit or to demonstrate attainment of federal ambient air quality standards or reasonable further progress towards achieving attainment of federal ambient air quality standards. For the purpose of determining the amount of surplus emission reductions, any seasonal emission limitation or standard shall be assumed to apply throughout the year. Emission reductions which have previously been used to avoid New Source Review through a netting demonstration are not considered surplus.

O.C.G.A. § 12-9-1 et seq., as amended.

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Compilation of Rules and Regulations of the State of GeorgiaDepartment 391 - RULES OF GEORGIA DEPARTMENT OF NATURAL RESOURCESChapter 391-3 - ENVIRONMENTAL PROTECTIONSubject 391-3-1 - AIR QUALITY CONTROLRule 391-3-1-.03 - Permits. Amended

Compilation of Rules and Regulations of the State of Georgia
Department 391 - RULES OF GEORGIA DEPARTMENT OF NATURAL RESOURCES
Chapter 391-3 - ENVIRONMENTAL PROTECTION
Subject 391-3-1 - AIR QUALITY CONTROL
Rule 391-3-1-.03 - Permits. Amended