(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.
(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.
(c)
Storage Tanks.
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.
|
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.
(c)
For the purpose of this
section, the following definitions shall apply:
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 after October 1 of the calendar year in which the fee was due
or October 1, 2010, which 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
Part 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
Part 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 Part
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.
(c)
Permit Applications
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 Part 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 Part 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, Part 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 Part 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 Part 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 Part
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) 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.
Concrete mixing 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 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.
(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) 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. Cotton ginning operations
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.
(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) 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. Printing operations 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.
(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)
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. Non-reactive mixing operations shall be deemed to have a
Permit by Rule if the conditions in paragraphs (I) through (V) 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 this rule shall obtain a Part 70 Permit.
(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) 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. Fiberglass
molding operations 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.
(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) 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 threshold. Peanut/nut shelling
facilities shall be deemed to have a Permit by Rule if the conditions in
paragraph (I), (II) and (III) 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 paragraph (I), (II) and (III) shall obtain a
Part 70 Permit.
(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.
(c)
Quantification of Emission
Reduction Credits.
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.