FORM A Page 1 

Grain Elevator Survey

FORM A – General Information

A-1 Facility Name: 

A-2 (a) Facility Street Address: 

(b) Suite or P.O (specify): (c) City: 

(d) State: (e) Zip Code: (f) County: 

A-3 (a) Facility Manager: (b) Phone: 

A-4 (a) Technical contact (for information on this survey): 

(b) Title: (c) Telephone Number: 

(d) Email Address: 

A-5 Number of full-time employees at this location (total for all shifts): 

A-6 Number of seasonal employees at this location (total for all shifts): 

A-7 (a) Parent Company/ Co-Op: 

 (b) Is this a co-op? (check one) Yes No 

(c) Parent Company/ Co-Op Main Office Street Address: 

 

(d) Suite or P.O. (specify): (e) City: 

(f) State: (g) Zip Code: 

A-8 Number of full-time employees within all business units of the Parent Company: 

 (please check one): < 100 101- 249 250- 499 > 500 

A-9 Number of seasonal employees within all business units of the Parent Company 

 (please check one): < 100 101- 249 250- 499 > 500 

FACILITY ID: 

FACID:

(First 4 letters of company name plus first 

4 letters of city name. If not unique 

identifier, add number at end of ID) 

ADMVALD Archer Daniels Midland Valdosta 1841 Clay Rd 1589 Valdosta GA 31601 Lowndes Scott De Jong 229-293-2622 Lisa Shyrigh Environmental Manager 229-293-2639 lisa.shyrigh@adm.com 805

Archer Daniels Midland ■

4666 Faries Parkway

Decatur IL 62526 ■

■
FORM B - Storage Information 

(B-1) FACID: 

FORM B Page 1 

B-2 In what year was this facility first constructed? 

B-3 Total number of storage units: (a) "permanent" storage 

 (b) "temporary" storage 

 (c) "emergency" storage 

[Note: In completing the remainder of the survey, you will be able to group information for similar 

storage units. See B-4 for example.]

B-4 Please provide an overview flow diagram (or block flow diagram) of the grain elevator(s) at 

your facility. Please include permanent (P), temporary (T), and emergency (E) storage units, 

associated receiving (R) and shipping (S) units, and grain dryers (D). 

o Permanent Storage ID: use your current designation or assign a numerical value. If assigning 

an ID, please use “P-1, P-2, etc” format. You may group multiple storage units into one 

permanent storage ID; if not readily apparent, please provide explanations on the back of this 

sheet or indicate in your elevator diagram. 

o Temporary Storage ID: use your current designation or assign a numerical value. If assigning 

a new ID, please use “T-1, T-2” format. 

o Emergency Storage ID: use your current designation or assign a numerical value. If assigning 

a new ID, please use “E-1, E-2” format. 

o Receiving Units ID: use your current designation or assign a numerical value. If assigning an 

ID, please use “R-1, R-2” format. 

o Shipping Units ID: use your current designation or assign a numerical value. If assigning an 

ID, please use “S-1, S-2” format. 

o Grain Dryer ID: use your current designation or assign a numerical value. If assigning an ID, 

please use “D-1, D-2” format. 

o Capacity: please provide capacity in bushels. Do not use a pack factor. 

ADMVALD 1968 9

0

0
FORM B 

Please check one: This page includes CBI □ This page does NOT include CBI [If no box is checked, EPA will assume that the page does NOT contain CBI]

FORM B – Storage Information 

(B-1) FACID: B-5. Please complete the following table for storage information. An example is provided. 

2005 2006 

Storage Type 

(P, T, E) 

Storage 

ID 

Year First 

Used 

Storage 

Capacity 

(Bushels)2

Grain 

Stored1 Through-put (actual bushels)2 Weeks per year utilized Through-put (actual bushels)2 Weeks per year utilized T

(ac

Corn 100,000 2 P - example P-1 1970 300,000 

Wheat 400,000 

50 

300,000 50 

P - example P-2 1985 400,000 Corn 400,000 52 400,000 50 

T - example T-1 2004 450,000 Corn 200,000 22 250,000 20 

1 Use grain designations: corn, wheat, sorghum, rice, rye, oats, barley, soybeans, or specify a different grain. 2 Storage capacity and throughput refer to the aggregated storage capacity and throughput of the units included in th

temporary and emergency storage units, storage capacity and throughput may be estimated based on operator’s knavailable. For permanent storage units, throughput may be estimated based on operator’s knowledge if actual data 

ADMVALD PPP P-1 1968 108000 Soybeans 2074671 26 2173595 26 

P-2 1968 180000 Soybeans 10373356 52 10867978 52 P-3 1971 750000 Soybeans 2074671 39 2173595 39 

P P-4 1971 750000 Soybeans 2074671 39 2173595 39 P P-5 1972 750000 Soybeans 2074671 39 2173595 39 P P-6 1972 750000 Soybeans 2074671 39 2173595 39 P P-7 1974 1000000 Soybeans 2074671 39 2173595 39 P P-8 1974 1000000 Soybeans 2074671 39 2173595 39 

P P-9 1978 1000000 Soybeans 2074671 39 2173595 39 
FORM C 

Please check one: This page includes CBI □ This page does NOT include CBI [If no box is checked, EPA will assume that the page does NOT contain CBI]

FORM C – Receiving and Shipping Information 

(C-1) FACID: C-2 Please complete the following table for receiving and shipping operations at each storage unit (or grou

Storage, Shipping, and Receiving ID’s provided in B-4. An example is provided. 

What is the Maximum Loading Receiving/ Rate? 

Shipping 

ID 

Storage ID 

associated with 

receiving/ 

shipping unit 

How is Grain Received Into or 

Shipped (Loaded) Out of 

Storage?a Value Units 

Are there any add

on controls for th

receiving/ 

shipping unit (Y/N

R-1 P1 Fixed Conveyor Belt 

S-1 P1 Fixed Conveyor Belt 

R-1 T1 Portable Auger 

aLoading and unloading methods include: 

 portable auger  fixed receiving pit with leg to aeration tower  enmass drag conve

 portable inclined belt  fixed conveyor off main complex  pneumatic unloader  gravity fill spout  portable conveyor with trucks  or specify a differen front-end loader  marine leg  fixed drag conveyor  track hoe/clamshell unloader  fixed conveyor belt  continuous barge unloader bQualitative methods include opacity measurements as well as monitoring instruments (e.g. CEMS), and mon

indicate whether the air pollution control device is operating properly. 

ADMVALD R-1 P1-P9 Fixed Receiving Pit with Leg 16000 Bushels/hr Y 

R-2 P1-P9 Fixed Receiving Pit with Leg 16000 Bushels/hr Y R-3 P1-P9 Fixed Receiving Pit with Leg 15000 Bushels/hr Y 
FORM D – “Temporary” Storage 

(D-1) FACID: (D-2) Temporary Storage ID: 

FORM D Page 1 

 (Please copy this sheet and complete a separate sheet for each 

temporary storage at your facility) 

D-3 Please provide a diagram of each storage unit and indicate which pieces of equipment (e.g., 

walls, cover, floor, conveyance system, generator, housing for electrical, etc) remain in place 

year round and which are removed during specific times of the year. If this system is identical 

(or nearly identical) to another temporary system at the same facility, only one diagram is 

needed. Please include all applicable ID numbers on the diagram and explain any differences 

below. 

D-4 What are the materials of construction for this storage unit? 

(a) Walls: 

 (b) Cover/tarp: 

 (c) Floor: 

D-5 (a) Has the cover/tarp ever been replaced? (check one) Y N 

 (b) If yes, month(s)/year(s) cover/tarp was used before being replaced: 

ADMVALD N/A
FORM D – “Temporary” Storage 

(D-1) FACID: (D-2) Temporary Storage ID: 

FORM D Page 2 

D-6 Describe the routine maintenance (including repair and replacement) that is conducted on the 

temporary storage units, including frequency of these activities. If you typically replace a 

component of a unit (e.g., replacement of a tarp/cover in sections, as opposed to entire 

replacement), indicate frequency and typical percent of the entire unit that is replaced. 

Walls: 

 Floors: 

Cover/Tarp: 

Aeration: 

Other equipment associated with storage (e.g., conveying equipment) 

D-7 Describe methods used to reduce particulate emissions during receiving and shipping, 

aeration (or other similar processes), and general storage. Indicate frequencies of any actions. 

(Please complete Form I for any add-on pollution control device).

ADMVALD N/A
FORM E – “Emergency” Storage 

(E-1) FACID: (E-2) Emergency Storage ID: 

FORM E Page 1

E- 3 Explain any approaches taken to minimize particulate emissions from the emergency storage 

pile. Indicate frequencies of any actions. 

ADMVALD N/A
FORM F – Grain Dryers 

(F-1) FACID: 

 

FORM F Page 1 

F- Please complete the following table for grain dryers used at your facility. Use the Dryer, 

Storage, Shipping, and Receiving ID’s provided in B-3. An example is provided. 

How much fuel was used 

Grain Dryer ID 

Storage/Receiving/Ship

ping units associated 

with Dryer Fuel Used1

2005 2006 2007 

D-1 P-1, P-2, R-1, S-1 FO2 10,000 10,000 8,000 

D-2 T-1 FO2 1,000 1,000 1,000 

 

 

 

 

 

1

 Select fuel from list below. If other, please specify. 

FO2 - #2 Fuel Oil (gallons) 

FO6 - #6 Fuel Oil (gallons) 

NG – Natural Gas (MM cubic feet) 

Bio – Biofuel (gallons) 

O – Other, please specify type of fuel and unit of measure 

F- For each column dryer at your facility that does not include a perforated column plate in its 

design, please: (1) describe the design of that dryer, including whether it uses woven wire 

screening; (2) indicate the grain(s) for which the dryer is used; and (3) provide the year of 

original installation. 

ADMVALD 4611 D-1 R-1, R-2, R-3, P2, P3-P9 NG 6276 11388 6184 D-2 R-1, R-2, R-3, P2, P3-P9 NG 5700 4959
FORM G –Permitted Sources 

(G-1) FACID: 

FORM G Page 1 

G-2 Please indicate the total number of each component listed below that you have at this facility 

and the number for which your operating permit specifies an applicable control requirement. 

Component Total Number at Site 

Number for which your permit 

specifies a control requirement? 

Truck receiving station 

Truck shipping station 

Barge and ship receiving station 

Barge and ship shipping station 

Railcar receiving station 

Railcar shipping station 

Grain dryer 

 

 

G-3 Is any grain handling equipment subjected to a control requirement in your permit? 

 (check one) Y N 

As defined in NSPS, Subpart DD, grain handling operations include, as an assemblage of equipment, bucket elevators or 

legs (excluding legs used to unload barges or ships), scale hoppers and surge bins (garners), turn heads, scalpers, 

cleaners, trippers, and the headhouse and other such structures. 

For purposes of Form G, the term “control requirement” refers only to particulate matter (PM) 

emission limits specified for the particular “component” in question and expressed in terms of 

emissions per unit of time or production (e.g., lb of PM/hr; grains/dscf), opacity (e.g., 20%), or a 

design or work practice (e.g., use of enclosure), and not to restrictions on operational parameters 

such as hours, feedstock or throughput. 

ADMVALD 1 1

2 2

2

■
FORM H – Work Practices 

(H-1) FACID: 

FORM H Page 1 

H-2 Describe the design or work practices you follow to reduce emissions (e.g, choke flow, louvered grates, 

mineral oil, etc.). Please describe the frequency the activity is used (e.g, during each loading operation, 

all the time, etc) and the estimated time spent on the activity per usage (e.g, 20 minutes per loading 

event). For “barge and ship receiving station,” please provide copies of any equivalency determinations 

under 40 CFR 60.302(d) and any permit conditions resulting from such determinations. 

Truck receiving station 

Truck shipping station 

Barge and ship receiving station 

Barge and ship shipping station 

Railcar receiving station 

Railcar shipping station 

Grain dryer 

Grain handling operationsa 

a

As defined in NSPS, Subpart DD, grain handling operations include, as an assemblage of equipment, bucket elevators or 

legs (excluding legs used to unload barges or ships), scale hoppers and surge bins (garners), turn heads, scalpers, 

cleaners, trippers, and the headhouse and other such structures. 

ADMVALD

The baghouse runs while the Truck Dump is operating. Differential pressure readings (in. of WC) are recorded three 

times a day (or once per shift) when the baghouse is running. Visible emissions checks are completed and recorded 

once a day while the baghouse is running. 

The baghouse associated with each receiving station operates whenever the receiving station is operational. 

Differential pressure readings (in. of WC) are recorded three times a day (or once per shift) when the baghouse is 

running. Visible emissions checks are completed and recorded once a day while the baghouse is running. 

Visible emissions are checked and recorded once a day while the equipment Baghouse is operated whenever grain handling equipment is operating. Differential pressure readings (in. of WC) are 

recorded three times a day (or once per shift) when the baghouse is running. Visible emissions checks are completed 

and recorded once a day while the baghouse is running; visible emissions checks are also performed on storage bins 

while ventilation fans are operating. 
FORM I – Add-on Pollution Control Device 

(I-1) FACID: FORM I If data are not available or unknown, please enter ND I-2 Please complete the following table for any air pollution control devices at your facility. Please provide I

diagram. For each unit, please provide the most recent performance data you have. An example is pro

Air Pollution Control 

Device ID 

Type of Control [e.g., fabric 

filter/baghouse; cyclone; 

other (specify)] 

Points controlled 

by this control 

(Use ID’s from 

Forms B, C, and 

D) 

Type of Data Available [e.g., 

performance test, manufacturer’s 

specs or guarantee, engineering 

calculations, other (specify)] 

Desig

Efficien

APCD-1 example Cyclone R-1, R-2 Manufacturer’s specifications 40% APCD-2 example Fabric Filter S-1 Manufacturer’s specifications 90% Make additional copies, as necessary 

ADMVALD APCD-1 Fabric Filter R-1 Manufacturer's Specifications 99.96% 

APCD-2 Fabric Filter R-2 Manufacturer's Specifications 99.96% APCD-3 Fabric Filter R-3 Manufacturer's Specifications 99.96% 
FORM I – Add-on Pollution Control Device 

(I-1) FACID: 

FORM I  Page 2 

I-3. Provide a copy of the most recent performance test for each air pollution control device 

 If no performance tests are available, complete questions I-4 through I-7. 

I-4. Please complete for each control device listed in I-2. 

Inlet Flow Pressure Drop Inlet Temperature 

APCD ID Max Units Min Max Units Min Max o

C/oF 

 

I-5 For each cyclone, please complete the following table 

APCD ID Particle Density Units 

 

ADMVALD APCD-1 26500 acfm .1 5.5 in WC ambient ambient F

APCD-2 26500 acfm .1 5.5 in WC ambient ambient F

APCD-3 26500 acfm .1 5.5 in WC ambient ambient F
FORM I – Add-on Pollution Control Device 

(I-1) FACID: 

FORM I  Page 3 

I-6. For each fabric filter/baghouse, please provide the following information. 

 

APCD ID Number of bags Total Surface Area Units 

 

I-7 For each control not listed in I-5 and I-6, please describe the technology and the parameters that 

are relevant for operation of the control 

ADMVALD APCD-1 159 2385 sq ft APCD-2 159 2385 sq ft APCD-3 460 5750 sq ft
R1

R2R3

P2

P1

P3-P9

R1 feeds P1, P2, P3, P4, P5, P6, P7, P8, P9R2 feeds P1, P2, P3, P4, P5, P6, P7, P8, P9R3 feeds P1, P2, P3, P4, P5, P6, P7, P8, P9R1, R2, P2, P3, P4, P5, P6, P7, P8, and P9 are the receiving and storage units associated with the dryer

P3 P4

P9 P8 P7

P5 P6

APCD1

APCD2

APCD3
Part 70 Operating Permit

Permit Number: 2075-185-0051-V-02-0 Effective Date: February 23, 2009

Facility Name: ADM Valdosta

Facility Address: 1841 Clay Road

Valdosta, Georgia 31601, Lowndes County

Mailing Address: P.O. Box 1470

Decatur, Illinois 62525

Parent/Holding 

Company:

Archer Daniels Midland Company

Facility AIRS Number: 04-13-185-00051

In accordance with the provisions of the Georgia Air Quality Act, O.C.G.A. Section 12-9-1, et seq and the 

Georgia Rules for Air Quality Control, Chapter 391-3-1, adopted pursuant to and in effect under the Act, 

the Permittee described above is issued a Part 70 Permit for:

The operation of a Soybean Oil mill, a Cottonseed Oil Mill and a Vegetable Oil Refinery.

This Permit is conditioned upon compliance with all provisions of The Georgia Air Quality Act, O.C.G.A. 

Section 12-9-1, et seq, the Rules, Chapter 391-3-1, adopted and in effect under that Act, or any other 

condition of this Permit. Unless modified or revoked, this Permit expires five years after the effective 

date indicated above.

This Permit may be subject to revocation, suspension, modification or amendment by the Director for 

cause including evidence of noncompliance with any of the above, for any misrepresentation made in 

Title V Application No. TV-17537 signed on July 12, 2007, Application No. SAWO 17922 signed on 

January 14, 2008, and Application No. SAWO 18093 signed on April 3, 2008, any other applications 

upon which this Permit is based, supporting data entered therein or attached thereto, or any subsequent 

submittal of supporting data, or for any alterations affecting the emissions from this source.

This Permit is further subject to and conditioned upon the terms, conditions, limitations, standards, or 

schedules contained in or specified on the attached 61 pages.

[Signed] 

Director

Environmental Protection Division
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

i

Table of Contents

PART 1.0 FACILITY DESCRIPTION .............................................................................................................1

1.1 Site Determination ...............................................................................................................................1

1.2 Previous and/or Other Names..............................................................................................................1

1.3 Overall Facility Process Description....................................................................................................1

PART 2.0 REQUIREMENTS PERTAINING TO THE ENTIRE FACILITY .............................................4

2.1 Facility Wide Emission Caps and Operating Limits............................................................................4

2.2 Facility Wide Federal Rule Standards .................................................................................................4

2.3 Facility Wide SIP Rule Standards........................................................................................................5

2.4 Facility Wide Standards Not Covered by a Federal or SIP Rule and Not Instituted as an Emission 

Cap or Operating Limit........................................................................................................................5

PART 3.0 REQUIREMENTS FOR EMISSION UNITS .................................................................................6

3.1 Emission Units.....................................................................................................................................6

3.2 Equipment Emission Caps and Operating Limits................................................................................9

3.3 Equipment Federal Rule Standards....................................................................................................13

3.4 Equipment SIP Rule Standards..........................................................................................................15

3.5 Equipment Standards Not Covered by a Federal or SIP Rule and Not Instituted as an Emission Cap 

or Operating Limit .............................................................................................................................17

PART 4.0 REQUIREMENTS FOR TESTING...............................................................................................18

4.1 General Testing Requirements...........................................................................................................18

4.2 Specific Testing Requirements ..........................................................................................................20

PART 5.0 REQUIREMENTS FOR MONITORING (Related to Data Collection)....................................22

5.1 General Monitoring Requirements.....................................................................................................22

5.2 Specific Monitoring Requirements....................................................................................................22

PART 6.0 RECORD KEEPING AND REPORTING REQUIREMENTS ..................................................28

6.1 General Record Keeping and Reporting Requirements.....................................................................28

6.2 Specific Record Keeping and Reporting Requirements ....................................................................32

PART 7.0 OTHER SPECIFIC REQUIREMENTS........................................................................................43

7.1 Operational Flexibility .......................................................................................................................43

7.2 Off-Permit Changes ...........................................................................................................................43

7.3 Alternative Requirements ..................................................................................................................44

7.4 Insignificant Activities.......................................................................................................................44

7.5 Temporary Sources............................................................................................................................44

7.6 Short-term Activities..........................................................................................................................44

7.7 Compliance Schedule/Progress Reports ............................................................................................44

7.8 Emissions Trading..............................................................................................................................44

7.9 Acid Rain Requirements....................................................................................................................44

7.10 Prevention of Accidental Releases (Section 112(r) of the 1990 CAAA) ..........................................44

7.11 Stratospheric Ozone Protection Requirements (Title VI of the CAAA of 1990)..............................46

7.12 Revocation of Existing Permits and Amendments ............................................................................47

7.13 Pollution Prevention...........................................................................................................................47

7.14 Specific Conditions............................................................................................................................47

PART 8.0 GENERAL PROVISIONS..............................................................................................................48

8.1 Terms and References........................................................................................................................48

8.2 EPA Authorities.................................................................................................................................48

8.3 Duty to Comply..................................................................................................................................48

8.4 Fee Assessment and Payment ............................................................................................................49
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

ii

8.5 Permit Renewal and Expiration .........................................................................................................49

8.6 Transfer of Ownership or Operation..................................................................................................49

8.7 Property Rights ..................................................................................................................................49

8.8 Submissions .......................................................................................................................................50

8.9 Duty to Provide Information..............................................................................................................50

8.10 Modifications.....................................................................................................................................51

8.11 Permit Revision, Revocation, Reopening and Termination...............................................................51

8.12 Severability ........................................................................................................................................52

8.13 Excess Emissions Due to an Emergency ...........................................................................................52

8.14 Compliance Requirements.................................................................................................................53

8.15 Circumvention....................................................................................................................................55

8.16 Permit Shield......................................................................................................................................55

8.17 Operational Practices .........................................................................................................................56

8.18 Visible Emissions...............................................................................................................................56

8.19 Fuel-burning Equipment ....................................................................................................................56

8.20 Sulfur Dioxide....................................................................................................................................57

8.21 Particulate Emissions.........................................................................................................................57

8.22 Fugitive Dust......................................................................................................................................57

8.23 Solvent Metal Cleaning......................................................................................................................58

8.24 Incinerators.........................................................................................................................................59

8.25 Volatile Organic Liquid Handling and Storage .................................................................................59

8.26 Use of Any Credible Evidence or Information ..................................................................................60

8.27 Diesel-Fired Internal Combustion Engines........................................................................................60

Attachments..............................................................................................................................................................61

A. List of Standard Abbreviations and List of Permit Specific Abbreviations

B. Insignificant Activities Checklist, Insignificant Activities Based on Emission Levels and Generic 

Emission Groups

C. List of References
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Page 1 of 61 

PART 1.0 FACILITY DESCRIPTION

1.1 Site Determination

ADM’s Valdosta facility consists of a Cottonseed oil extraction plant, a Soybean oil extraction plant, 

and a Vegetable oil refinery. The facility is located at 1841 Clay Road in Valdosta. There are no 

other sources or facilities under the Permittee’s common control that are adjacent or contiguous to the 

subject facility.

1.2 Previous and/or Other Names

The facility was constructed by Gold Kist, which owned and operated the facility until 1987, when it 

was sold to the Archer Daniel Midlands (ADM) Company. Since 1987, the facility has been owned 

and operated by ADM.

Prior to 1996 the cottonseed oil extraction plant had a separate permit under the name of Southern 

Cotton Oil Company, which was a division within the parent ADM Corporation. In April 1996 the 

operation of the cottonseed oil extraction plant was brought under ADM’s soybean oil extraction 

plant permit. The original permit issued to Southern Cotton Oil Company was revoked at that time.

1.3 Overall Facility Process Description

The raw materials consist of soybeans and cottonseed, which are brought in by rail cars or trucks. 

The soybeans are dumped into a below ground storage area and then conveyed into storage bins. 

Prior to storage, the soybeans are cleaned of unwanted debris. The trash is sent to a grinder. Fabric 

filters control PM emissions from soybean handling operations. The moisture of the raw materials is 

measured and the beans are dried in one of two grain dryers, if the moisture content exceeds 13%. 

The grain dryers are mostly used during the months of September through December.

Soybeans are conveyed to a fluidized bed dryer, which dries the bean hulls to enable separation from 

the rest of the bean. The dried beans are sent to a cracking mill to crack the beans. The cracked 

beans are then sent to the dehulling system, which separates the hulls from the bean meat. Fabric 

filters and cyclones control PM emission from these operations. The hulls are ground up and sold to 

be used as filler in animal feed. The loose hulls are pneumatically conveyed to storage and a 

baghouse separates the hulls from the air stream. A pelletizer can be used to form pellets from the 

soybean hulls.

The dried and dehulled beans are passed through smooth rollers to turn the beans into flakes. The 

flakes are introduced into a shallow bed, percolation type, continuous, counter-current extractor, 

which is a closed system of hexane and miscella (a mixture of hexane and vegetable oil). The hexane 

is used to extract the oil from the bean flakes. After the extraction, the material consists of wet flakes 

and miscella. The miscella drains to the lower compartments. After the miscella is completely 

drained, the flakes are conveyed in a vapor tight conveyor to the soybean desolventizer-toaster-dryercooler (DTDC).
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Page 2 of 61 

In the DTDC, the flakes are introduced into the upper tray, which is heated by indirect steam to 

vaporize the remaining hexane. The flakes are then transferred to the middle tray for toasting, to 

increase the meal quality. The dryer-cooler section of the DTDC consists of five decks: the top four 

for drying and the lower deck for cooling. In the dryer decks, hot air is passed through the meal to 

reduce the moisture in the meal. In the cooling deck, ambient air passes through the meal to cool it. 

The particulate matter emissions from each deck are controlled by a cyclone. After the DTDC 

process, the meal is sized and ground. The meal is next transferred to storage and loadout areas.

The miscella from the extractor passes through hydrocyclones to remove suspended solids and is then 

separated into oil and solvent by two-stage evaporation. After evaporation, oil flows to a stripper, 

which removes the remaining traces of solvent by heating with low-pressure steam. The 

solvent/water vapors from the evaporators are condensed and fed to the solvent/water separator, 

which is a continuous decanting system. The vapors are sent to a mineral oil absorption system.

Refining consists of the following processes: water wash, vacuum drying, bleaching and deodorizing. 

The refining process removes the undesirable fatty acids, phosphatides and insoluble matter, by 

reacting the oil with a caustic solution and then separating the solution using a self-cleaning 

centrifuge. The water wash process neutralizes the residual amounts of caustic left in the oil from 

refining to prevent oil loss. The vacuum drying process reduces the moisture content of the oil to 

prevent water hydrolysis of the oil. The bleaching process removes trace amounts of undesirable 

compounds, which could affect the stability of the oil. This is achieved by adsorbing these 

compounds onto acid activated clay and then filtering. The deodorizing process improves the taste, 

odor, color, and stability of the oil. This is achieved by steam stripping out various flavor and odor 

compounds and fatty acids.

The facility has seven (7) boilers for generating process steam. The Wellons boiler (Source Code: 

630) and two 52 MMBtu/hr boilers (Source Codes: B115A and B115B) are wood fired and can also 

be fired with oilseed hulls, in loose or pelletized form, and other fuels. The Cleaver-Brooks boiler 

(Source Code: 640), the CE boiler (Source Code: 650) and the two GTS boilers (Source Codes: 701 

and 705) fire natural gas and can burn distillate fuel oil and vegetable oil as backup fuel. There is a 

natural gas fired hydrogen generator in the refinery and two natural gas fired grain dryers used for 

drying soybeans. Note that three dryers are included in the Title V application; the oldest dryer has 

been taken out of service.

Cottonseed hulls are either sent to bulk hull storage for loading or they are forced through dies 

creating pellets. The pellets are then dried and cooled in a pellet cooler (Source Code: C420) which 

is controlled by a cyclone (Source Code: C421). ADM conveys pelleted hulls to the White Seed 

Rail/Hull Rail and Truck Loadout (Source Code: C460) for shipping.

The cottonseed processing plant is similar to the soybean plant. In it seed is received, cleaned, 

delinted, hulled, flaked, conditioned, and expanded in preparation for the extraction of the oil. 

Vegetable oil is extracted from the expanded flakes, or collets, using hexane as the extracting agent. 

The oil is then separated from the hexane. Hexane is also removed from the cottonseed meal, and the 

meal is further processed prior to shipment. The hexane is recovered and used in the extractor. The 

refining process removes impurities contained in the oil.
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Page 3 of 61 

Cottonseed collets that have been preconditioned (i.e., flaked, heated, and expanded) are conveyed to 

a shallow bed, percolation type, continuous, counter-current extractor, which is a closed system of 

hexane and miscella. The hexane is used to extract the oil from the collets. After the extraction, the 

material consists of spent collets and miscella. The spent collets are conveyed to the cottonseed 

DTDC for further processing and the miscella is separated in the distillation system.

In the DTDC, the spent collets are introduced into the upper tray, which is heated by indirect steam, 

to vaporize the remaining hexane. The collets are then transferred to the middle tray for toasting, to 

increase the meal quality. The dryer-cooler section of the DTDC consists of three decks: the top two 

for drying and the lower deck for cooling. In the dryer decks, hot air is passed through the meal to 

reduce the moisture in the meal. In the cooling deck, ambient air passes through the meal to cool it. 

The particulate matter emissions from each deck are controlled by a cyclone. After the DTDC 

process, the meal is sized and ground. The meal is next transferred to storage and loadout areas.

The miscella from the extractor is heated in the rising film evaporator to boil off hexane. Caustic is 

added to the oil-rich miscella, combining with impurities in the oil and forming a mixture called soap 

stock that is removed from the oil with centrifuges. The soap stock is combined with meal before 

being sent to the DTDC. The oil-rich miscella passes through several stage of evaporation to remove 

all hexane. After evaporation, oil flows to a stripper, which removes the remaining traces of solvent 

by heating with low-pressure steam. The solvent/water vapors from the evaporators are condensed 

and fed to the solvent/water separator, which is a continuous decanting system. The vapors are sent 

to a mineral oil absorption system.

Refining consists of the same processes used in refining soybean oil.

Note: The delinting process consists of first, second, and third-cut delinters and associated lint 

beaters. The first-cut delinters consist of several saws that act to remove the longest lint from the 

white seed, since some seed parts and foreign material remain with the lint, the first-cut lint beaters 

are used to clean the lint. These machines beat, stir, and convey the lint over perforated metal, which 

is sized to remove the various sizes of foreign material. The clean lint is then sent to the lint press 

and baled. The material removed from the lint by the beaters consists of hulls and meats, which are 

conveyed to the seed hulling operation. The partially delinted seed is then processed through the 

second-cut and the third-cut delinters which are similar in appearance and operation to the first-cut 

delinters.
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Page 4 of 61 

PART 2.0 REQUIREMENTS PERTAINING TO THE ENTIRE FACILITY

2.1 Facility Wide Emission Caps and Operating Limits

2.1.1 The Permittee shall not process more than 1,095,000 tons of soybeans per any twelve 

consecutive months, through the facility.

[PSD, 40 CFR 52.21(j)]

2.1.2 The Permittee shall not process more than 1095 million pounds of crude vegetable oil per 

any twelve consecutive months, through the vegetable oil refinery.

[PSD, 40 CFR 52.21(j)]

2.2 Facility Wide Federal Rule Standards

2.2.1 The ADM Valdosta facility is subject to 40 CFR Part 63, Subpart GGGG “National 

Emission Standards for Hazardous Air Pollutants: Solvent Extraction for Vegetable Oil 

Production”.

[40 CFR 63.2832, 40 CFR 63.2833, and 40 CFR 63.2834]

2.2.2 The ADM Valdosta facility shall comply with all applicable provisions of 40 CFR Part 63, 

Subpart A, “General Provisions”.

[40 CFR 63 Subpart A]

2.2.3 The allowable HAPS loss for the cottonseed and the soybean oil extraction shall be 

determined using solvent loss factors in Table 1 and equation 2 of 40 CFR 63.2840.

[40 CFR 63.2840]

2.2.4 The Permittee shall develop, implement and comply with a written site specific plan (the 

"Plan"), and revisions thereto, that specifies the detailed procedures that will be followed 

for monitoring and recording data necessary for demonstrating compliance with all 

applicable provisions of the Vegetable Oil MACT found in 40 CFR Part 63, Subpart 

GGGG and Subpart A. The Plan shall include the items in paragraphs (a)(1) through (a)(7) 

of 40 CFR63.2851. The Permittee shall keep the Plan on site and readily available as long 

as the source is operational. If any changes are made to the Plan for demonstrating 

compliance, then the Permittee must keep all previous versions of the Plan and make them 

readily available for inspection for at least five years after each revision. The Division may 

require reasonable revisions to the Plan if the procedures lack detail, are inconsistent or do 

not accurately determine solvent loss, HAP content of the solvent, or the tons of oilseed 

processed. The current Plan dated June 2004 is hereby incorporated by reference.

[40 CFR 63.2851]

2.2.5 The Permittee shall develop a written startup shutdown and malfunction (SSM) plan in 

accordance with 40 CFR 63.2852. The current SSM plan is incorporated in this Title V 

permit by reference.

[40 CFR 63.2852]
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Page 5 of 61 

2.3 Facility Wide SIP Rule Standards

None applicable.

2.4 Facility Wide Standards Not Covered by a Federal or SIP Rule and Not Instituted as an 

Emission Cap or Operating Limit

None applicable.
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Page 6 of 61 

PART 3.0 REQUIREMENTS FOR EMISSION UNITS

Note: Except where an applicable requirement specifically states otherwise, the averaging times of any of 

the Emissions Limitations or Standards included in this permit are tied to or based on the run 

time(s) specified for the applicable reference test method(s) or procedures required for 

demonstrating compliance.

3.1 Emission Units

Emission Units Specific Limitations/Requirements Air Pollution Control Devices

ID No. Description Applicable 

Requirements/Standards

Corresponding 

Permit Conditions ID No. Description

001 Rail Pit No. 1 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.4.1, 3.4.2 001 Baghouse

002 Rail Pit No. 2 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.4.1, 3.4.2 002 Baghouse

003 Truck Dump 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.10, 3.4.1, 3.4.2 044 Baghouse

004 Bean Cleaning and 

Distribution

391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.10, 3.4.1, 3.4.2 044 Baghouse

005 Bean Storage 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.4.1, 3.4.2 None

009 Grain Dryer (Column Dryer) 

No. 3 

40 CFR 60, Subpart A

40 CFR 60, Subpart DD

391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

391-3-1-.02(2)(g)

3.2.1, 3.2.3, 3.2.6, 

3.2.7, 3.2.10, 3.3.4, 

3.4.1, 3.4.2, 3.4.6

None

010 Grain Dryer (Column Dryer) 

No. 2

391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

391-3-1-.02(2)(g)

3.2.1, 3.2.3, 3.2.6, 

3.2.7, 3.2.10, 3.4.1, 

3.4.2, 3.4.6

None

120 Fluid Bed Dryer 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.10, 3.4.1, 3.4.2 121, 

122

Cyclone,

Baghouse

130 Cracking Rolls 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.10, 3.4.1, 3.4.2 141 Baghouse

140 Fluid Bed Dehulling 

Dryer/Conditioner

391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.10, 3.4.1, 3.4.2 121 (via 

120),

122

Cyclone,

Baghouse

150 Flaking Rolls 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.10, 3.4.1, 3.4.2 151 Cyclone

170 Secondary Dehulling 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.10, 3.4.1, 3.4.2 141 Baghouse

180 Hull Grinders 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.10, 3.4.1, 3.4.2 182 Baghouse

190 Soybean Hull Pelletizing 

(Mill, Cooler)

391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.5, 3.4.1, 3.4.2 191 Cyclone

210 Cottonseed Oil Extractor 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

40 CFR 63, Subpart A

40 CFR 63, Subpart GGGG

PSD

2.2.3, 3.3.1, 3.4.1, 

3.4.3

221 (via 

220)

Mineral Oil 

Scrubber and 

Condenser

220 Cottonseed Solvent Recovery 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

40 CFR 63, Subpart A

40 CFR 63, Subpart GGGG

PSD

2.2.3, 3.3.1, 3.4.1, 

3.4.3

221 Mineral Oil 

Scrubber
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Page 7 of 61 

Emission Units Specific Limitations/Requirements Air Pollution Control Devices

ID No. Description Applicable 

Requirements/Standards

Corresponding 

Permit Conditions ID No. Description

230 Cottonseed Desolventizer, 

Toaster, Dryer, Cooler

391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

40 CFR 63, Subpart A

40 CFR 63, Subpart GGGG

PSD

2.2.3, 3.2.4, 3.3.1, 

3.4.1, 3.4.3

C226, 

C236, 221

2 Cyclones,

Mineral Oil 

Scrubber, and 

Condenser 

330 Meal Grinders 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.10, 3.4.1, 3.4.2 331 Baghouse

340 Clay Storage Bin 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.2, 3.2.10, 3.4.1, 

3.4.2

341 Baghouse

410 Product Storage 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.10, 3.4.1, 3.4.2 311 Baghouse

420 Product Blend 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.10, 3.4.1, 3.4.2 311 Baghouse

430 Rail Loadout 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.10, 3.4.1, 3.4.2 311 Baghouse

440 Truck Loadout 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.10, 3.4.1, 3.4.2 311 Baghouse

630 Wellons Boiler 391-3-1-.02(2)(d)

391-3-1-.02(2)(g)

3.2.3, 3.2.6, 3.2.7, 

3.2.8, 3.2.10, 3.3.3, 

3.4.4, 3.4.6

631, 632, 

633

Multiclone,

2 Baghouses

640 Cleaver Brooks Boiler 391-3-1-.02(2)(d)

391-3-1-.02(2)(g)

3.2.3, 3.2.6, 3.2.7, 

3.2.9, 3.2.10, 3.3.2, 

3.3.4, 3.4.4, 3.4.6

None NA

650 CE Boiler 391-3-1-.02(2)(d)

391-3-1-.02(2)(g)

3.2.3, 3.2.6, 3.2.7, 

3.2.9, 3.2.10, 3.3.2, 

3.3.4, 3.4.4, 3.4.6

None NA

701 GTS Boiler No. 1 391-3-1-.02(2)(d)

391-3-1-.02(2)(g)

40 CFR 60, Subpart A

40 CFR 60, Subpart Dc

3.2.3, 3.3.2, 3.3.3, 

3.3.5, 3.4.4, 3.4.6

None NA

705 GTS Boiler No. 2 391-3-1-.02(2)(d)

391-3-1-.02(2)(g)

40 CFR 60, Subpart A

40 CFR 60, Subpart Dc

3.2.3, 3.3.2, 3.3.3, 

3.3.5, 3.4.4, 3.4.6

None NA

710 Bleaching Clay Receiving 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.2, 3.2.10, 3.4.1, 

3.4.2, 3.4.5

711 Baghouse

C010 Seed Receiving 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.4, 3.4.1, 3.4.3 C011 Rotary Drum Filter

C030 Seedhouse No. 1 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.4, 3.4.1, 3.4.3 None

C040 Seedhouse No. 2 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.4, 3.4.1, 3.4.3 None

C050 Seedhouse No. 3 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.4, 3.4.1, 3.4.3 None

C060 Seedhouse No. 4 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.4, 3.4.1, 3.4.3 None

C070 Seedhouse No. 6 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.4, 3.4.1, 3.4.3 None

C080 Seedhouse No. 7 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.4, 3.4.1, 3.4.3 None

C100 Seed Cleaning 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.4, 3.4.1, 3.4.3 C101 Rotary Drum Filter

C110 Seed Delinting 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.4, 3.4.1, 3.4.3 C111, 

C116, 

C121, 

C126, 

C131, C136

Rotary Drum 

Filters

C140 Seed Hulling 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.4, 3.4.1, 3.4.3 C141 Rotary Drum Filter
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Page 8 of 61 

Emission Units Specific Limitations/Requirements Air Pollution Control Devices

ID No. Description Applicable 

Requirements/Standards

Corresponding 

Permit Conditions ID No. Description

C150 Lint Press 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.4, 3.4.1, 3.4.3 C151 Rotary Drum Filter

C160 Flaking 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.4, 3.4.1, 3.4.3 C161** Baghouse

C170 Conditioning 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.4, 3.4.1, 3.4.3 C171 Cyclone

C180 Expanding 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.4, 3.4.1, 3.4.3 None None

C190 Collet Cooler 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.4, 3.4.1, 3.4.3 C191 Baghouse

C400 Bulk Hull Storage 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.4, 3.4.1, 3.4.3 C401 Baghouse

C410 Pelleted Hull Storage 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.4, 3.4.1, 3.4.3 C411 Baghouse

C420 Pellet Cooling 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.4.1, 3.4.3, 6.1.7 C421 Cyclone

C430 Cottonseed Meal Grinding 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.4, 3.4.1, 3.4.3 C431 Baghouse

C435 Clay Tank 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.4, 3.4.1, 3.4.3 C431 Baghouse

C440 Meal Storage and Loadout 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.4, 3.4.1, 3.4.3 C441 Baghouse

C450 White Seed Truck Loadout 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.4, 3.4.1, 3.4.3 C451 Rotary Drum Filter

C460 White Seed Rail/Hull Rail and 

Truck Loadout

391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

3.2.4, 3.4.1, 3.4.3, 

6.1.7, 6.2.9

C461 Rotary Drum Filter

12 Soy Hexane Process Tank 

(20,000gallons)

40 CFR 63, Subpart A

40 CFR 63, Subpart GGGG

2.2.3 None NA

13 Soy Hexane Process Tank 

(20,000gallons)

40 CFR 63, Subpart A

40 CFR 63, Subpart GGGG

2.2.3 None NA

14 Cottonseed Hexane Process 

Tank (30,000 gallons)

40 CFR 63, Subpart A

40 CFR 63, Subpart GGGG

2.2.3 None NA

720 Hot Well Tank 391-3-1-.02(2)(b)

PSD

3.3.1, 3.4.1 None

S200 Soybean Oil Extractor 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

40 CFR 63, Subpart A

40 CFR 63, Subpart GGGG

PSD

2.2.3, 3.3.1, 3.4.1, 

3.4.2, 3.5.1, 

S241 (via 

240)

Mineral Oil 

Scrubber and 

Condenser

S240 Soybean Solvent Recovery 391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

40 CFR 63, Subpart A

40 CFR 63, Subpart GGGG

PSD

2.2.3, 3.3.1, 3.4.1, 

3.4.2, 3.5.1

S241 Mineral Oil 

Scrubber

S250 Soybean Desolventizer, 

Toaster, Dryer, Cooler

391-3-1-.02(2)(e)

391-3-1-.02(2)(b)

40 CFR 63, Subpart A

40 CFR 63, Subpart GGGG

PSD

2.2.3, 3.3.1, 3.4.1, 

3.4.2, 3.5.1

S251, S256, 

S261, S266, 

S271,

S241

5 Cyclones,

Mineral Oil 

Scrubber, and 

Condenser

CT01 Miscella Aboveground 

Storage Tank

40 CFR 63, Subpart A

40 CFR 63, Subpart GGGG

PSD

2.2.3, 3.3.1 221 Scrubber

CT02 Miscella Aboveground 

Storage Tank

40 CFR 63, Subpart A

40 CFR 63, Subpart GGGG

PSD

2.2.3, 3.3.1 221 Scrubber

HP1 Hydrogen Gas Generator 391-3-1-.02(2)(d)

391-3-1-.02(2)(g)

3.2.3, 3.2.6, 3.2.7, 

3.4.4, 3.4.6

None NA
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Page 9 of 61 

Emission Units Specific Limitations/Requirements Air Pollution Control Devices

ID No. Description Applicable 

Requirements/Standards

Corresponding 

Permit Conditions ID No. Description

B115A 52 MMBTU/ hr Wood-Fired 

Boiler

40 CFR 52.21

40 CFR 60, Subpart A

40 CFR 60, Subpart Dc

391-3-1-.02(2)(d) 

391-3-1-.02(2)(g)

3.2.11, 3.2.12, 3.2.13, 

3.2.14, 3.2.15, 3.2.16, 

3.3.3, 3.3.5, 3.3.6, 

3.3.7, 3.3.8, 3.3.9, 

3.3.10, 3.3.11, 3.3.12, 

4.1.3, 4.2.8, 4.2.9, 

4.2.10, 4.2.11, 5.1.1, 

5.2.1, 5.2.2, 6.1.7, 

6.2.16, 6.2.17, 6.2.18, 

6.2.19, 6.2.20, 6.2.21, 

6.2.22, 6.2.23, 6.2.24, 

6.2.25, 6.2.26, 6.2.27, 

6.2.28, 6.2.29, 6.2.30, 

7.14.1

ESP-661 Electrostatic 

Precipitator

B115B 52 MMBTU/ hr Wood-Fired 

Boiler

40 CFR 52.21

40 CFR 60, Subpart A

40 CFR 60, Subpart Dc

391-3-1-.02(2)(d) 

391-3-1-.02(2)(g)

3.2.11, 3.2.12, 3.2.13, 

3.2.14, 3.2.15, 3.2.16, 

3.3.3, 3.3.5, 3.3.6, 

3.3.7, 3.3.8, 3.3.9, 

3.3.10, 3.3.11, 3.3.12, 

4.1.3, 4.2.8, 4.2.9, 

4.2.10, 4.2.11, 5.1.1, 

5.2.1, 5.2.2, 6.1.7, 

6.2.16, 6.2.17, 6.2.18, 

6.2.19, 6.2.20, 6.2.21, 

6.2.22, 6.2.23, 6.2.24, 

6.2.25, 6.2.26, 6.2.27, 

6.2.28, 6.2.29, 6.2.30, 

7.14.1

ESP-661 Electrostatic 

Precipitator

* Generally applicable requirements contained in this permit may also apply to emission units listed above.

** Baghouse C161 is used when portions of the process are open. During normal operation the baghouse will not be in operation but the 

system is completely closed, preventing release of emissions.

3.2 Equipment Emission Caps and Operating Limits

3.2.1 The Permittee shall not process more than 549,200 tons of soybeans through the grain 

dryers (Source Codes: 009 and 010) per any twelve consecutive months.

[PSD avoidance and 391-3-1-.03(2)(c)]

3.2.2 The total clay loaded in the clay storage silo (Source Code: 340) and in the refinery 

bleaching clay storage silo (Source Code: 710) shall not exceed 10,000 tons per any twelve 

consecutive months.

[PSD avoidance and 391-3-1-.03(2)(c)]

3.2.3 The Permittee may burn the following fuels in the fuel burning sources listed below:

[391-3-1-.03(2)(c)]

a. The Wellons boiler (Source Code: 630) may burn only the following:

i. Woodwaste.

ii. Oilseed hulls in loose and pelletized forms.
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Page 10 of 61 

iii. Railroad crossties. At any one time the Permittee shall not burn used railroad 

crossties at rates exceeding 2.5 tons per hour. The used railroad crossties shall 

not be burned during startup, shutdown, or boiler malfunction. Should the boiler 

or pollution control equipment malfunction during normal operation and result in 

increased emissions, the Permittee shall not fire additional railroad crossties in the 

boiler until the malfunction has been corrected and operations have returned to 

the normal mode.

b. The Cleaver-Brooks boiler (Source Code: 640), the CE boiler (Source Code: 650), 

and the GTS boiler (Source Code: 705) may burn only natural gas, distillate fuel oil, 

and vegetable oil.

c. The GTS boiler (Source Code: 701) may burn only natural gas and distillate fuel oil.

d. The Hydrogen Reformer (Source Code: HP1) may burn only natural gas and 

recirculated vent gas.

e. Grain Dryers 3 and 2 (Source Codes: 009 and 010) may burn only natural gas.

3.2.4 The Permittee shall not discharge or cause the discharge into the atmosphere from the 

following sources PM-10 in excess of the listed pound per hour rates or exceed the 

allowable hour limits:

[PSD Avoidance and 391-3-1-.03(2)(c)]

Emission Unit

Allowable

Hourly Emission

of PM-10 (lb/hr)

Allowable Hours

of Operation

(hr/12 months)

Allowable

Annual Emissions

of PM-10 (tpy)

Seed Receiving (SC C010) 0.16 3500 0.28

Seedhouses (SC C030, C040, C050, C060, 

C070, C080)

0.07* 16000 0.56

Seed Cleaning (SC C100) 0.24 8760 1.05

Seed Delinting (SC C110) 1.42 8760 6.22

Seed Hulling (SC C140) 0.24 8760 1.05

Lint Press (SC C150) 0.24 8760 1.05

Flaking (SC C160) -- 8760 0.05

Conditioning (SC C170) 0.10 8760 0.44

Expanding (SC C180) -- 8760 0.05

Collet Cooler (SC C190) 0.54 8760 2.35

DTDC (SC 230) 0.17 8760 0.74

Hull Storage and Conveying (SC C400, 

C410)

-- 8760 0.05

Meal Grinding (SC C430) -- 8760 0.05

Clay Tank (SC C435) 0.05 80 ~0.00

Meal Loadout (SC C440) 0.05 6000 0.15

White Seed Truck Loadout (SC C450) 0.16 2000 0.16

White Seed/Hull Rail and Truck Loadout (SC 

C460)

0.55 2600 0.72

TOTAL 14.97

* Each Seedhouse fan is limited to 0.07 lb/hr; the 12 fans may not exceed a total of 16,000 hours of operation during 

any 12 consecutive month period.
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Page 11 of 61 

3.2.5 The Permittee shall not discharge, or cause the discharge into the atmosphere, from the 

soybean hull pelletizer (Source Code: 190) any gases, which contain PM in excess of 5.5 

lb/hr and PM-10 in excess of 3.2 lb/hour under any operating condition.

[PSD avoidance and 391-3-1-.03(2)(c)]

3.2.6 The Permittee shall not discharge, or cause the discharge into the atmosphere, from the 

Wellons boiler (Source Code: 630), the Cleaver-Brooks boiler (Source Code: 640), the CE 

boiler (Source Code: 650), the reformer (Source Code: HP1), and the column grain dryers 

with Source Codes: 009 and 010, nitrogen oxides (NOx) emissions in excess of 106.80 tons 

during any twelve consecutive months.

[PSD Avoidance and 391-3-1-.03(2)(c)]

3.2.7 The Permittee shall not discharge, or cause the discharge into the atmosphere, from the 

Wellons boiler (Source Code: 630), the Cleaver-Brooks boiler (Source Code: 640), the CE 

boiler (Source Code: 650), the reformer (Source Code: HP1), and the column grain dryers 

with Source Codes: 009 and 010, carbon monoxide (CO) emissions in excess of 343 tons 

during any twelve consecutive months.

[PSD Avoidance and 391-3-1-.03(2)(c)]

3.2.8 The Permittee shall not discharge, or cause the discharge into the atmosphere, from the 

Wellons boiler (Source Code: 630) nitrogen oxides (NOx) emissions in excess of 0.456 

pounds of NOx per thousand pounds of steam generated.

[PSD avoidance and 391-3-1-.03(2)(c)]

3.2.9 The firing of fuel oil and vegetable oil in the boilers, with Source Codes: 640 and 650, shall 

be limited such that the total uncontrolled emissions of sulfur dioxide (SO2) shall not equal 

or exceed 40.62 tons during any consecutive twelve months. The consumption of fuel and 

vegetable oil shall not exceed 1,120,000 gallons during any twelve consecutive months.

[PSD avoidance and 391-3-1-.03(2)(c)]

3.2.10 The Permittee shall not discharge, or cause the discharge, into the atmosphere, from the 

emission sources listed in the tables below, any gases, which contain pollutants in excess of 

the amounts indicated in the tables, under any operating condition.

[PSD avoidance and 391-3-1-.03(2)(c)]

Source code Description Stack Code PM (lb/hr) PM-10 (lb/hr)

044 Bean Receiving Baghouse S44 5.19 2.04

122 Escher-Wyss Fluidized-Bed Dryer Baghouse 125 0.25 0.13

141 Secondary Dehulling Baghouse 145 0.83 0.11

151 Flaking Mill (Prep-wet) Cyclone 155 4.1 2.19

182 Hull Grinder Baghouse 185 0.75 0.27
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C226, C236 Desolventizer/Toaster/Dryer/Cooler (DTDC) 

Cyclones

235 2.65 2.04

311 Meal/Hull Loadout Baghouse 315 0.6 0.29

331 Meal Grinder Baghouse 335 0.15 0.09

341 Clay Storage Baghouse 345 0.15 0.10

711 Refinery Bleaching Clay Storage Baghouse 715 0.15 0.10

630 Wellons Wood Waste Fired Boiler 635 1.48 1.03

640 Cleaver-Brooks Boiler 645 1.34 1.0

650 CE Boiler 655 1.17 0.83

Source code Description Stack Code PM (lb/ton) PM-10 (lb/ton)

009, 010 Column Grain Dryers (including combustion 

emissions)*

S09, S10 0.222* 0.056*

* The PM and PM-10 emission limits for the two grain dryers are in lbs/ton of soybeans processed through the dryers and 

represent the combined emissions from both dryers.

3.2.11 The Permittee shall only fire wood wastes and similar wastes in Boiler 115A and Boiler 

115B (Source Code: B115A or B115B). Acceptable materials include trusses, saw dust, 

cotton hulls, soybean hulls, ground stumps and tree refuse. The Permittee shall not fire any 

wood wastes that have been painted, pigment-stained, or pressure treated with compounds 

such as chromate copper arsenate, pentachlorophenol, or creosote, nor any waste plywood, 

particle board, oriented strand board, or other types of wood product bound by glues and 

resins.

[Avoidance of 40 CFR 52.21 and 391-3-1-.03(2)(c)]

3.2.12 The Permittee shall not cause, let, suffer, permit or allow the emission of volatile organic 

compounds (VOCs) from:

[Avoidance of 40 CFR 52.21 and 391-3-1-.03(2)(c)]

a. Either Boiler 115A or Boiler 115B in amounts equal to or exceeding 0.086 

lbs/MMBTU, and 

b. Both Boiler 115A and Boiler 115B in amounts equal to or exceeding 39 tons per 12 

consecutive month period.

3.2.13 The Permittee shall not cause, let, suffer, permit or allow the emission of fluoride from:

[Avoidance of 40 CFR 52.21 and 391-3-1-.03(2)(c)]

a. Either Boiler 115A or Boiler 115B in amounts equal to or exceeding 0.004 

lbs/MMBTU, and 
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ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Page 13 of 61 

b. Both Boiler 115A and Boiler 115B in amounts equal to or exceeding 2 tons per 12 

consecutive month period.

3.2.14 The Permittee shall not cause, let, suffer, permit or allow the emission of sulfuric acid mist 

from:

[Avoidance of 40 CFR 52.21 and 391-3-1-.03(2)(c)]

a. Either Boiler 115A or Boiler 115B in amounts equal to or exceeding 0.013 

lbs/MMBTU, and 

b. Both Boiler 115A and Boiler 115B in amounts equal to or exceeding 6 tons per 12 

consecutive month period.

3.2.15 The Permittee shall not cause, let, suffer, permit or allow the emission of sulfur dioxide 

from:

[Avoidance of 40 CFR 52.21 and 391-3-1-.03(2)(c)]

a. Either Boiler 115A or Boiler 115B in amounts equal to or exceeding 0.086 

lbs/MMBTU, and 

b. Both Boiler 115A and Boiler 115B in amounts equal to or exceeding 39 tons per 12 

consecutive month period.

3.2.16 To comply with Permit Condition 3.2.15, wood waste fired in either Boiler 115A or Boiler 

115B shall not contain more than 0.08 percent sulfur, by weight.

[Avoidance of 40 CFR 52.21; 391-3-1-.03(2)(c); and 391-3-1-.02(2)(g) subsumed]

3.3 Equipment Federal Rule Standards

3.3.1 The Permittee shall consume no more than 0.175 gallons of hexane per ton of soybeans 

processed, 0.33 gallons of hexane per ton of cottonseeds processed, and 0.99 pounds of 

hexane per ton of soybeans processed and 1.86 pounds of hexane per ton of cottonseeds 

processed. Compliance with these limits shall be determined on a 12-month (365-day) 

rolling average, calculated and recorded daily.

[PSD, 40 CFR 52.21(j)]

3.3.2 Fuel oil fired in the Cleaver-Brooks boiler (Source Code: 640), the CE boiler (Source Code:

650), and the GTS boilers (Source Codes: 701 and 705) shall be distillate fuel oil and shall 

contain no more than 0.5 percent sulfur by weight. Distillate fuel oil means fuel oil that 

complies with the specifications for fuel oil numbers 1 or 2, as defined by the American 

Society for Testing and Materials in ASTM D396, "Standard Specification for Fuel Oils”. 

Vegetable oil fired in the boilers, with Source Codes: 640, 650 and 705 shall not contain 

more than 0.5% sulfur by weight.

[40 CFR 60.42c(d), PSD Avoidance, and 391-3-1-.03(2)(c)]
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ADM Valdosta Permit No.: 2075-185-0051-V-02-0

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3.3.3 The Permittee shall comply with all applicable provisions of the New Source Performance 

Standards (NSPS) as found in 40 CFR Part 60, Subpart A - "General Provisions" and 40 

CFR Part 60, Subpart Dc - "Standards of Performance for Small Industrial-CommercialInstitutional Steam Generating Units," for operation of the boilers with Source Codes: 

B115A, B115B, 701 and 705.

[40 CFR Part 60, Subpart Dc]

3.3.4 Grain Dryer No. 3 (Source Code: 009) shall not have a plate perforation size exceeding 2.4 

mm (0.094 in) diameter.

[40 CFR Part 60, Subpart DD]

3.3.5 For purposes of this Permit, Boiler 115A, Boiler 115B, and the electrostatic precipitator 

(Control Device ID No: 661) share a common stack, Stack No. 0665.

[PSD, 40 CFR 52.21(j)]

3.3.6 The Permittee shall not discharge or cause the discharge into the atmosphere from:

[40 CFR 60.43c(c) and 391-3-1-.02(2)(d)(3) subsumed]

a. Either Boiler 115A or Boiler 115B, any visible emissions of which the opacity is 

equal to or greater than 20 percent opacity (6-minute average), except for one 6-

minute period per hour of not more than 27 percent opacity, and

b. Both Boiler 115A and Boiler 115B, any visible emissions of which the opacity is 

equal to or greater than 20 percent opacity (6-minute average), except for one 6-

minute period per hour of not more than 27 percent opacity.

3.3.7 The Permittee shall not cause, let, suffer, permit or allow the emission of fly ash and/or 

other particulate matter emissions from:

[40 CFR 60.43c(b)1 and 391-3-1-.02(2)(d) subsumed]

a. Either Boiler 115A or Boiler 115B, in amounts equal to or exceeding 0.025 

lbs/MMBTU, and

b. Both Boiler 115A and Boiler 115B, in amounts equal to or exceeding 0.025 

lbs/MMBTU.

3.3.8 The Permittee shall not cause, let, suffer, permit or allow the emission of nitrogen oxides 

compounds (NOx) from:

a. Either Boiler 115A or Boiler 115B, in amounts equal to or exceeding 0.30 

lbs/MMBTU, and

b. Both Boiler 115A and Boiler 115B, in amounts equal to or exceeding 0.30 

lbs/MMBTU.

The emission limits listed in this permit condition apply during all times of operation, 

including startup, shutdown, and malfunction.

[PSD, 40 CFR 52.21 and 391-3-1-.03(2)(c)]
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3.3.9 The Permittee shall not cause, let, suffer, permit or allow the emission of carbon monoxide 

from:

a. Either Boiler 115A or Boiler 115B, in amounts equal to or exceeding 400 ppm by 

volume on a dry basis corrected to seven percent O2 (3-test run average), and

b. Both Boiler 115A and Boiler 115B, in amounts equal to or exceeding 400 ppm by 

volume on a dry basis corrected to seven percent O2 (3-test run average).

The emission limits listed in this permit condition apply during all times of operation, 

including startup, shutdown, and malfunction.

[PSD, 40 CFR 52.21]

3.3.10 The Permittee shall operate the electrostatic precipitator (Control Device ID No: 661) as 

described in Condition 3.3.5, at all times that either Boiler 115A or Boiler 115B is in 

operation.

[391-3-1-.03(2)(c)]

3.3.11 The Permittee shall not cause, let, suffer, permit or allow the emission of hydrogen chloride 

from:

[40 CFR 63.7500(a)(1)]

a. Either Boiler 115A or Boiler 115B in amounts equal to or exceeding 0.02 

lbs/MMBTU, and

b. Boiler 115A and Boiler 115B in amounts equal to or exceeding 0.02 lbs/MMBTU.

3.3.12 The Permittee shall not cause, let, suffer, permit or allow the emission of mercury from:

[40 CFR 63.7500(a)(1)]

a. Either Boiler 115A or Boiler 115B in amounts equal to or exceeding 3x10-6

lbs/MMBTU, and

b. Boiler 115A and Boiler 115B in amounts equal to or exceeding 3x10-6 lbs/MMBTU.

3.4 Equipment SIP Rule Standards

3.4.1 The Permittee shall not discharge or cause the discharge into the atmosphere from the 

soybean extraction processing equipment, the cottonseed extraction processing equipment, 

or the edible oil refinery processing equipment any gases, which exhibit visible emissions 

with opacity equal to or greater than 40%.

[391-3-1-.02(2)(b)]

3.4.2 The Permittee shall not discharge, or cause the discharge, into the atmosphere, from the 

soybean extraction processing equipment, particulate emissions (PM) in excess of the rate 

derived from the following equations:
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a. E = 4.1 × P0.67 for process input weight rate up to and including 30 tons per hour.

b. E = 55 × P0.11 – 40 for process input weight rate above 30 tons per hour.

Where E is the emission rate in pounds per hour and P is the process input weight rate in 

tons per hour.

[391-3-1-.02(2)(e)1(i)]

3.4.3 The Permittee shall not discharge, or cause the discharge, into the atmosphere, from the 

cottonseed extraction processing equipment, particulate emissions (PM) in excess of the 

rate derived from the following equations:

a. E = 4.1 × P0.67 for process input weight rate up to and including 30 tons per hour.

b. E = 55 × P0.11 – 40 for process input weight rate above 30 tons per hour.

Where E is the emission rate in pounds per hour and P is the process input weight rate in 

tons per hour.

[391-3-1-.02(2)(e)1(i)]

3.4.4 The Permittee shall not discharge or cause the discharge into the atmosphere from the 

boilers with Source Codes: 630, 640, 650, 701, and 705, and the hydrogen reformer (Source 

Code: HP1) any gases which:

[391-3-1-.02(2)(d)3 and 391-3-1-.02(2)(d)2.(ii)]

a. Exhibit visible emissions the opacity of which is equal to or greater than 20 percent 

opacity except for one 6-minute period per hour of not more than 27 percent opacity.

b. Contain particulate matter (PM) in excess of the rate derived from P = 0.5*(10/R)0.5 

where P equals the allowable emission rate in pounds per million BTU heat input and 

R equals the heat input rate in million BTU per hour from the emission unit.

3.4.5 The Permittee shall not discharge, or cause the discharge, into the atmosphere, from 

Bleaching Clay Receiving (Source Code: 710), particulate emissions in excess of the rate 

derived from the following equations: 

a. E = 4.1 × P0.67 for process input weight rate up to and including 30 tons per hour.

b. E = 55 × P0.11 – 40 for process input weight rate above 30 tons per hour.

Where E is the emission rate in pounds per hour and P is the process input weight rate in 

tons per hour.

[391-3-1-.02(2)(e)1(i)]

3.4.6 The Permittee shall not burn, in the fuel burning sources (Source Codes: 630, 640, 650, 

701, 705, HP1, 009, and 010), any fuel with a fuel sulfur content exceeding 2.5%, by 

weight.

[391-3-1-.02(2)(g)2]
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3.5 Equipment Standards Not Covered by a Federal or SIP Rule and Not Instituted as an Emission 

Cap or Operating Limit

3.5.1 The soybean and the cottonseed oil extraction units (Source Codes: S200 and 210), and the 

Desolventizer/Toaster of the DTDC unit (Source Code: S250), shall be equipped with a 

condenser and a mineral oil scrubber emission control system. The control system shall be 

in operation at all times when any of the process units specified in this condition are in 

operation. In the event that the emission control system is off-line while any of the 

specified process units are in operation, the Division shall be notified within four hours of 

any such occurrence.

[391-3-1-.02(2)(a)10 and 391-3-1-.03(2)(c)]

3.5.2 The Permittee shall maintain an inventory of the filter bags such that an adequate supply of 

the clean bags is on hand to replace any defective bags in each baghouse.

[391-3-1-.02(2)(a)10 and 391-3-1-.03(2)(c)]
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PART 4.0 REQUIREMENTS FOR TESTING

4.1 General Testing Requirements

4.1.1 The Permittee shall cause to be conducted a performance test at any specified emission unit 

when so directed by the Environmental Protection Division (“Division”). The test results 

shall be submitted to the Division within 60 days of the completion of the testing. Any 

tests shall be performed and conducted using methods and procedures that have been 

previously specified or approved by the Division.

[391-3-1-.02(6)(b)1(i)]

4.1.2 The Permittee shall provide the Division thirty (30) days (or sixty (60) days for tests 

required by 40 CFR Part 63) prior written notice of the date of any performance test(s) to 

afford the Division the opportunity to witness and/or audit the test, and shall provide with 

the notification a test plan in accordance with Division guidelines.

[391-3-1-.02(3)(a)]

4.1.3 Performance and compliance tests shall be conducted and data reduced in accordance with 

applicable procedures and methods specified in the Division’s Procedures for Testing and 

Monitoring Sources of Air Pollutants. The methods for the determination of compliance 

with emission limits listed under Sections 3.2, 3.3, 3.4 and 3.5 are as follows:

a. Method 1 for the selection of sampling site and the number of traverse points.

b. Method 2 for the determination of stack gas flow rate.

c. Method 3 or 3A for the determination of stack gas molecular weight.

d. Method 3B or Method 3A for the determination of the emissions rate correction 

factor or excess air.

e. Method 4 for the determination of moisture.

f. Method 202, Method 5 and Method 5B, or Method 17 for the determination of 

particulate matter concentration.

[40 CFR 60.45c(a)]

g. Method 7 or 7E for the determination of nitrogen oxides concentration.

h. Method 9 and the procedures of Section 1.3 of the above referenced document for the 

determination of opacity.

i. Method 10 or Method 10B for the determination of carbon monoxide concentration.

[40 CFR 52.21]
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j. Method 19 shall be used, when applicable, to convert particulate matter, carbon 

monoxide, and nitrogen oxides concentrations (i.e., grains/dscf for PM; ppm for 

gaseous pollutants), as determined using other methods specified in this section, to 

pollutant emission rates (i.e., lb/MMBtu).

k. Method 201 or 201A, in conjunction with Method 202 as applicable, for the 

determination of PM-10 emissions.

l. Method 2, Method 2F, or Method 2G for the determination of Boiler 115A or Boiler 

115B velocity and volumetric flow.

[40 CFR 60.45c(a)]

m. Method 3B for the determination of Boiler 115A or Boiler 115B Oxygen (O2) and 

carbon dioxide (CO2) concentrations. Method 3A may be used as an alternative.

[PSD, 40 CFR 60.45c(a)]

n. Determination of sulfur content of the fuel type for a fuel sample of the wood waste 

fuel fired in Boiler 115A or Boiler 115B shall be determined by procedure discussed 

in ASTM Method E775).

[PSD, 40 CFR 52.21]

o. Method 25 for the determination of volatile organic compounds emissions of Boiler 

115A or Boiler 115B.

[PSD, 40 CFR 52.21]

p. Method 13A or Method 13B for the determination of fluoride emissions of Boiler 

115A or Boiler 115B.

[PSD, 40 CFR 52.21]

q. Method 6 or Method 8 for the determination of sulfuric acid mist emissions of Boiler 

115A or Boiler 115B.

[PSD, 40 CFR 52.21]

r. Method 6, Method 6C, or Method 8 for the determination of sulfur dioxide emissions 

of Boiler 115A or Boiler 115B.

[PSD, 40 CFR 52.21]

Minor changes in methodology may be specified or approved by the Director or his 

designee when necessitated by process variables, changes in facility design, or 

improvement or corrections that, in his opinion, render those methods or procedures, or 

portions thereof, more reliable.

[391-3-1-.02(3)(a)]
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4.2 Specific Testing Requirements

4.2.1 Should the Permittee elect to burn oilseed hulls in the Wellons boiler (Source Code: 630) 

the Permittee shall conduct a performance test for PM-10, CO and NOx within 90 days of 

the commencement of the combustion of such fuel and submit the source test results to 

EPD within 30 days of the completion of the testing.

[391-3-1-.02(6)(b)]

4.2.2 Unless otherwise specified by the Director, the Permittee shall cause to be conducted on the 

Wellons boiler (Source Code: 630), a performance test for PM emissions at approximately 

twelve-month intervals. The test results shall be submitted to the Division within 60 days 

of the completion of said testing.

[391-3-1-.02(6)(b)]

4.2.3 Unless otherwise specified by the Director, the Permittee shall cause to be conducted on the 

Wellons boiler (Source Code: 630), performance tests for CO and NOx emissions by July 

2011 and at approximately thirty-six month intervals thereafter. The test results shall be 

submitted to the Division within 60 days of the completion of said testing.

[391-3-1-.02(6)(b)]

4.2.4 Within 90 days of burning vegetable oil in either two of the boilers with Source Codes: 640 

and 650, the Permittee shall conduct performance tests for PM-10, CO and NOx emissions 

from that boiler, while firing vegetable oil. The same boiler shall also be tested for PM-10, 

CO and NOx emissions while burning #2 fuel oil. The results of the performance tests 

shall be submitted to the Division within 60 days of the completion of the testing.

[391-3-1-.02(6)(b)]

4.2.5 Within 60 days after achieving the maximum production rate at which the Collet cooler 

(Source Code: C190) will be operated, but no later than 180 days after the initial startup, 

the Permittee shall conduct particulate matter and PM-10 performance tests on the Collet 

cooler. The results of the performance tests shall be submitted to the Division within 60 

days of the completion of testing.

[391-3-1-.02(6)(b)]

4.2.6 Should the performance testing results, per Condition 4.2.1 show that emissions of any 

pollutant from oilseed hull combustion in the Wellons boiler (Source Code: 630) is greater 

than emissions from wood-waste combustion or greater than the emission factors used to 

support the permitting conclusions, the Division reserves the right to reopen and modify 

this permit.

[391-3-1-.02(6)(b)]

4.2.7 Consistent with Condition 6.2.5, should the performance testing results per Condition 4.2.4 

show that emissions of any pollutant from vegetable oil combustion is greater than 

emissions from fuel oil combustion or greater than the emission factors used to support the 

permitting conclusions, the Division reserves the right to reopen and modify this permit.

[391-3-1-.02(6)(b)]
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4.2.8 In the event the Permittee fires fuel, in either boiler with Source Code: B115A or B115B, 

that differs from the fuel blend fired during the initial performance testing, the facility must 

conduct fuel analysis to determine if the nitrogen fuel content and compare it with that of 

the fuel fired during the initial compliance test. The results of this fuel analysis shall be 

submitted to the Division within 30 days of the test.

If a fuel analysis shows that the nitrogen content of a fuel exceeds, by more than 20 percent, 

the nitrogen content of the fuel fired during the initial performance testing, then new 

performance testing is required to demonstrate compliance with the NOx emission limit, 

unless otherwise specified by the Division. The Permittee shall conduct performance 

testing, using the appropriate procedures in Method 7 or Method 7E, to determine whether 

emissions are in compliance with the emission limits in Condition 3.3.8. Performance 

testing shall not be conducted during periods of startup, shutdown, or malfunction. The test 

results shall be submitted to the Division within sixty (60) days of the completion of 

testing.

If testing is required, the Permittee shall conduct a total of three (3) performance tests, 

unless otherwise specified by the Division. The performance tests shall be conducted for 

the following operating scenarios: Boiler 115A operating independently, Boiler 115B 

operating independently, and Boilers 155A and 115B operating concurrently. Such 

performance tests shall be conducted at maximum load for both boilers and using the worstcase proposed fuel blend.

The performance test results shall be used to establish a nitrogen oxides emission factor for 

each boiler, in pounds of nitrogen oxides per ton of wood waste combusted. Additionally, 

the results shall be used to establish the maximum wood waste firing rate, the maximum 

nitrogen content of the fuel, and the heat value at which compliance with Condition 3.3.8 is 

expected. This information shall be submitted to the Division, along with the test results, 

within sixty (60) days of the completion of testing.

[PSD, 40 CFR 52.21]

4.2.9 Any performance testing required by Condition 4.2.8 for nitrogen oxide emission shall be 

accompanied by simultaneous performance testing for carbon monoxide (CO).

4.2.10 The Permittee shall conduct an initial performance evaluation per 40 CFR 63.8 and 

performance specification 1 (PS–1) of 40 CFR Part 60, Appendix B for the COMS required 

per Condition 5.2.1a. The Permittee shall furnish to the Division a written report of the 

results of such performance tests. A separate performance evaluation is required for the 

following operating scenarios: Boiler 115A operating independently and Boiler 115B 

operating independently. Such performance evaluations shall be conducted at maximum 

load using the worst-case proposed fuel blend. In the event that the Permittee makes any 

changes to operation including but not limited to the fuel blend fired in either boiler 

(Source Code: B115A or B115B), the facility must conduct additional performance 

evaluation by applicable methods.
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PART 5.0 REQUIREMENTS FOR MONITORING (Related to Data Collection)

5.1 General Monitoring Requirements

5.1.1 Any continuous monitoring system required by the Division and installed by the Permittee 

shall be in continuous operation and data recorded during all periods of operation of the 

affected facility except for continuous monitoring system breakdowns and repairs. 

Monitoring system response, relating only to calibration checks and zero and span 

adjustments, shall be measured and recorded during such periods. Maintenance or repair 

shall be conducted in the most expedient manner to minimize the period during which the 

system is out of service.

[391-3-1-.02(6)(b)1]

5.2 Specific Monitoring Requirements

5.2.1 The Permittee shall install, calibrate, maintain, and operate a system to continuously 

monitor and record the indicated pollutants on the following equipment. Each system shall 

meet the applicable performance specification(s) of the Division's monitoring requirements.

[391-3-1-.02(6)(b)1 and 40 CFR 70.6(a)(3)(i)]

a. A continuous opacity monitoring system (COMS), installed at Stack No. 0665 per 

PS-1 of 40 CFR Part 60, Appendix B, to monitor opacity from the boilers with Source 

Codes: B115A and B115B.

[40 CFR 60.43c(c) and 40 CFR 60.47c]

5.2.2 The Permittee shall install, calibrate, maintain, and operate monitoring devices for the 

measurement of the indicated parameters on the following equipment. Data shall be 

recorded at the frequency specified below. Where such performance specification(s) exist, 

each system shall meet the applicable performance specification(s) of the Division's 

monitoring requirements.

[391-3-1-.02(6)(b)1 and 40 CFR 70.6(a)(3)(i)]

a. Natural gas, fuel oil, and vegetable oil consumption in the Cleaver-Brooks boiler 

(Source Code: 640), the CE boiler (Source Code: 650), and the GTS boiler (Source 

Code: 705). Data shall be recorded monthly.

b. Natural gas and fuel oil consumption in the GTS boiler (Source Code: 701). Data 

shall be recorded monthly.

c. Natural gas consumption in the column grain dryers (Source Codes: 009 and 010) and 

the reformer (Source Code: HP1). Data shall be recorded monthly.
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d. Pressure drop from the following baghouses: Rail Pit, Nos. 1 and 2 (Source Codes: 

001 and 002), Bean Cleaning and Distribution (Source Code: 044), Truck Dump 

(Source Code: 044), Fluidized-Bed Dryer (Source Code: 122), Secondary Dehulling 

(Source Code: 141), Hull Grinder (Source Code: 182), Meal/Hull Loadout (Source 

Code: 311), Meal Grinder (Source Code: 331), Clay Storage (Source Code: 341), 

Bleaching Clay Receiving (Source Code: 711), and two baghouses on the Wellons 

boiler (Source Codes: 632 and 633). The pressure drop shall be recorded at least once 

per operating week.

e. Pressure drop from the following baghouses in the cottonseed oil extraction unit: 

Flaking (Source Code: C161), Collet Cooler (Source Code: C191), Bulk Hull Storage 

(Source Code: C401), Pelleted Hull Storage (Source Code: C411), Meal Grinding 

(Source Code: C431), and Meal Loadout (Source Code: C441). The pressure drop 

shall be recorded at least once per operating week.

f. Temperature indicators on the ducting to the two baghouses (Source Codes: 632 and 

633) receiving exhaust from the Wellons boiler.

g. Continuous steam flow meter to measure and record the amount of steam produced 

from the Wellons boiler (Source Code: 630). Steam production records in this boiler 

shall be compiled monthly for use in NOx and CO emission equations.

5.2.3 The Permittee shall implement and maintain a leak detection and repair/correction (LDAR) 

program to minimize hexane emissions from process piping and other equipment in the 

soybean and cottonseed oil solvent extraction units. A description of this program, 

including the record keeping format of said records, shall be kept in a permanent form at 

the facility, readily available for inspection. At a minimum, the LDAR program shall 

contain the following elements:

[391-3-1-.02(7)]

a. Each pump and valve shall be inspected weekly for indication of liquids dripping 

from a pump seal. If an indication of liquid dripping from a pump seal (such as 

dripping, spraying, misting, clouding, ice formation, puddling or new stains) is 

present, this is considered to be a leak detected.

b. Each pump and valve shall be monitored monthly using Method 21. The instrument 

used shall be calibrated before its use by the procedures specified in Method 21. If a 

reading of 10,000 ppm or greater is measured, this is considered to be a leak detected.

c. When a leak is detected, the Permittee shall repair the leak as soon as practicable, but 

not later than 15 calendar days after the leak is first detected. A first attempt at repair 

shall be made within 5 calendar days after the leak is first detected.

d. The records of location, magnitude, date, and detection method for each leak; the date 

and the methods for each repair attempt; and the date of the successful repair of the 

leak shall be kept in a form suitable for inspection or submittal.
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e. The Permittee may incorporate into its LDAR program any reduction in monitoring 

frequency or repair delay that would be allowed by 40 CFR Part 60, Subpart VV, 

provided the citation allowing the modification is indicated in the plan.

5.2.4 The Permittee shall create and maintain a record, suitable for inspection or submittal, 

utilizing the following applicable operation and maintenance checks for each week or 

portion of each week of operation of the vegetable oil mill:

[391-3-1-.02(6)(b)1]

a. Check the exterior of each cyclone listed in the Table in Section 3.1 of this permit for 

holes in the body or evidence of malfunction in the interior of the cyclone.

b. Check each hopper for bridging and plugging.

c. Check each screw conveyor (or other particulate transfer device) for proper operation 

to ensure dust removal.

For the purpose of the report required by Condition 6.1.4, the Permittee shall report as 

excursion, any adverse condition disclosed by these weekly operational and maintenance 

surveillance checks. In addition to the information required to be reported by Condition 

6.1.4, the report shall contain a summary of any weeks for which the required weekly 

operational and maintenance checks were not made and the reason for such failure to 

perform the surveillance.

5.2.5 The Permittee shall perform a check to determine if visible emissions are present from each 

rotary drum filter and baghouse venting to the atmosphere from the emission units listed in 

Section 3.1 of this permit and the uncontrolled emission units with Source Codes: 005, 009, 

010, C030, C040, C050, C060, C070, C080, and C180. The Permittee shall retain records 

in a daily visible emissions (VE) log suitable for inspection or submittal. The checks shall 

be conducted at least once for each day or portion of each day of operation and shall be 

conducted using the following procedure:

[391-3-1-.02(6)(b)1 and 40 CFR 70.6(a)(3)(i)]

a. The person performing the determination shall stand at a distance of at least 15 feet, 

which is sufficient to provide a clear view of the plume against a contrasting 

background with the sun in the 140° sector at his/her back. Consistent with this 

requirement, the determination shall be made from a position such that the line of 

vision is approximately perpendicular to the plume direction. Only one plume shall 

be in the line of sight at any time when multiple stacks are in proximity to each other.
Title V Permit

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For each source that exhibits visible emissions, the Permittee shall determine the cause of 

the visible emissions and correct the problem in the most expedient manner possible. The 

Permittee shall note the cause of the visible emissions and the corrective action taken in the 

daily maintenance log.

5.2.6 The Permittee shall develop and implement a Preventive Maintenance Program for the 

baghouses specified in Conditions 5.2.2 d. and e. to assure that the provisions of Condition 

8.17.1 are met. The program shall be subject to review and modification by the Division 

and shall include the pressure drop ranges that indicate proper operation for the baghouse. 

At a minimum, the following operation and maintenance checks shall be made on at least a 

daily basis, with a record of the findings and corrective actions taken kept in a maintenance 

log:

[391-3-1-.02(6)(b)1 and 40 CFR 70.6(a)(3)(i)]

a. Record the pressure drop across the baghouse and ensure that it is within the 

appropriate range.

b. For baghouses equipped with compressed air cleaning systems, check the system for 

proper operation. This may include checking for low pressure, leaks, proper 

lubrication, and proper operation of timer and valves.

c. For baghouses equipped with reverse air cleaning systems, check the system for 

proper operation. This may include checking damper, bypass, and isolation valves 

for proper operation.

d. For baghouses equipped with shaker cleaning systems, check the system for proper 

operation. This may include checking shaker mechanism for loose or worn bearings, 

drive components, mountings, proper operation of outlet/isolation valves, and proper 

lubrication.

e. Check hopper for bridging and plugging. If hopper is equipped with screw conveyor, 

check for proper operation to ensure efficient dust removal.

5.2.7 The Permittee shall monitor the nitrogen oxides (NOx) and the carbon monoxide (CO) from 

the emission units with Source Codes: 630, 640, 650, and HP1, using the following plan:

[391-3-1-.02(6)(b)1 and 40 CFR 70.6(a)(3)(i)]

a. Measurements of nitrogen oxides, carbon monoxide, and oxygen concentrations shall 

be conducted using the procedures of American Society for Testing and Materials 

(ASTM) D6522, Standard Test Method for Determination of Nitrogen Oxides, 

Carbon Monoxide, and Oxygen Concentrations in Emissions from Natural Gas-Fired 

Reciprocating Engines, Combustion Turbines, Boilers and Process Heaters Using 

Portable Analyzers. Method 7E in conjunction with Method 3A may be used as an 

alternative.

b. For emission units except the Wellons boiler (Source Code: 630), the NOx and the 

CO emission rates shall be determined using the following equation:
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2 20.9

20.9

O

E KCd Fd − =

where:

E = Mass emissions of NOx or CO (lb/MMBTU)

K = Conversion factor ([lb/scf]/ppm)

= 1.194 x 10-7 for nitrogen oxides

= 7.263 x 10-8 for carbon monoxide

Cd = Concentration of NOx or CO (ppm by volume, dry basis)

Fd = F-factor (dscf/MMBTU)

= 8710 [for Natural Gas]

= 9190 [for Fuel Oil]

= Various [for Mixture of Natural Gas and Vent Gas in HP1 (will be calculated 

based on the ratio of natural gas and vent gas being used for the day of the test)]

O2 = Exhaust Gas Oxygen Concentration (percent by volume, dry basis)

c. For the Wellons Boiler (Source Code: 630), a measurement of stack gas flow rate 

shall be made using the procedures in Method 2 of the Division’s Procedures for 

Testing and Monitoring Sources of Air Pollutants, Appendix A. In lieu of 

measuring the molecular weight and moisture of the stack gas, these values may be 

taken from the most recent performance test on the Wellons boiler. The steam flow 

from the Wellons boiler shall be recorded during the monitoring period using the 

device required by Condition 5.2.1. The NOx and the CO emission rates shall be 

determined using the following equation:

E = 60K Cd Qsd

where:

E = Emission rate of NOx or CO (lb/hr)

K = Conversion factor ([lb/scf]/ppm)

= 1.194 x 10-7 for nitrogen oxides

= 7.263 x 10-8 for carbon monoxide

Cd = Concentration of NOx or CO (ppm by volume, dry basis)

Qsd= Stack gas flow rate measured using Method 2 corrected to dry standard 

condition (dscf/min)

d. The Permittee shall measure the NOx and the CO emissions rate from each emission 

unit. The measurement periods shall consist of one (1) test run thirty minutes in 

duration.

e. The Permittee shall conduct measurements at a frequency of one per calendar quarter 

that the unit is operated.
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f. Following any measurement that is greater than the applicable NOx or CO level listed 

in Condition 6.1.7 c., the Permittee shall conduct a new measurement within one unitoperating day. Following this measurement, subsequent measurements shall be 

conducted on a weekly basis until two consecutive measurements are less than the 

applicable level.

g. A unit-operating day shall be defined as any day that the unit is operated for more 

than 30 minutes between 12:00 midnight and the following midnight.

5.2.8 Monitor and record the amount and type of wood waste combusted in each boiler with 

Source Code: B115A and B115B daily.

[40 CFR 60.48c(g)]
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PART 6.0 RECORD KEEPING AND REPORTING REQUIREMENTS

6.1 General Record Keeping and Reporting Requirements

6.1.1 Unless otherwise specified, all records required to be maintained by this Permit shall be 

recorded in a permanent form suitable for inspection and submission to the Division and to 

the EPA. The records shall be retained for at least five (5) years following the date of 

entry.

[391-3-1-.02(6)(b)1(i) and 40 CFR 70.6(a)(3)]

6.1.2 In addition to any other reporting requirements of this Permit, the Permittee shall report to 

the Division in writing, within seven (7) days, any deviations from applicable requirements 

associated with any malfunction or breakdown of process, fuel burning, or emissions 

control equipment for a period of four hours or more which results in excessive emissions.

The Permittee shall submit a written report that shall contain the probable cause of the 

deviation(s), duration of the deviation(s), and any corrective actions or preventive measures 

taken.

[391-3-1-.02(6)(b)1(iv), 391-3-1-.03(10)(d)1(i), and 40 CFR 70.6(a)(3)(iii)(B)]

6.1.3 The Permittee shall submit written reports of any failure to meet an applicable emission 

limitation or standard contained in this permit and/or any failure to comply with or 

complete a work practice standard or requirement contained in this permit which is not 

otherwise reported in accordance with condition 6.1.4 or 6.1.2. Such failures shall be 

determined through observation; data from any monitoring protocol, or by any other 

monitoring that is required by this permit. The reports shall cover each semiannual period

ending June 30 and December 31 of each year, shall be postmarked by the 30th day 

following the end of each reporting period, July 30 and January 30, respectively, and shall 

contain the probable cause of the failure(s), duration of the failure(s), and any corrective 

actions or preventive measures taken.

[391-3-1-.03(10)(d)1(i) and 40 CFR 70.6(a)(3)(iii)(B)]

6.1.4 The Permittee shall submit a written report containing any excess emissions, exceedances, 

and/or excursions as described in this permit and any monitor malfunctions for each 

quarterly period ending March 31, June 30, September 30, and December 31 of each year. 

All reports shall be postmarked by the 30th day following the end of each reporting period, 

April 30, July 30, October 30, and January 30, respectively. In the event that there have not 

been any excess emissions, exceedances, excursions or malfunctions during a reporting 

period, the report should so state. Otherwise, the contents of each report shall be as 

specified by the Division’s Procedures for Testing and Monitoring Sources of Air 

Pollutants and shall contain the following:

[391-3-1-.02(6)(b)1 and 40 CFR 70.6(a)(3)(iii)(A)]

a. A summary report of excess emissions, exceedances and excursions, and monitor 

downtime, in accordance with Section 1.5(c) and (d) of the above referenced 

document, including any failure to follow required work practice procedures.
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b. Total process operating time during each reporting period.

c. The magnitude of all excess emissions, exceedances and excursions computed in 

accordance with the applicable definitions as determined by the Director, and any 

conversion factors used, and the date and time of the commencement and completion 

of each time period of occurrence.

d. Specific identification of each period of such excess emissions, exceedances, and 

excursions that occur during startups, shutdowns, or malfunctions of the affected 

facility. Include the nature and cause of any malfunction (if known), the corrective 

action taken or preventive measures adopted.

e. The date and time identifying each period during which any required monitoring 

system or device was inoperative (including periods of malfunction) except for zero 

and span checks, and the nature of the repairs, adjustments, or replacement. When 

the monitoring system or device has not been inoperative, repaired, or adjusted, such 

information shall be stated in the report.

f. Certification by a Responsible Official that, based on information and belief formed 

after reasonable inquiry, the statements and information in the report are true, 

accurate, and complete.

6.1.5 Where applicable, the Permittee shall keep the following records:

[391-3-1-.03(10)(d)1(i) and 40 CFR 70.6(a)(3)(ii)(A)]

a. The date, place, and time of sampling or measurement;

b. The date(s) analyses were performed;

c. The company or entity that performed the analyses;

d. The analytical techniques or methods used;

e. The results of such analyses; and

f. The operating conditions as existing at the time of sampling or measurement.

6.1.6 The Permittee shall maintain files of all required measurements, including continuous 

monitoring systems, monitoring devices, and performance testing measurements; all 

continuous monitoring system or monitoring device calibration checks; and adjustments 

and maintenance performed on these systems or devices. These files shall be kept in a 

permanent form suitable for inspection and shall be maintained for a period of at least five 

(5) years following the date of such measurements, reports, maintenance and records.

[391-3-1-.03(10)(d)1(i) and 40 CFR 70.6 (a)(3)(ii)(B)]
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6.1.7 For the purpose of reporting excess emissions, exceedances or excursions in the report 

required in Condition 6.1.4, the following excess emissions, exceedances, and excursions 

shall be reported:

[391-3-1-.02(6)(b)1 and 40 CFR 70.6(a)(3)(i)]

a. Excess emissions: (means for the purpose of this condition and condition 6.1.4, any 

condition that is detected by monitoring or record keeping which is specifically 

defined, or stated to be, excess emissions by an applicable requirement)

i. Any day the 12-month rolling average hexane loss exceeds 0.175 gallons per 

ton of soybean processed, 0.33 gallons per ton of cottonseeds processed or 0.99 

pounds per ton of hexane per ton of soybean processed and 1.86 pounds of 

hexane per ton of cottonseeds processed. Hexane consumption shall be 

calculated as shown in Condition 6.2.11 of this permit.

ii. Any day the 12 consecutive operating months rolling average hexane loss 

exceeds the allowable hexane loss, calculated using equations and values in 

Table 1 of 40 CFR 63.2840.

b. Exceedances: (means for the purpose of this condition and Condition 6.1.4, any 

condition that is detected by monitoring or record keeping that provides data in terms 

of an emission limitation or standard and that indicates that emissions (or opacity) do 

not meet the applicable emission limitation or standard consistent with the averaging 

period specified for averaging the results of the monitoring).

i. Any 12-consecutive month period that the total soybeans processed exceeds 

1,095,000 tons.

ii. Any 12-consecutive month period that the total crude vegetable oil processed in 

the vegetable oil refinery exceeds 1095 million pounds.

iii. Any 12-consecutive month period that the total fuel oil and vegetable oil 

consumption in the boilers with Source Codes: 640, 650 and 705 exceeds 

1,120,000 gallons.

iv. Any 12-consecutive month period that the total soybeans processed through the 

grain dryers (Source Codes: 009 and 010) exceeds 549,200 tons.

v. Any 12-consecutive month period that the total clay loaded in the clay storage 

silos (Source Codes: 340 and 710) exceeds 10,000 tons.

vi. Any time during which fuel oil is combusted with a sulfur content greater than 

0.5 percent, by weight, in the Cleaver-Brooks boiler (Source Code: 640), the CE 

boiler (Source Code: 650), or the GTS boilers (Source Codes: 701, and SC 

705).

vii. Any time during which the firing rate of used railroad ties exceeds 2.5 tons per 

hour in the Wellons boiler (Source Code: 630).
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viii. Any measurement of the NOx emission rate from the wood-fired Wellons boiler 

(Source Code: 630) made, in accordance with the procedures of Condition 

5.2.7, which exceeds 0.456 pounds per thousand pounds of steam generated.

ix. Any 12-consecutive month period that the total hours of operation exceeds 

3,500 hours for Seed Receiving (Source Code: C010); 16,000 hours for the 

Seedhouses (Source Codes: C030, C040, C050, C060, C070, and C080); 80 

hours for the Clay Tank (Source Code: C435); 6,000 hours for Meal Loadout 

(Source Code: C440); 2,000 hours for White Seed Truck Loadout (Source 

Code: C450); or 2,600 hours for White Seed/Hull Rail and Truck Loadout 

(Source Code: C460).

x. Any 12-consecutive month period that the total NOx emissions from the 

emission units listed in Condition 3.2.6 exceed 106.8 tons.

xi. Any 12-consecutive period that the total CO emissions from the emission units 

listed in Condition 3.2.7 exceed 343 tons.

xii. Any 6-minute average opacity from the boilers with Source Codes: B115A

and/or B115B (Stack 0665), which equals or exceeds 20%, except for one 6-

minute period per hour of not more than 27%.

xiii. Any combined 12-consecutive month rolling total of VOC emissions from the 

boilers with Source Codes: B115A and B115B in excess of 39 tons.

xiv. Any combined 12-consecutive month rolling total of fluoride emissions from 

the boilers with Source Codes: B115A and B115B in excess of 2 tons.

xv. Any combined 12-consecutive month rolling total of sulfuric acid mist 

emissions from the boilers with Source Codes: B115A and B115B in excess of 

6 tons.

xvi. Any combined 12-consecutive month rolling total of sulfur dioxide emissions 

from the boilers with Source Codes: B115A and B115B in excess of 39 tons.

xvii. Any daily wood waste firing rate for either Boiler 115A or 115B that exceeds 

the maximum rate established by testing requirements per Condition 4.2.11 for 

nitrogen oxides from the boilers with Source Codes: B115A and B115B.

xviii. Any time a fuel is fired in either Boiler 115A or Boiler 115B that violates 

Condition 3.2.11.

c. Excursions: (means for the purpose of this condition and condition 6.1.4, any 

departure from an indicator range or value established for monitoring consistent with 

any averaging period specified for averaging the results of the monitoring).
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i. Any adverse condition discovered in a weekly check required per Condition 

5.2.4.

ii. Any two consecutive daily determinations of visible emission from any source 

listed in Condition 5.2.5.

iii. Any incident, wherein the condenser and mineral oil scrubber emission control 

system is offline while the soybean or the cottonseed oil extraction units 

(Source Codes: S200 and 210), or the desolventizer and toaster units (Source 

Code: S250) are in operation.

iv. Any measurement of NOx from the specified sources firing the specified fuels 

in accordance with Condition 5.2.7 that exceeds:

Source Codes Fuel

650 natural gas 0.0363 lb/MMBtu

Emission factor

HP1 natural gas/vent gas 0.2844 lb/MMBtu

640 natural gas 0.140 lb/MMBtu

640 & 650 fuel oil/vegetable oil 0.143 lb/MMBtu

v. Any measurement of CO from the specified sources firing the specified fuels in 

accordance with Condition 5.2.7 that exceeds:

Source Codes Fuel

650 natural gas 0.040 lb/MMBtu

Emission factor

HP1 natural gas/vent gas 0.2389 lb/MMBtu

640 natural gas 0.035 lb/MMBtu

640 & 650 fuel oil/vegetable oil 0.0357 lb/MMBtu

630 Any As calculated in Cond. 6.2.11

vi. Any time a leak, as specified in Condition 5.2.3, is not fixed within 15 calendar 

days of first discovering the leak.

vii. Any incident, wherein the ESP (Control Source ID No.: ESP 661) is not in 

operation or is bypassed while either Boiler 115A or Boiler 115B is in 

operation.

6.2 Specific Record Keeping and Reporting Requirements

6.2.1 The Permittee shall record the amount of crude vegetable oil processed at the refinery each 

calendar month. The Permittee shall calculate the 12-consecutive month cumulative crude 

oil processed each month in the refinery during the semiannual reporting period. A 

12-consecutive month total shall be defined as the sum of a reporting month's total plus the 

totals for the previous eleven consecutive months. Methods and procedures used to 

determine monthly consumption of hexane shall be approved by the Division.

[391-3-1-.02(6)(b) and 40 CFR 70.6(a)(3)(i)]
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6.2.2 For each shipment of distillate fuel oil (Numbers 1 or 2) received for combustion, in the 

boilers with Source Codes: 640, 650, 701, and 705, the Permittee shall obtain from the 

fuel supplier a statement that the fuel oil complies with the specifications for Number 2 

fuel oil as defined in ASTM D396 - Standard Specifications for Fuel Oil. Verification of 

the fuel oil supplies shall contain a statement from the owner or operator of the facility 

stating that the records of fuel supplier certifications submitted represent all of the fuel oil 

combusted during the quarter.

[391-3-1-.02(6)(b)1, 391-3-1-.03(2)(c), 40 CFR 60.48c(e,g,j), and 40 CFR 70.6(a)(3)(i)]

6.2.3 The Permittee shall maintain monthly records that specify the quantity of each fuel (natural 

gas, distillate fuel oil, and vegetable oil, as allowed per Condition 3.2.3) consumed by each 

of the following sources, unless otherwise noted.

[40 CFR 70.6(a)(3)(i) and 40 CFR 60.48c(e)(11)]

a. Natural gas, distillate fuel oil, and vegetable oil in the boilers with Source Codes: 640, 

650, and 705.

b. Natural gas and distillate fuel oil in the boiler with Source Code: 701.

c. Natural gas in the reformer (Source Code: HP1).

d. Natural gas usage in the column grain dryers (Source Codes: 009 and 010). Usage 

records can be combined for these two sources.

6.2.4 The Permittee shall monitor the charging rate of used railroad ties in the Wellons boiler 

(Source Code: 630) and ensure that the charging rate of used railroad ties does not exceed 

2.5 tons per hour.

[40 CFR 70.6(a)(3)(i) and 391-3-1-.02(6)(b)(1)]

6.2.5 The total monthly emissions of carbon monoxide (CO) due to combustion of fuel in the 

boilers with Source Codes: 630, 640, and 650, the grain dryers (Source Codes: 009 and 

010) and the reformer (Source Code: HP1) to demonstrate compliance with Condition 3.2.7 

of this permit, shall be calculated according to the following equation:

[391-3-1-.02(7)]

CO = [40 x Total Mo. Nat. Gas for SC 650 (MMft3

)] + [35 x Total Mo. Nat. Gas for SC 

640 (MMft3)] + [84 x Total Mo. Nat. Gas and Vent Gas for SC HP1 (MMft3)] + [84 x 

Total Mo. Nat. Gas for Grain dryers SCs 009 and 010 (MMft3)] + [5 x Total Mo. #2 Fuel 

Oil and Vegetable oil for SCs 640 and 650 (Mgal)] + [Total Mo. CO (lbs) for SC 630 

calculated per Condition 6.2.6]

Each month, the Permittee shall calculate the cumulative total CO emissions for the last 

twelve consecutive months. The cumulative totals include the total amount of CO 

emissions during the current month plus the cumulative total CO emissions in the previous 

eleven consecutive months. Should subsequent tests determine that the emission factors are 

different from those used in the above equation, the Permit may be amended to modify the 

factors in accordance with normal permitting procedures.
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These emission factor records shall be available for inspection or submittal to the Division 

and shall be retained for a period of five years following the date of record.

6.2.6 The monthly carbon monoxide (CO) emission rate for the Wellons boiler with Source 

Code: 630 shall be calculated as follows:

[391-3-1-.02(7)]

Z

Monthly CO Emissions = Σ (XN/6)*[5.890 - (XN)*0.0867]

N=1

Where:

N = any 10 minute period during the calendar month when the boiler is generating steam;

Z = number of such 10 minute periods in the calendar month of record; and

X = amount of steam generated (in 1000 lbs per hour) during the Nth period.

The monthly CO emissions calculated from this condition shall be entered into the facility 

wide CO emissions equation in Condition 6.2.5.

6.2.7 The total monthly emissions of nitrogen oxides (NOx) in pounds due to the combustion of 

fuel in the boilers with Source Codes: 630, 640, and 650; the grain dryers (Source Codes: 

009 and 010); and the reformer (Source Code: HP1) shall be calculated according to the 

following equation to demonstrate compliance with Condition 3.2.6:

[391-3-1-.02(7)]

NOx = [36.3 x Total Mo. Nat. Gas for SC 650 (MMft3

)] + [140 x Total Mo. Nat. Gas for 

SC 640 (MMft3)] + [100 x Total Mo. Nat. Gas and Vent Gas for SC HP1 (MMft3)] + [100 x 

Total Mo. Nat. Gas for Grain dryers SCs 009 and 010 (MMft3

)] + [20 x Total Mo. #2 Fuel 

Oil and Vegetable oil for SCs 640 and 650 (Mgal)] + [0.456 x Total Mo. Steam Production 

for SC 630 (Mlbs)]

Each month, the Permittee shall calculate the cumulative total NOx emissions for the last 

twelve-consecutive months. The cumulative totals include the total amount of NOx 

emission during the current month plus the cumulative total NOx emission in the last 

eleven consecutive months. Should subsequent tests determine that the emission factors are 

different from those used in the above equation, the Permit may be amended to modify the 

factors in accordance with normal permitting procedures. Such emission factor records 

shall be kept available for inspection or submittal to the Division and shall be retained for a 

period of five years following the date of record.
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6.2.8 The Permittee shall maintain daily and monthly records of the amount of soybeans 

processed through the facility including the column grain dryers (Source Codes: 009 and 

010). The daily records shall be used to determine compliance with Conditions 2.1.1 and 

3.2.1. Each month the Permittee shall calculate the cumulative total of the soybeans 

processed through the column grain dryers (Source Codes: 009 and 010) and the amount of 

soybeans processed through the facility in the last twelve-consecutive months. The 

cumulative totals include the total amount processed during the current month plus the 

cumulative amounts processed in the last eleven consecutive months.

[40 CFR 70.6(a)(3)(i) and 391-3-1-.02(6)(b)(1)]

6.2.9 The Permittee shall maintain monthly records of operating hours of Seed Receiving (Source 

Code: C010), the Seedhouses (Source Codes: C030, C040, C050, C060, C070, and C080), 

the Clay Tank (Source Code: C435), Meal Loadout (Source Code: C440), White Seed 

Truck Loadout (Source Code: C450), and White Seed/Hull Rail and Truck Loadout (Source 

Code: C460). The records shall be used to determine compliance with the hours of 

operation limitations in Condition 3.2.4. Each month the Permittee shall calculate the 

cumulative hours of operation of each source listed above in the last twelve consecutive 

months. The cumulative totals include the hours of operation during the current month plus 

the cumulative amounts in the previous eleven consecutive months.

[40 CFR 70.6(a)(3)(i) and 391-3-1-.02(6)(b)(1)]

6.2.10 The Permittee shall maintain records of each shipment of clay received for loading in the 

Clay Storage Bin (Source Code: 340) and the Bleaching Clay Receiving Bin (Source Code: 

710). The records shall include a copy of the shipping receipts indicating the date of 

receipt, the quantity of clay received, and the silo into which it was loaded (Source Codes: 

340 and 710) for demonstrating compliance with Condition 3.2.2.

[40 CFR 70.6(a)(3)(i) and 391-3-1-.02(6)(b)(1)]

6.2.11 To demonstrate compliance with Condition 3.3.1, the Permittee shall maintain daily records 

of each shipment of hexane and crude vegetable oil received, daily system hexane losses, 

daily cottonseeds processed, and daily soybeans processed. The daily hexane shipment 

records shall contain the name and address of the hexane supplier. The daily crude 

vegetable oil records shall contain the name and address of the crude vegetable oil supplier.

a. The daily consumption of hexane per ton of soybeans processed shall be calculated 

using the following equation:

DHCS (gal/ton) = 

SP

HRS + HCOR +SHLS

Where,

DHCS = Daily Hexane Consumption (gallons of hexane consumed per ton of soybeans);

HRS = Hexane Receipts Soybean (gallons per day);

HCOR = Hexane in Crude Oil Receipts (gallons per day);

SHLS = System Hexane Losses Soybeans, which is the daily total change in hexane storage 

inventory for the soybean process (gallons per day); and

SP = Amount of soybeans processed daily (tons per day).
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Page 36 of 61 

HCOR = 

5.63

(CORCS x CSPPM) + (CORNC x 400)

Where,

HCOR = Hexane in Crude Oil Receipts (gallons per day);

CORCS = Crude Oil Receipts included in Composite Sample (million pounds per day);

CSPPM = Composite Sample PPM (ppm hexane); and

CORNC = Crude Oil Receipts Not in Composite sample (million pounds per day).

b. The daily consumption of hexane per ton of cottonseed processed shall be calculated 

using the following equation:

DHCC (gal/ton) = 

CP

HRC + SHLC

Where,

DHCC = Daily Hexane Consumption Cottonseed (gallons of hexane consumed per ton of 

cottonseed);

HRC = Hexane Receipts Cottonseed (gallons per day);

SHLC = System Hexane Losses Cottonseed, which is the daily total change in hexane 

storage inventory for the cottonseed process (gallons per day); and

CP = Amount of cottonseed processed daily (tons per day).

c. The daily consumption of hexane per ton of soybeans and cottonseeds processed shall 

be calculated using the following equation:

DHC (lbs/ton) = (

CP + SP

DHCS + DHCC) x 5.63

Where,

DHC = Daily Hexane Consumption (pounds of hexane consumed per ton of soybeans and 

cottonseed);

DHCS = Daily Hexane Consumption Soybeans (gallons of hexane consumed per ton of

soybeans);

DHCC = Daily Hexane Consumption Cottonseed (gallons of hexane consumed per ton of 

cottonseed);

SP = Amount of soybeans processed daily (tons per day); and

CP = Amount of cottonseed processed daily (tons per day).

All calculations used to compute the hexane consumption, as well as the receipts, shall be 

kept as part of the daily record. These records shall be used to compute the 12-month (365-

day) rolling average hexane consumption by the facility, expressed as pounds hexane 

consumed per ton of soybean and cottonseed processed, computed daily. These records 

shall be available for inspection or submittal to the Division and shall be kept for a period 

of five years following the last date of record.

[40 CFR 70.6(a)(3)(i) and 391-3-1-.02(6)(b)(1)]
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Page 37 of 61 

6.2.12 The Permittee shall submit to the Division a quarterly report, within 30 days following the 

end of each calendar quarter, regarding distillate fuel oil purchases and the firing of such oil 

in the boilers with Source Codes: 701 and 705. The report shall contain:

a. The name of each fuel oil supplier and a statement from each supplier certifying that 

the fuel oil complies with Condition 3.3.2.

b. A certified statement signed by the Permittee that the records of fuel oil supplier 

certifications, submitted in accordance with paragraph a of this condition, represent 

all of the fuel oil fired in the boiler during the quarter.

The report shall so note when the Permittee did not combust fuel oil in any of these 

boilers.

[391-3-1-.02(6)(b)1 and 40 CFR 60.48c(e)(11)]

6.2.13 [Reserved]

6.2.14 The Permittee shall calculate the Compliance Ratio (CR) for Soybean and Cottonseed oil 

processing units. The Compliance Ratio is defined in the Vegetable Oil MACT at 40 CFR 

63.2840 (Subpart GGGG).

[40 CFR 63.2840]

6.2.15 The Permittee shall submit the following reports required by the vegetable oil MACT:

[40 CFR 63.2861]

a. Annual compliance certifications in accordance with §63.2861(a).

b. Deviation notification report in accordance with §63.2861(b) for each compliance 

determination in which the compliance ratio exceeds 1.00 as determined, per 

§63.2840(c).

c. Periodic startup, shutdown, and malfunction reports in accordance with §63.2861(c).

d. Immediate startup, shutdown, and malfunction reports in accordance with 

§63.2861(d).

e. The Permittee shall submit all notifications and reports and maintain all records 

required by the General Provisions for performance testing, if the Permittee adds a 

control device that destroys the extraction solvent.
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Page 38 of 61 

6.2.16 The Permittee shall record and maintain records of the amounts of each fuel, including fuel 

type, combusted during each day in each boiler with Source Codes: B115A and B115B, as 

required by Permit Condition 5.2.2.f. The records shall be kept for a period of five years 

from the date of generation. The quantity of fuel burned monthly in each boiler with 

Source Codes: B115A and B115B shall be reported in the semiannual report required by 

Permit Condition 6.1.4.

[40 CFR 60.48c(g)]

6.2.17 The Permittee shall use the records required in Permit Condition 6.2.16 to calculate 

combined total monthly VOC emissions from the boilers with Source Codes: B115A and 

B115B. All demonstration calculations, including any Division-approved emission factor, 

used in the calculations, shall be kept as part of the records required in Condition 6.2.16. 

The Permittee shall notify the Division in writing if the combined total monthly VOC 

emission exceeds 3.3 tons during any calendar month. This notification shall be 

postmarked by the fifteenth day of the following month and shall include an explanation of 

how the Permittee intends to maintain compliance with the emission limit in Permit 

Condition 3.2.12.

[391-3-1-.02(6)(b)1, 391-3-1.03(2)(c), Avoidance of 40 CFR 52.21]

6.2.18 The Permittee shall use the monthly VOC emission data required in Permit Condition 

6.2.17 to calculate the combined 12-month rolling total of VOC emissions from the boilers 

with Source Codes: B115A and B115B for each calendar month. The Permittee shall 

notify the Division in writing if the combined 12-month rolling total of VOC emissions 

equals or exceeds 39 tons. This notification shall be postmarked by the fifteenth day of the 

following month and shall include an explanation of how the Permittee intends to attain 

compliance with the emission limit in Condition 3.2.12.

[391-3-1-.02(6)(b)1, 391-3-1.03(2)(c), and Avoidance of 40 CFR 52.21]

6.2.19 The Permittee shall use the following equations when calculating the monthly VOC 

emissions from the boilers with Source Codes: B115A and B115B. All calculations shall 

be kept as part of the monthly record. These records shall be kept available for inspection 

by or submittal to the Division for five years from the date of record.

[391-3-1-.02(6)(b)1 and 391-3-1-.03(2)(c)]

a. VOCB115A (lbs) = VOCB115A EF (lbs/ton wood waste burned) * Wood Waste 

BurnedB115A (tons/month); and

b. VOCB115B (lbs) = VOCB115B EF (lbs/ton wood waste burned) * Wood Waste 

BurnedB11B (tons/month); and

c. Total VOC (lbs) = VOCB115A (lbs) + VOCB115B (lbs) 

Where:

VOCB115A (lbs) = the monthly VOC emissions from Boiler 115A.

VOCB115A EF = the VOC Emission Factor for Boiler 115A.
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Page 39 of 61 

Wood Waste BurnedB115A = the amount of wood waste combusted in Boiler 115A 

determined from records required by Permit Condition 6.2.16.

VOCB115B (lbs) = the monthly VOC emissions from Boiler 115B.

VOCB115B EF = the VOC Emission Factor for Boiler 115B.

Wood Waste BurnedB115B = the amount of wood waste combusted in Boiler 115B 

determined from records required by Permit Condition 6.2.16.

6.2.20 The Permittee shall use the records required in Permit Condition 6.2.16 to calculate 

combined total monthly fluoride emissions from the boilers with Source Codes: B115A and 

B115B. All demonstration calculations, including any Division-approved emission factor, 

used in the calculations, shall be kept as part of the records required in Condition 6.2.16. 

The Permittee shall notify the Division in writing if the combined total monthly flouride 

emissions exceed 0.17 tons during any calendar month. This notification shall be 

postmarked by the fifteenth day of the following month and shall include an explanation of 

how the Permittee intends to maintain compliance with the emission limit in Permit 

Condition 3.2.13.

[391-3-1-.02(6)(b)1, 391-3-1.03(2)(c), and Avoidance of 40 CFR 52.21]

6.2.21 The Permittee shall use the monthly fluoride emission data required in Permit Condition 

6.2.20 to calculate the combined 12-month rolling total of flouride emissions from the 

boilers with Source Codes: B115A and B115B for each calendar month. The Permittee 

shall notify the Division in writing if the combined 12-month rolling total of flouride 

emissions equals or exceeds 2 tons. This notification shall be postmarked by the fifteenth 

day of the following month and shall include an explanation of how the Permittee intends 

to attain compliance with the emission limit in Condition 3.2.13.

[391-3-1-.02(6)(b)1, 391-3-1.03(2)(c), and Avoidance of 40 CFR 52.21]

6.2.22 The Permittee shall use the following equations when calculating the monthly flouride 

emissions from the boilers with Source Codes: B115A and B115B. All calculations shall 

be kept as part of the monthly record. These records shall be kept available for inspection 

by or submittal to the Division for five years from the date of record.

[391-3-1-.02(6)(b)1 and 391-3-1-.03(2)(c)]

a. FB115A (lbs) = FB115A EF (lbs/ton wood waste burned) * Wood Waste BurnedB115A 

(tons/month); and

b. FB115B (lbs) = FB115B EF (lbs/ton wood waste burned) * Wood Waste BurnedB115B 

(tons/month); and

c. Total F (lbs) = FB115A (lbs) + FB115B (lbs).

Where:

FB115A (lbs) = the monthly fluoride emissions from Boiler 115A.
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Page 40 of 61 

FB115A EF = the Fluoride Emission Factor for Boiler 115A.

Wood Waste BurnedB115A = the amount of wood waste combusted in Boiler 115A 

determined from records required by Permit Condition 6.2.16.

FB115B (lbs) = the monthly fluoride emissions from Boiler 115B.

FB115B EF = the Fluoride Emission Factor for Boiler 115B.

Wood Waste BurnedB115B = the amount of wood waste combusted in Boiler 115B 

determined from records required by Permit Condition 6.2.16.

6.2.23 The Permittee shall use the records required in Permit Condition 6.2.16 to calculate 

combined total monthly sulfuric acid mist emissions from the boilers with Source Codes: 

B115A and B115B. All demonstration calculations, including any Division-approved 

emission factor, used in the calculations, shall be kept as part of the records required in 

Condition 6.2.16. The Permittee shall notify the Division in writing if the combined total 

monthly sulfuric acid mist emissions exceed 0.5 tons during any calendar month. This 

notification shall be postmarked by the fifteenth day of the following month and shall 

include an explanation of how the Permittee intends to maintain compliance with the 

emission limit in Permit Condition 3.2.14.

[391-3-1-.02(6)(b)1, 391-3-1.03(2)(c), and Avoidance of 40 CFR 52.21]

6.2.24 The Permittee shall use the monthly sulfuric acid mist emission data required in Permit 

Condition 6.2.23 to calculate the combined 12-month rolling total of sulfuric acid mist 

emissions from the boilers with Source Codes: B115A and B115B for each calendar month. 

The Permittee shall notify the Division in writing if the combined 12-month rolling total of 

sulfuric acid mist emissions equals or exceeds 6 tons. This notification shall be postmarked 

by the fifteenth day of the following month and shall include an explanation of how the 

Permittee intends to attain compliance with the emission limit in Condition 3.2.14.

[391-3-1-.02(6)(b)1, 391-3-1.03(2)(c), and Avoidance of 40 CFR 52.21]

6.2.25 The Permittee shall use the following equations when calculating the monthly sulfuric acid 

mist emissions from the boilers with Source Codes: B115A and B115B. All calculations 

shall be kept as part of the monthly record. These records shall be kept available for 

inspection by or submittal to the Division for five years from the date of record.

[391-3-1-.02(6)(b)1 and 391-3-1-.03(2)(c)]

a. SAMB115A (lbs)= SAMB115A EF (lbs/ton wood waste burned) * Wood Waste 

BurnedB115A (tons/month); and

b. SAMB115B (lbs) = SAMB115B EF (lbs/ton wood waste burned) * Wood Waste 

BurnedB11B (tons/month); and

c. Total SAM (lbs) = SAMB115A (lbs) + SAMB115B (lbs).

Where:
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Page 41 of 61 

SAMB115A (lbs) = the monthly sulfuric acid mist emissions from Boiler 115A.

SAMB115A EF = the Sulfuric Acid Mist Emission Factor for Boiler 115A.

Wood Waste BurnedB115A = the amount of wood waste combusted in Boiler 115A 

determined from records required by Permit Condition 6.2.16.

SAMB115B (lbs) = the monthly sulfuric acid mist emissions from Boiler 115B.

SAMB115B EF = the sulfuric acid mist Emission Factor for Boiler 115B.

Wood Waste BurnedB115B = the amount of wood waste combusted in Boiler 115B 

determined from records required by Permit Condition 6.2.16.

6.2.26 The Permittee shall use the records required in Permit condition 6.2.16 to calculate 

combined total monthly sulfur dioxide emissions from the boilers with Source Codes: 

B115A and B115B. All demonstration calculations, including any Division-approved 

emission factor, used in the calculations, shall be kept as part of the records required in 

condition 6.2.16. The Permittee shall notify the Division in writing if the combined total 

monthly sulfur dioxide emissions exceed 3.3 tons during any calendar month. This 

notification shall be postmarked by the fifteenth day of the following month and shall 

include an explanation of how the Permittee intends to maintain compliance with the 

emission limit in Permit Condition 3.2.15.

[391-3-1-.02(6)(b)1, 391-3-1.03(2)(c), and Avoidance of 40 CFR 52.21]

6.2.27 The Permittee shall use the monthly sulfur dioxide emission data required in Permit 

Condition 6.2.26 to calculate the combined 12-month rolling total of sulfur dioxide 

emissions from the boilers with Source Codes: B115A and B115B for each calendar month. 

The Permittee shall notify the Division in writing if the combined 12-month rolling total of 

sulfur dioxide emissions equals or exceeds 39 tons. This notification shall be postmarked 

by the fifteenth day of the following month and shall include an explanation of how the 

Permittee intends to attain compliance with the emission limit in Condition 3.2.15.

[391-3-1-.02(6)(b)1, 391-3-1.03(2)(c), and Avoidance of 40 CFR 52.21]

6.2.28 The Permittee shall use the following equations when calculating the monthly sulfur 

dioxide emissions from the boilers with Source Codes: B115A and B115B. All 

calculations shall be kept as part of the monthly record. These records shall be kept 

available for inspection by or submittal to the Division for five years from the date of 

record.

[391-3-1-.02(6)(b)1 and 391-3-1-.03(2)(c)]

a. SO2B115A (lbs) = SO2B115A EF (lbs/ton wood waste burned) * Wood Waste 

BurnedB115A (tons/month); and

b. SO2B115B (lbs) = SO2B115B EF (lbs/ton wood waste burned) * Wood Waste 

BurnedB11B (tons/month); and

c. Total SO2 (lbs) = SO2B115A (lbs) + SO2B115B (lbs).
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Page 42 of 61 

Where:

SO2B115A (lbs) = the monthly sulfur dioxide emissions from the boiler with Source Code: 

B115A.

SO2B115A EF = the SO2 Emission Factor for Boiler 115A.

Wood Waste BurnedB115A = the amount of wood waste combusted in Boiler 115A 

determined from records required by Permit Condition 6.2.16.

SO2B115B (lbs) = the monthly SO2 emissions from Boiler 115B.

SO2B115B EF = the SO2 Emission Factor for Boiler 115B.

Wood Waste BurnedB115B = the amount of wood waste combusted in Boiler 115B 

determined from records required by Permit Condition 6.2.16.

6.2.29 The Permittee shall submit to the Division records as required by Permit Conditions 6.2.19, 

6.2.22, 6.2.25, and 6.2.28 in the semiannual report required by Permit Condition 6.1.4.

[391-3-1-.02(6)(b)1, 391-3-1.03(2)(c), and Avoidance of 40 CFR 52.21]

6.2.30 The Permittee shall compare the applicable wood-firing rate established per Permit 

Condition 4.2.11 with the records required by Permit Condition 6.2.16. The Permittee shall 

notify the Division in writing if the daily wood-firing rate exceeds the established woodfiring rate per Permit Condition 4.2.11. This notification shall be postmarked by the 

fifteenth day of the following month and shall include an explanation of how the Permittee 

intends to maintain compliance with the emission limit in Permit Condition 3.3.8.

6.2.31 The Permittee shall maintain all records necessary to demonstrate compliance with the 

Vegetable Oil MACT 40 CFR 63, Subpart GGGG. The Permittee shall also maintain the 

Startup, Shutdown and Malfunction Plan (SSM) and associated records at the facility and 

have it accessible to State and Federal officials upon request. The records must be retained 

for five (5) years, kept on-site for at least two years.

[40 CFR 63.2862]
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Page 43 of 61 

PART 7.0 OTHER SPECIFIC REQUIREMENTS

7.1 Operational Flexibility

7.1.1 The Permittee may make Section 502(b)(10) changes as defined in 40 CFR 70.2 without 

requiring a 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 Permittee shall provide the Division and the EPA 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 Permittee and the Division shall 

attach each such notice to their copy of this Permit.

[391-3-1-.03(10)(b)5 and 40 CFR 70.4(b)(12)(i)]

a. For each such change, the Permittee’s written notification and application for a 

construction Permit shall be submitted well in advance of any critical date (typically 

at least 3 months in advance of any commencement of construction, Permit issuance 

date, etc.) involved in the change, but no less than seven (7) 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.

b. The Permit shield described in Condition 8.16.1 shall not apply to any change made 

pursuant to this condition.

7.2 Off-Permit Changes

7.2.1 The Permittee may make changes that are not addressed or prohibited by this Permit, other 

than those described in Condition 7.2.2 below, without a Permit revision, provided the 

following requirements are met:

[391-3-1-.03(10)(b)6 and 40 CFR 70.4(b)(14)]

a. Each such change shall meet all applicable requirements and shall not violate any 

existing Permit term or condition.

b. The Permittee must provide contemporaneous written notice to the Division and to 

the EPA of each such change, except for changes that qualify as insignificant under 

Rule 391-3-1-.03(10)(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.

c. The change shall not qualify for the Permit shield in Condition 8.16.1.

d. 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.
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Page 44 of 61 

7.2.2 The Permittee shall not make, without a Permit revision, any changes that are not addressed 

or prohibited by this 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.

[Rule 391-3-1-.03(10)(b)7 and 40 CFR 70.4(b)(15)]

7.3 Alternative Requirements

[White Paper #2]

Not Applicable.

7.4 Insignificant Activities

(see Attachment B for the list of Insignificant Activities in existence at the facility at the time of 

permit issuance)

7.5 Temporary Sources

[391-3-1-.03(10)(d)5 and 40 CFR 70.6(e)]

Not Applicable.

7.6 Short-term Activities

(see Form D5 “Short Term Activities” of the Permit application and White Paper #1)

Not Applicable.

7.7 Compliance Schedule/Progress Reports

[391-3-1-.03(10)(d)3 and 40 CFR 70.6(c)(4)]

Not Applicable.

7.8 Emissions Trading

[391-3-1-.03(10)(d)1(ii) and 40 CFR 70.6(a)(10)]

Not Applicable.

7.9 Acid Rain Requirements

Not Applicable.

7.10 Prevention of Accidental Releases (Section 112(r) of the 1990 CAAA)

[391-3-1-.02(10)]

7.10.1 When and if the requirements of 40 CFR Part 68 become applicable, the Permittee shall 

comply with all applicable requirements of 40 CFR Part 68, including the following.

a. The Permittee shall submit a Risk Management Plan (RMP) as provided in 40 CFR 

68.150 through 68.185. The RMP shall include a registration that reflects all covered 

processes.
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Page 45 of 61 

b. For processes eligible for Program 1, as provided in 40 CFR 68.10, the Permittee 

shall comply with 7.10.1.a. and the following additional requirements:

i. Analyze the worst-case release scenario for the process(es), as provided in 40 

CFR 68.25; document that the nearest public receptor is beyond the distance to 

a toxic or flammable endpoint defined in 40 CFR 68.22(a); and submit in the 

RMP the worst-case release scenario as provided in 40 CFR 68.165.

ii. Complete the five-year accident history for the process as provided in 40 CFR 

68.42 and submit in the RMP as provided in 40 CFR 68.168

iii. Ensure that response actions have been coordinated with local emergency 

planning and response agencies

iv. Include a certification in the RMP as specified in 40 CFR 68.12(b)(4)

c. For processes subject to Program 2, as provided in 40 CFR 68.10, the Permittee shall 

comply with 7.10.1.a., 7.10.1.b. and the following additional requirements:

i. Develop and implement a management system as provided in 40 CFR 68.15

ii. Conduct a hazard assessment as provided in 40 CFR 68.20 through 68.42

iii. Implement the Program 2 prevention steps provided in 40 CFR 68.48 through 

68.60 or implement the Program 3 prevention steps provided in 40 CFR 68.65 

through 68.87

iv. Develop and implement an emergency response program as provided in 40 CFR 

68.90 through 68.95

v. Submit as part of the RMP the data on prevention program elements for 

Program 2 processes as provided in 40 CFR 68.170

d. For processes subject to Program 3, as provided in 40 CFR 68.10, the Permittee shall 

comply with 7.10.1.a., 7.10.1.b. and the following additional requirements:

i. Develop and implement a management system as provided in 40 CFR 68.15

ii. Conduct a hazard assessment as provided in 40 CFR 68.20 through 68.42

iii. Implement the prevention requirements of 40 CFR 68.65 through 68.87

iv. Develop and implement an emergency response program as provided in 40 CFR 

68.90 through 68.95

v. Submit as part of the RMP the data on prevention program elements for 

Program 3 as provided in 40 CFR 68.175

e. All reports and notification required by 40 CFR Part 68 must be submitted 

electronically (e.g., diskette or compact disc) to:

MAIL

Attention: RMP*Submit

Risk Management Program (RMP) Reporting Center

P.O. Box 1515

Lanham-Seabrook, MD 20703-1515
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Page 46 of 61 

COURIER & FEDEX

Risk Management Program (RMP) Reporting Center

C/O CSC

Suite 300

8400 Corporate Drive

New Carrollton, MD 20785

Compliance with all requirements of this condition, including the registration and 

submission of the RMP, shall be included as part of the compliance certification submitted 

in accordance with Condition 8.14.1.

7.11 Stratospheric Ozone Protection Requirements (Title VI of the CAAA of 1990)

7.11.1 If the Permittee performs any of the activities described below or as otherwise defined in 40 

CFR Part 82, the Permittee shall comply with the standards for recycling and emissions 

reduction pursuant to 40 CFR Part 82, Subpart F, except as provided for motor vehicle air 

conditioners (MVACs) in Subpart B:

a. Persons opening appliances for maintenance, service, repair, or disposal must comply 

with the required practices pursuant to 40 CFR 82.156.

b. Equipment used during the maintenance, service, repair, or disposal of appliance must 

comply with the standards for recycling and recovery equipment pursuant to 40 CFR 

82.158.

c. Persons performing maintenance, service, repair, or disposal of appliances must be 

certified by an approved technician certification program pursuant to 40 CFR 82.161.

d. Persons disposing of small appliances, MVACs, and MVAC-like appliances must 

comply with record keeping requirements pursuant to 40 CFR 82.166.

[Note: “MVAC-like appliance” is defined in 40 CFR 82.152.]

e. Persons owning commercial or industrial process refrigeration equipment must 

comply with the leak repair requirements pursuant to 40 CFR 82.156.

f. Owners/operators of appliances normally containing 50 or more pounds of refrigerant 

must keep records of refrigerant purchased and added to such appliances pursuant to 

40 CFR 82.166.

7.11.2 If the Permittee performs a service on motor (fleet) vehicles and if this service involves an 

ozone-depleting substance (refrigerant) in the MVAC, the Permittee is subject to all the 

applicable requirements as specified in 40 CFR Part 82, Subpart B, Servicing of Motor 

Vehicle Air Conditioners.
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Page 47 of 61 

The term “motor vehicle” as used in Subpart B does not include a vehicle in which final 

assembly of the vehicle has not been completed. The term “MVAC” as used in Subpart B 

does not include air-tight sealed refrigeration systems used for refrigerated cargo, or air 

conditioning systems on passenger buses using HCFC-22 refrigerant.

7.12 Revocation of Existing Permits and Amendments

The following Air Quality Permits, Amendments, and 502(b)10 are subsumed by this permit and are 

hereby revoked:

Air Quality Permit and Amendment Number(s) Dates of Original Permit or Amendment Issuance 

2075-185-0051-V-01-0 January 9, 2003

2075-185-0051-V-01-1 July 14, 2003

2075-185-0051-V-01-2 October 12, 2004

2075-185-0051-V-01-3 December 8, 2004

2075-185-0051-V-01-4 February 16, 2005

2075-185-0051-V-01-5 May 3, 2006

2075-185-0051-V-01-6 September 19, 2006

2075-185-0051-V-01-7 January 10, 2007

7.13 Pollution Prevention

Not Applicable.

7.14 Specific Conditions

Not Applicable.
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Page 48 of 61 

PART 8.0 GENERAL PROVISIONS

8.1 Terms and References

8.1.1 Terms not otherwise defined in the Permit shall have the meaning assigned to such terms in 

the referenced regulation.

8.1.2 Where more than one condition in this Permit applies to an emission unit and/or the entire 

facility, each condition shall apply and the most stringent condition shall take precedence.

[391-3-1-.02(2)(a)2]

8.2 EPA Authorities

8.2.1 Except as identified as “State-only enforceable” requirements in this Permit, all terms and 

conditions contained herein shall be enforceable by the EPA and citizens under the Clean 

Air Act, as amended, 42 U.S.C. 7401, et seq.

[40 CFR 70.6(b)(1)]

8.2.2 Nothing in this Permit shall alter or affect the authority of the EPA to obtain information 

pursuant to 42 U.S.C. 7414, “Inspections, Monitoring, and Entry.”

[40 CFR 70.6(f)(3)(iv)]

8.2.3 Nothing in this Permit shall alter or affect the authority of the EPA to impose emergency 

orders pursuant to 42 U.S.C. 7603, “Emergency Powers.”

[40 CFR 70.6(f)(3)(i)]

8.3 Duty to Comply

8.3.1 The Permittee shall comply with all conditions of this operating Permit. Any Permit 

noncompliance constitutes a violation of the Federal Clean Air Act and the Georgia Air 

Quality Act and/or State rules and is grounds for enforcement action; for Permit 

termination, revocation and reissuance, or modification; or for denial of a Permit renewal 

application. Any noncompliance with a Permit condition specifically designated as 

enforceable only by the State constitutes a violation of the Georgia Air Quality Act and/or 

State rules only and is grounds for enforcement action; for Permit termination, revocation 

and reissuance, or modification; or for denial of a Permit renewal application.

[391-3-1-.03(10)(d)1(i) and 40 CFR 70.6(a)(6)(i)]

8.3.2 The Permittee shall not use as a defense in an enforcement action the contention that it 

would have been necessary to halt or reduce the Permitted activity in order to maintain 

compliance with the conditions of this Permit.

[391-3-1-.03(10)(d)1(i) and 40 CFR 70.6(a)(6)(ii)]

8.3.3 Nothing in this Permit shall alter or affect the liability of the Permittee for any violation of 

applicable requirements prior to or at the time of Permit issuance.

[391-3-1-.03(10)(d)1(i) and 40 CFR 70.6(f)(3)(ii)]
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8.3.4 Issuance of this Permit does not relieve the Permittee from the responsibility of obtaining 

any other permits, licenses, or approvals required by the Director or any other federal, state, 

or local agency.

[391-3-1-.03(10)(e)1(iv) and 40 CFR 70.7(a)(6)]

8.4 Fee Assessment and Payment

8.4.1 The Permittee shall calculate and pay an annual Permit fee to the Division. The amount of 

fee shall be determined each year in accordance with the “Procedures for Calculating Air 

Permit Fees.”

[391-3-1-.03(9)]

8.5 Permit Renewal and Expiration

8.5.1 This Permit shall remain in effect for five (5) years from the effective date. The Permit 

shall become null and void after the expiration date unless a timely and complete renewal 

application has been submitted to the Division at least six (6) months, but no more than 

eighteen (18) months prior to the expiration date of the Permit.

[391-3-1-.03(10)(d)1(i), (e)2, and (e)3(ii) and 40 CFR 70.5(a)(1)(iii)]

8.5.2 Permits being renewed are subject to the same procedural requirements, including those for 

public participation and affected State and EPA review, that apply to initial Permit 

issuance.

[391-3-1-.03(10)(e)3(i)]

8.5.3 Notwithstanding the provisions in 8.5.1 above, if the Division has received a timely and 

complete application for renewal, deemed it administratively complete, and failed to reissue 

the Permit for reasons other than cause, authorization to operate shall continue beyond the 

expiration date to the point of Permit modification, reissuance, or revocation.

[391-3-1-.03(10)(e)3(iii)]

8.6 Transfer of Ownership or Operation

8.6.1 This Permit is not transferable by the Permittee. Future owners and operators shall obtain a 

new Permit from the Director. The new Permit may be processed as an administrative 

amendment if no other change in this Permit is necessary, and provided that a written 

agreement containing a specific date for transfer of Permit responsibility coverage and 

liability between the current and new Permittee has been submitted to the Division at least 

thirty (30) days in advance of the transfer.

[391-3-1-.03(4)]

8.7 Property Rights

8.7.1 This Permit shall not convey property rights of any sort, or any exclusive privileges.

[391-3-1-.03(10)(d)1(i) and 40 CFR 70.6(a)(6)(iv)]
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8.8 Submissions

8.8.1 Reports, test data, monitoring data, notifications, annual certifications, and requests for 

revision and renewal shall be submitted to:

Georgia Department of Natural Resources

Environmental Protection Division

Air Protection Branch

Atlanta Tradeport, Suite 120

4244 International Parkway

Atlanta, Georgia 30354-3908

8.8.2 Any records, compliance certifications, and monitoring data required by the provisions in 

this Permit to be submitted to the EPA shall be sent to:

Air and EPCRA Enforcement Branch – U. S. EPA Region 4

Sam Nunn Atlanta Federal Center

61 Forsyth Street, SW

Atlanta, Georgia 30303-3104

8.8.3 Any application form, report, or compliance certification submitted pursuant to this Permit 

shall contain a certification by a responsible official of its truth, accuracy, and 

completeness. This certification shall state that, based on information and belief formed 

after reasonable inquiry, the statements and information in the document are true, accurate, 

and complete.

[391-3-1-.03(10)(c)2, 40 CFR 70.5(d) and 40 CFR 70.6(c)(1)]

8.8.4 Unless otherwise specified, all submissions under this permit shall be submitted to the 

Division only.

8.9 Duty to Provide Information

8.9.1 The Permittee, upon becoming aware that any relevant facts were omitted or incorrect 

information was submitted in the Permit application, shall promptly submit such 

supplementary facts or corrected information to the Division.

[391-3-1-.03(10)(c)5]

8.9.2 The Permittee shall furnish to the Division, in writing, information that the Division may 

request to determine whether cause exists for modifying, revoking and reissuing, or 

terminating the Permit, or to determine compliance with the Permit. Upon request, the 

Permittee shall also furnish to the Division copies of records that the Permittee is required 

to keep by this Permit or, for information claimed to be confidential, the Permittee may 

furnish such records directly to the EPA, if necessary, along with a claim of confidentiality.

[391-3-1-.03(10)(d)1(i) and 40 CFR 70.6(a)(6)(v)]
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8.10 Modifications

8.10.1 Prior to any source commencing a modification as defined in 391-3-1-.01(pp) that may 

result in air pollution and not exempted by 391-3-1-.03(6), the Permittee shall submit a 

Permit application to the Division. The application shall be submitted sufficiently in 

advance of any critical date involved to allow adequate time for review, discussion, or 

revision of plans, if necessary. Such application shall include, but not be limited to, 

information describing the precise nature of the change, modifications to any emission 

control system, production capacity of the plant before and after the change, and the 

anticipated completion date of the change. The application shall be in the form of a 

Georgia air quality Permit application to construct or modify (otherwise known as a SIP 

application) and shall be submitted on forms supplied by the Division, unless otherwise 

notified by the Division. 

[391-3-1-.03(1) through (8)]

8.11 Permit Revision, Revocation, Reopening and Termination

8.11.1 This Permit may be revised, revoked, reopened and reissued, or terminated for cause by the 

Director. The Permit will be reopened for cause and revised accordingly under the 

following circumstances:

[391-3-1-.03(10)(d)1(i)]

a. If additional applicable requirements become applicable to the source and the 

remaining Permit term is one (1) year or longer. In this case, the reopening shall be 

completed no later than eighteen (18) months after promulgation of the applicable 

requirement. A reopening shall not be required if compliance with the applicable 

requirement is not required until after the date on which the Permit is due to expire;

[391-3-1-.03(10)(e)6(i)(I)]

b. If any additional applicable requirements of the Acid Rain Program become 

applicable to the source;

[391-3-1-.03(10)(e)6(i)(II)] (Acid Rain sources only)

c. The Director determines that the Permit contains a material mistake or inaccurate 

statements were made in establishing the emissions standards or other terms or 

conditions of the Permit; or

[391-3-1-.03(10)(e)6(i)(III) and 40 CFR 70.7(f)(1)(iii)]

d. The Director determines that the Permit must be revised or revoked to assure 

compliance with the applicable requirements.

[391-3-1-.03(10)(e)6(i)(IV) and 40 CFR 70.7(f)(1)(iv)]

8.11.2 Proceedings to reopen and reissue a Permit shall follow the same procedures as applicable 

to initial Permit issuance and shall affect only those parts of the Permit for which cause to 

reopen exists. Reopenings shall be made as expeditiously as practicable.

[391-3-1-.03(10)(e)6(ii)]
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8.11.3 Reopenings shall not be initiated before a notice of intent to reopen is provided to the 

source by the Director at least thirty (30) days in advance of the date the Permit is to be 

reopened, except that the Director may provide a shorter time period in the case of an 

emergency.

[391-3-1-.03(10)(e)6(iii)]

8.11.4 All Permit conditions remain in effect until such time as the Director takes final action. 

The filing of a request by the Permittee for any Permit revision, revocation, reissuance, or 

termination, or of a notification of planned changes or anticipated noncompliance, shall not 

stay any Permit condition.

[391-3-1-.03(10)(d)1(i) and 40 CFR 70.6(a)(6)(iii)]

8.11.5 A Permit revision shall not be required for changes that are explicitly authorized by the 

conditions of this Permit.

8.11.6 A Permit revision shall not be required for changes that are part of an approved economic 

incentive, marketable Permit, emission trading, or other similar program or process for 

change which is specifically provided for in this Permit.

[391-3-1-.03(10)(d)1(i) and 40 CFR 70.6(a)(8)]

8.12 Severability

8.12.1 Any condition or portion of this Permit which is challenged, becomes suspended or is ruled 

invalid as a result of any legal or other action shall not invalidate any other portion or 

condition of this Permit.

[391-3-1-.03(10)(d)1(i) and 40 CFR 70.6(a)(5)]

8.13 Excess Emissions Due to an Emergency

8.13.1 An “emergency” means any situation arising from sudden and reasonably unforeseeable 

events beyond the control of the source, including acts of God, which situation requires 

immediate corrective action to restore normal operation, and that causes the source to 

exceed a technology-based emission limitation under the Permit, due to unavoidable 

increases in emissions attributable to the emergency. An emergency shall not include 

noncompliance to the extent caused by improperly designed equipment, lack of 

preventative maintenance, careless or improper operation, or operator error.

[391-3-1-.03(10)(d)7 and 40 CFR 70.6(g)(1)]

8.13.2 An emergency shall constitute an affirmative defense to an action brought for

noncompliance with the technology-based emission limitations if the Permittee 

demonstrates, through properly signed contemporaneous operating logs or other relevant 

evidence, that:

[391-3-1-.03(10)(d)7 and 40 CFR 70.6(g)(2) and (3)]

a. An emergency occurred and the Permittee can identify the cause(s) of the emergency;

b. The Permitted facility was at the time of the emergency being properly operated;
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c. During the period of the emergency, the Permittee took all reasonable steps to 

minimize levels of emissions that exceeded the emissions standards, or other 

requirements in the Permit; and

d. The Permittee promptly notified the Division and submitted written notice of the 

emergency to the Division within two (2) working days of the time when emission 

limitations were exceeded due to the emergency. This notice must contain a 

description of the emergency, any steps taken to mitigate emissions, and corrective 

actions taken.

8.13.3 In an enforcement proceeding, the Permittee seeking to establish the occurrence of an 

emergency shall have the burden of proof.

[391-3-1-.03(10)(d)7 and 40 CFR 70.6(g)(4)]

8.13.4 The emergency conditions listed above are in addition to any emergency or upset 

provisions contained in any applicable requirement.

[391-3-1-.03(10)(d)7 and 40 CFR 70.6(g)(5)] 

8.14 Compliance Requirements

8.14.1 Compliance Certification

The Permittee shall provide written certification to the Division and to the EPA, at least 

annually, of compliance with the conditions of this Permit. The annual written certification 

shall be postmarked no later than January 30 of each year and shall be submitted to the 

Division and to the EPA. The certification shall include, but not be limited to, the 

following elements:

[391-3-1-.03(10)(d)3 and 40 CFR 70.6(c)(5)]

a. The identification of each term or condition of the Permit that is the basis of the 

certification;

b. The status of compliance with the terms and conditions of the permit for the period 

covered by the certification, including whether compliance during the period was 

continuous or intermittent, based on the method or means designated in paragraph c 

below. The certification shall identify each deviation and take it into account in the 

compliance certification. The certification shall also identify as possible exceptions 

to compliance any periods during which compliance is required and in which an 

excursion or exceedance as defined under 40 CFR Part 64 occurred;

c. The identification of the method(s) or other means used by the owner or operator for 

determining the compliance status with each term and condition during the 

certification period;

d. Any other information that must be included to comply with section 113(c)(2) of the 

Act, which prohibits knowingly making a false certification or omitting material 

information; and
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e. Any additional requirements specified by the Division.

8.14.2 Inspection and Entry

a. Upon presentation of credentials and other documents as may be required by law, the 

Permittee shall allow authorized representatives of the Division to perform the 

following:

[391-3-1-.03(10)(d)3 and 40 CFR 70.6(c)(2)]

i. Enter upon the Permittee's premises where a Part 70 source is located or an 

emissions-related activity is conducted, or where records must be kept under the 

conditions of this Permit;

ii. Have access to and copy, at reasonable times, any records that must be kept 

under the conditions of this Permit;

iii. Inspect at reasonable times any facilities, equipment (including monitoring and 

air pollution control equipment), practices, or operations regulated or required 

under this Permit; and

iv. Sample or monitor any substances or parameters at any location during 

operating hours for the purpose of assuring Permit compliance or compliance 

with applicable requirements as authorized by the Georgia Air Quality Act.

b. No person shall obstruct, hamper, or interfere with any such authorized representative 

while in the process of carrying out his official duties. Refusal of entry or access may 

constitute grounds for Permit revocation and assessment of civil penalties.

[391-3-1-.07 and 40 CFR 70.11(a)(3)(i)]

8.14.3 Schedule of Compliance

a. For applicable requirements with which the Permittee is in compliance, the Permittee 

shall continue to comply with those requirements.

[391-3-1-.03(10)(c)2 and 40 CFR 70.5(c)(8)(iii)(A)]

b. For applicable requirements that become effective during the Permit term, the 

Permittee shall meet such requirements on a timely basis unless a more detailed 

schedule is expressly required by the applicable requirement.

[391-3-1-.03(10)(c)2 and 40 CFR 70.5(c)(8)(iii)(B)]

c. Any schedule of compliance for applicable requirements with which the source is not 

in compliance at the time of Permit issuance shall be supplemental to, and shall not 

sanction noncompliance with, the applicable requirements on which it is based.

[391-3-1-.03(10)(c)2 and 40 CFR 70.5(c)(8)(iii)(C)]

8.14.4 Excess Emissions

a. Excess emissions resulting from startup, shutdown, or malfunction of any source 

which occur though ordinary diligence is employed shall be allowed provided that:

[391-3-1-.02(2)(a)7(i)]
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i. The best operational practices to minimize emissions are adhered to;

ii. All associated air pollution control equipment is operated in a manner 

consistent with good air pollution control practice for minimizing emissions; 

and

iii. The duration of excess emissions is minimized.

b. Excess emissions which are caused entirely or in part by poor maintenance, poor 

operation, or any other equipment or process failure which may reasonably be 

prevented during startup, shutdown or malfunction are prohibited and are violations 

of Chapter 391-3-1 of the Georgia Rules for Air Quality Control.

[391-3-1-.02(2)(a)7(ii)]

c. The provisions of this condition and Georgia Rule 391-3-1-.02(2)(a)7 shall apply only 

to those sources which are not subject to any requirement under Georgia Rule 391-3-

1-.02(8) – New Source Performance Standards or any requirement of 40 CFR, Part 

60, as amended concerning New Source Performance Standards.

[391-3-1-.02(2)(a)7(iii)]

8.15 Circumvention

8.15.1 State Only Enforceable Condition.

The Permittee shall not build, erect, install, or use any article, machine, equipment or 

process the use of which conceals an emission which would otherwise constitute a violation 

of an applicable emission standard. Such concealment includes, but is not limited to, the 

use of gaseous diluents to achieve compliance with an opacity standard or with a standard 

which is based on the concentration of the pollutants in the gases discharged into the 

atmosphere.

[391-3-1-.03(2)(c)]

8.16 Permit Shield

8.16.1 Compliance with the terms of this Permit shall be deemed compliance with all applicable 

requirements as of the date of Permit issuance provided that all applicable requirements are 

included and specifically identified in the Permit.

[391-3-1-.03(10)(d)6]

8.16.2 Any Permit condition identified as “State only enforceable” does not have a Permit shield.
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8.17 Operational Practices

8.17.1 At all times, including periods of startup, shutdown, and malfunction, the Permittee shall 

maintain and operate the source, including associated air pollution control equipment, in a 

manner consistent with good air pollution control practice for minimizing emissions. 

Determination of whether acceptable operating and maintenance procedures are being used 

will be based on any information available to the Division that may include, but is not 

limited to, monitoring results, observations of the opacity or other characteristics of 

emissions, review of operating and maintenance procedures or records, and inspection or 

surveillance of the source.

[391-3-1-.02(2)(a)10]

State Only Enforceable Condition.

8.17.2 No person owning, leasing, or controlling, the operation of any air contaminant sources 

shall willfully, negligently or through failure to provide necessary equipment or facilities or 

to take necessary precautions, cause, permit, or allow the emission from said air 

contamination source or sources, of such quantities of air contaminants as will cause, or 

tend to cause, by themselves, or in conjunction with other air contaminants, a condition of 

air pollution in quantities or characteristics or of a duration which is injurious or which 

unreasonably interferes with the enjoyment of life or use of property in such area of the

State as is affected thereby. Complying with Georgia’s Rules for Air Quality Control 

Chapter 391-3-1 and Conditions in this Permit, shall in no way exempt a person from this 

provision.

[391-3-1-.02(2)(a)1]

8.18 Visible Emissions

8.18.1 Except as may be provided in other provisions of this Permit, the Permittee shall not cause, 

let, suffer, permit or allow emissions from any air contaminant source the opacity of which 

is equal to or greater than forty (40) percent.

[391-3-1-.02(2)(b)1]

8.19 Fuel-burning Equipment

8.19.1 The Permittee shall not cause, let, suffer, permit, or allow the emission of fly ash and/or 

other particulate matter from any fuel-burning equipment with rated heat input capacity of 

less than 10 million Btu per hour, in operation or under construction on or before January 1, 

1972 in amounts equal to or exceeding 0.7 pounds per million BTU heat input.

[391-3-1-.02(2)(d)]

8.19.2 The Permittee shall not cause, let, suffer, permit, or allow the emission of fly ash and/or 

other particulate matter from any fuel-burning equipment with rated heat input capacity of 

less than 10 million Btu per hour, constructed after January 1, 1972 in amounts equal to or 

exceeding 0.5 pounds per million BTU heat input.

[391-3-1-.02(2)(d)]
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8.19.3 The Permittee shall not cause, let, suffer, permit, or allow the emission from any fuelburning equipment constructed or extensively modified after January 1, 1972, visible 

emissions the opacity of which is equal to or greater than twenty (20) percent except for 

one six minute period per hour of not more than twenty-seven (27) percent opacity.

[391-3-1-.02(2)(d)]

8.20 Sulfur Dioxide

8.20.1 Except as may be specified in other provisions of this Permit, the Permittee shall not burn 

fuel containing more than 2.5 percent sulfur, by weight, in any fuel burning source that has 

a heat input capacity below 100 million Btu's per hour.

[391-3-1-.02(2)(g)]

8.21 Particulate Emissions

8.21.1 Except as may be specified in other provisions of this Permit, the Permittee shall not cause, 

let, permit, suffer, or allow the rate of emission from any source, particulate matter in total 

quantities equal to or exceeding the allowable rates shown below. Equipment in operation, 

or under construction contract, on or before July 2, 1968, shall be considered existing 

equipment. All other equipment put in operation or extensively altered after said date is to 

be considered new equipment.

[391-3-1-.02(2)(e)]

a. The following equations shall be used to calculate the allowable rates of emission 

from new equipment:

E = 4.1P0.67; for process input weight rate up to and including 30 tons per hour.

E = 55P0.11 - 40; for process input weight rate above 30 tons per hour.

b. The following equation shall be used to calculate the allowable rates of emission from 

existing equipment:

E = 4.1P0.67

In the above equations, E = emission rate in pounds per hour, and

P = process input weight rate in tons per hour.

8.22 Fugitive Dust

[391-3-1-.02(2)(n)]

8.22.1 Except as may be specified in other provisions of this Permit, the Permittee shall take all 

reasonable precautions to prevent dust from any operation, process, handling, transportation 

or storage facility from becoming airborne. Reasonable precautions that could be taken to 

prevent dust from becoming airborne include, but are not limited to, the following:

a. Use, where possible, of water or chemicals for control of dust in the demolition of 

existing buildings or structures, construction operations, the grading of roads or the 

clearing of land;
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b. Application of asphalt, water, or suitable chemicals on dirt roads, materials, 

stockpiles, and other surfaces that can give rise to airborne dusts;

c. Installation and use of hoods, fans, and fabric filters to enclose and vent the handling 

of dusty materials. Adequate containment methods can be employed during 

sandblasting or other similar operations;

d. Covering, at all times when in motion, open bodied trucks transporting materials 

likely to give rise to airborne dusts; and

e. The prompt removal of earth or other material from paved streets onto which earth or 

other material has been deposited.

8.22.2 The opacity from any fugitive dust source shall not equal or exceed 20 percent.

8.23 Solvent Metal Cleaning 

8.23.1 Except as may be specified in other provisions of this Permit, the Permittee shall not cause, 

suffer, allow, or permit the operation of a cold cleaner degreaser unless the following 

requirements for control of emissions of the volatile organic compounds are satisfied:

[391-3-1-.02(2)(ff)1]

a. The degreaser shall be equipped with a cover to prevent escape of VOC during 

periods of non-use,

b. The degreaser shall be equipped with a device to drain cleaned parts before removal 

from the unit, 

c. If the solvent volatility is 0.60 psi or greater measured at 100 oF, or if the solvent is 

heated above 120 oF, then one of the following control devices must be used:

i. The degreaser shall be equipped with a freeboard that gives a freeboard ratio of 

0.7 or greater, or 

ii. The degreaser shall be equipped with a water cover (solvent must be insoluble 

in and heavier than water), or 

iii. The degreaser shall be equipped with a system of equivalent control, including 

but not limited to, a refrigerated chiller or carbon adsorption system.

d. Any solvent spray utilized by the degreaser must be in the form of a solid, fluid 

stream (not a fine, atomized or shower type spray) and at a pressure which will not 

cause excessive splashing, and

e. All waste solvent from the degreaser shall be stored in covered containers and shall 

not be disposed of by such a method as to allow excessive evaporation into the 

atmosphere.
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8.24 Incinerators

8.24.1 Except as specified in the section dealing with conical burners, no person shall cause, let, 

suffer, permit, or allow the emissions of fly ash and/or other particulate matter from any 

incinerator, in amounts equal to or exceeding the following:

[391-3-1-.02(2)(c)1-4]

a. Units with charging rates of 500 pounds per hour or less of combustible waste, 

including water, shall not emit fly ash and/or particulate matter in quantities 

exceeding 1.0 pound per hour.

b. Units with charging rates in excess of 500 pounds per hour of combustible waste, 

including water, shall not emit fly ash and/or particulate matter in excess of 0.20 

pounds per 100 pounds of charge.

8.24.2 No person shall cause, let, suffer, permit, or allow from any incinerator, visible emissions 

the opacity of which is equal to or greater than twenty (20) percent except for one six 

minute period per hour of not more than twenty-seven (27) percent opacity.

8.24.3 No person shall cause or allow particles to be emitted from an incinerator which are 

individually large enough to be visible to the unaided eye.

8.24.4 No person shall operate an existing incinerator unless:

a. It is a multiple chamber incinerator;

b. It is equipped with an auxiliary burner in the primary chamber for the purpose of 

creating a pre-ignition temperature of 800o

F; and

c. It has a secondary burner to control smoke and/or odors and maintain a temperature 

of at least 1500oF in the secondary chamber.

8.25 Volatile Organic Liquid Handling and Storage 

8.25.1 The Permittee shall ensure that each storage tank subject to the requirements of Rule 391-3-

1-.02(2)(vv) “Volatile Organic Liquid Handling and Storage” is equipped with submerged 

fill pipes. For the purposes of this condition and the permit, a submerged fill pipe is 

defined as any fill pipe with a discharge opening, which is within six inches of the tank 

bottom.

[391-3-1-.02(2)(vv)(1)]
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8.26 Use of Any Credible Evidence or Information

8.26.1 Notwithstanding any other provisions of any applicable rule or regulation or requirement of 

this permit, for the purpose of submission of compliance certifications or establishing 

whether or not a person has violated or is in violation of any emissions limitation or 

standard, nothing in this permit or any Emission Limitation or Standard to which it pertains, 

shall preclude the use, including the exclusive use, of any credible evidence or information, 

relevant to whether a source would have been in compliance with applicable requirements 

if the appropriate performance or compliance test or procedure had been performed.

[391-3-1-.02(3)(a)]

8.27 Diesel-Fired Internal Combustion Engines

8.27.1 The Permittee shall comply with all applicable provisions of New Source Performance 

Standards (NSPS) Federal Rule 40 CFR Part 60 Subpart A-"General Provisions" and 

Subpart IIII-“Standards for Stationary Compression Ignition Internal Combustion Engines,” 

for diesel-fired internal combustion engine(s) manufactured after April 1, 2006 or 

modified/reconstructed after July 11, 2005. Such requirements include but are not limited 

to:

[40 CFR 60.4205(b), 391-3-1-.02(8)(b)77]

a. Equip all emergency generator engines with non-resettable hour meters

b. Use only diesel fuel with a maximum sulfur content of 500 ppm (15 ppm after 

October 1, 2010) unless otherwise specified by the Division.
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Attachments

A. List of Standard Abbreviations and List of Permit Specific Abbreviations

B. Insignificant Activities Checklist, Insignificant Activities Based on Emission Levels and Generic 

Emission Groups

C. List of References
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Appendix Page 1 of 6

ATTACHMENT A

List Of Standard Abbreviations

AIRS Aerometric Information Retrieval System PM Particulate Matter

APCD Air Pollution Control Device PM-10 

(PM-10)

Particulate Matter less than 10 micrometers in 

diameter

ASTM American Society for Testing and Materials PPM (ppm) Parts per Million

BACT Best Available Control Technology PSD Prevention of Significant Deterioration

BTU British Thermal Unit RACT Reasonably Available Control Technology

CAAA Clean Air Act Amendments RMP Risk Management Plan

CEMS Continuous Emission Monitor System SIC Standard Industrial Classification

CERMS Continuous Emission Rate Monitoring System SIP State Implementation Plan

CFR Code of Federal Regulations SO2 (SO2) Sulfur Dioxide

CMS Continuous Monitoring System(s) USC United States Code

CO Carbon Monoxide VE Visible Emissions

COMS Continuous Opacity Monitor System VOC Volatile Organic Compound

dscf/dscm Dry Standard Cubic Foot / Dry Standard Cubic 

Meter

EPA United States Environmental Protection Agency

EPCRA Emergency Planning and Community Right to 

Know Act

gr Grain(s)

GPM (gpm) Gallons per minute

H2O (H2O) Water

HAP Hazardous Air Pollutant

HCFC Hydro-chloro-fluorocarbon

MACT Maximum Achievable Control Technology

MMBtu Million British Thermal Units

MMBtu/hr Million British Thermal Units per hour

MVAC Motor Vehicle Air Conditioner

MW Megawatt

NESHAP National Emission Standards for Hazardous Air 

Pollutants

NOx (NOx) Nitrogen Oxides

NSPS New Source Performance Standards

OCGA Official Code of Georgia Annotated

List of Permit Specific Abbreviations
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Appendix Page 2 of 6

ATTACHMENT B

NOTE: Attachment B contains information regarding insignificant emission units/activities and groups of generic emission 

units/activities in existence at the facility at the time of Permit issuance. Future modifications or additions of insignificant 

emission units/activities and equipment that are part of generic emissions groups may not necessarily cause this attachment 

to be updated.

INSIGNIFICANT ACTIVITIES CHECKLIST

Category Description of Insignificant Activity/Unit Quantity

Mobile Sources 1. Cleaning and sweeping of streets and paved surfaces 1

Combustion 

Equipment

1. Fire fighting and similar safety equipment used to train fire fighters or other emergency 

personnel.

2. 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:

0

i) Less than 8 million BTU/hr heat input, firing types 0, 1, 2, and/or 3 waste. 0

ii) Less than 8 million BTU/hr heat input with no more than 10% pathological (type 4) waste 

by weight combined with types 0, 1, 2, and/or 3 waste. 0

iii) Less than 4 million BTU/hr heat input firing type 4 waste.

(Refer to 391-3-1-.03(10)(g)2.(ii) for descriptions of waste types) 0

3. Open burning in compliance with Georgia Rule 391-3-1-.02 (5). 0

4. Stationary engines burning: 4

i) Natural gas, LPG, gasoline, dual fuel, or diesel fuel which are used exclusively as 

emergency generators shall not exceed 500 hours per year or 200 hours per year if subject 

to Georgia Rule 391-3-1-.02(2)(mmm).7

0

ii) Natural gas, LPG, and/or diesel fueled generators used for emergency, peaking, and/or 

standby power generation, where the combined peaking and standby power generation do 

not exceed 200 hours per year.

0

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 2,000 hours per year.

4

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. 0

Trade Operations 1. Brazing, soldering, and welding equipment, and cutting torches related to manufacturing and 

construction activities whose emissions of hazardous air pollutants (HAPs) fall below 1,000 

pounds per year.

3

Maintenance, 

Cleaning, and 

Housekeeping

1. Blast-cleaning equipment using a suspension of abrasive in water and any exhaust system (or 

collector) serving them exclusively. 0

2. Portable blast-cleaning equipment. 0

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

of clothes. 0

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

halogenated solvent. 0

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

for maintenance or decommissioning. 1

6. 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.

0

7. Cleaning operations: Alkaline phosphate cleaners and associated cleaners and burners. 0
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Appendix Page 3 of 6

INSIGNIFICANT ACTIVITIES CHECKLIST

Category Description of Insignificant Activity/Unit Quantity

Laboratories and 

Testing

1. Laboratory fume hoods and vents associated with bench-scale laboratory equipment used for 

physical or chemical analysis. 7

2. Research and development facilities, quality control testing facilities and/or small pilot projects, 

where combined daily emissions from all operations are not individually major or are support 

facilities not making significant contributions to the product of a collocated major 

manufacturing facility.

0

Pollution Control 1. Sanitary waste water 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.

0

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. 0

3. 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. 0

4. Landfills that are not subject to any standard, limitation or other requirement under Section 111 

or 112 (excluding 112(r)) of the Federal Act. 0

Industrial 

Operations

1. Concrete block and brick plants, concrete products plants, and ready mix concrete plants 

producing less than 125,000 tons per year. 0

2. 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 5 

million BTU's per hour:

0

i) Furnaces for heat treating glass or metals, the use of which do not involve molten materials 

or oil-coated parts. 0

ii) Porcelain enameling furnaces or porcelain enameling drying ovens. 0

iii) Kilns for firing ceramic ware. 0

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.

0

v) Bakery ovens and confection cookers. 0

3. 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) Activity is performed indoors; &

ii) No significant fugitive particulate emissions enter the environment; &

iii) No visible emissions enter the outdoor atmosphere.

1

4. Photographic process equipment by which an image is reproduced upon material sensitized to 

radiant energy (e.g., blueprint activity, photographic developing and microfiche). 0

5. Grain, food, or mineral extrusion processes 0

6. 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. 0

7. Equipment for the mining and screening of uncrushed native sand and gravel. 0

8. Ozonization process or process equipment. 0

9. Electrostatic powder coating booths with an appropriately designed and operated particulate 

control system. 0

10. 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. 2

11. Equipment used exclusively for the mixing and blending water-based adhesives and coatings at 

ambient temperatures. 0

12. 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. 0

13. Ultraviolet curing processes where VOC emissions are less than 5 tons per year and HAP 

emissions are less than 1,000 pounds per year. 0
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Appendix Page 4 of 6

INSIGNIFICANT ACTIVITIES CHECKLIST

Category Description of Insignificant Activity/Unit Quantity

Storage Tanks and 

Equipment

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. 0

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 that are not subject to any 

standard, limitation or other requirement under Section 111 or 112 (excluding 112(r)) of the 

Federal Act.

9

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

petroleum liquid. 0

4. 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.

0

5. 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.

0

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

550 gallons. 200

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 (0.19 psia). 20

INSIGNIFICANT ACTIVITIES BASED ON EMISSION LEVELS

Description of Emission Units / Activities Quantity

Railcar and Truck clean out 1

Waste Wood Fuel Truck Dump 1

Waste Wood Fuel Bulk Storage Pile 1

Ash Loading from Boiler Ash House to Dumpster 1
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Appendix Page 5 of 6

ATTACHMENT B (continued)

GENERIC EMISSION GROUPS

Emission units/activities appearing in the following table are subject only to one or more of Georgia Rules 391-3-1-.02 (2) (b), (e) &/or (n). Potential 

emissions of particulate matter, from these sources based on TSP, are less than 25 tons per year per process line or unit in each group. Any emissions unit 

subject to a NESHAP, NSPS, or any specific Air Quality Permit Condition(s) are not included in this table.

Description of Emissions Units / Activities

Number

of Units

(if appropriate)

Applicable Rules

Opacity

Rule (b)

PM from

Mfg Process

Rule (e)

Fugitive Dust

Rule (n)

NA NA NA NA NA

The following table includes groups of fuel burning equipment subject only to Georgia Rules 391-3-1-.02 (2) (b) & (d).Any emissions unit subject to a 

NESHAP, NSPS, or any specific Air Quality Permit Condition(s) are not included in this table.

Description of Fuel Burning Equipment Number of Units

Fuel burning equipment with a rated heat input capacity of less than 10 million BTU/hr burning only natural gas 

and/or LPG.

0

Fuel burning equipment with a rated heat input capacity of less than 5 million BTU/hr, burning only distillate fuel 

oil, natural gas and/or LPG.

0

Any fuel burning equipment with a rated heat input capacity of 1 million BTU/hr or less. 0
Title V Permit

ADM Valdosta Permit No.: 2075-185-0051-V-02-0

Appendix Page 6 of 6

ATTACHMENT C

LIST OF REFERENCES

1. The Georgia Rules for Air Quality Control Chapter 391-3-1. All Rules cited herein which begin with 391-3-1 

are State Air Quality Rules.

2. Title 40 of the Code of Federal Regulations; specifically 40 CFR Parts 50, 51, 52, 60, 61, 63, 64, 68, 70, 72, 

73, 75, 76 and 82. All rules cited with these parts are Federal Air Quality Rules.

3. Georgia Department of Natural Resources, Environmental Protection Division, Air Protection Branch, 

Procedures for Testing and Monitoring Sources of Air Pollutants.

4. Georgia Department of Natural Resources, Environmental Protection Division, Air Protection Branch, 

Procedures for Calculating Air Permit Fees.

5. Compilation of Air Pollutant Emission Factors, AP-42, Fifth Edition, Volume I: Stationary Point and Area 

Sources. This information may be obtained from EPA's TTN web site at www.epa.gov/ttn/chief/ap42.html.

6. The latest properly functioning version of EPA's TANKS emission estimation software. The software may be 

obtained from EPA's TTN web site at www.epa.gov/ttn/chief/tanks.html.

7. The Clean Air Act (42 U.S.C. 7401 et seq).

8. White Paper for Streamlined Development of Part 70 Permit Applications, July 10, 1995 (White Paper #1).

9. White Paper Number 2 for Improved Implementation of the Part 70 Operating Permits Program, March 5, 

1996 (White Paper #2).