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 (s pecify): (c) City:

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

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

A-4 (a) Technical contact (for info rmation 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 a ll 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)

### 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) "t emporary" storage

(c) "emergency" storage

[Note : In completing the remainder of the survey, y ou will be able to group information for similar storage units. See B-4 for example.]

B-4 Please provide an overview flow diagram (or blo ck flow diagram) of the grain elevator(s) at your facility. Please include pe rmanent (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 nu merical 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 ex planations on the back of this sheet or indicate in your elevator diagram.

o Temporary Storage ID: use your current designation or assign a nu merical value. If assigning a new ID, please use “T-1, T-2” format.

o Emergency Storage ID: use your current designation or assign a nu merical 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 designati on 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 numerica l 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

.FORM BPage2Please 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 2007Storage Type(P, T, E)StorageIDYear FirstUsedStorageCapacity(Bushels)2GrainStored1Through-put(actual bushels)2Weeks peryear utilizedThrough-put(actual bushels)2Weeks per yearutilizedThrough-put(actual bushels)2Weeks peryear utilizedCorn100,0002P - exampleP-11970300,000Wheat400,00050300,00050300,00050P - exampleP-21985400,000Corn400,00052400,00050400,00048T - exampleT-12004450,000Corn200,00022250,00020150,000241 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 the storageID from B-4. Fortemporary and emergency storage units, storage capacity and throughput may be estimated based on operator’s knowledge if actualdata is notavailable. For permanent storage units, throughput may be estimated based on operator’s knowledge if actual data is not available.FORM CPage1Please 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-2Please complete the following table for receiving and shipping operationsat each storage unit (orgroup of units). Use theStorage, Shipping, and Receiving ID’s provided in B-4.An example is provided.What is the Maximum LoadingRate?Receiving/ShippingIDStorage IDassociated withreceiving/shipping unitHow is Grain Received Into orShipped (Loaded) Out ofStorage?aValue UnitsAre there any addon controls for thereceiving/shipping unit (Y/N)Any qualitativeemissionsmonitoringconducted?b(Y/N)R-1P1Fixed Conveyor BeltS-1P1Fixed Conveyor BeltR-1T1Portable AugeraLoading and unloading methods include:portable augerfixed receiving pit with leg to aeration towerenmass drag conveyor unloaderportable inclined beltfixed conveyor off main complexpneumatic unloadergravity fill spoutportable conveyor with trucksor specify a different methodfront-end loadermarine legfixed drag conveyortrack hoe/clamshell unloaderfixed conveyor beltcontinuous barge unloaderbQualitative methods include opacity measurements as well as monitoring instruments (e.g. CEMS), and monitoringof parameters toindicate whether the air pollutioncontrol device is operating properly.

### FORM D – “Temporary” Storage

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

FORM D Page 1 (Please copy this sheet and comp lete 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 time s of the year. If th is 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:

### FORM D – “Temporary” Storage

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

FORM D Page 2 D-6 Describe the routine maintenance (including repai r 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., repl acement of a tarp/cover in sections, as opposed to entire replacement), indicate frequency and typical perc ent of the entire unit that is replaced.

Walls:

Floors:

Cover/Tarp:

Aeration:

Other equipment associated with st orage (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).

### 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.

### FORM F – Grain Dryers

(F-1) FACID:

FORM F  Page 1 F-  Please complete the following tabl e for grain dryers used at your facility. Use the Dryer, Storage, Shipping, and Receiv ing 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 Used 1 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 t he dryer is used; and (3) provide the year of original installation.

### 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 requi rement in your permit?

(check one) Y N

As defined in NSPS, Subpart DD, grain handling operations includ e, as an assemblage of equi pment, bucket elevators or legs (excluding legs used to unload barges or ships), sc ale 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 onl y 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 rest rictions on operational parameters such as hours, feedstock or throughput.

### 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,” pleas e 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 operations a

a As defined in NSPS, Subpart DD, grain handl ing operations include, as an assemblage of equipment, bucket elevators or legs (excluding legs used to unload barges or ships), sc ale hoppers and surge bins (garners), turn heads, scalpers, cleaners, trippers, and the headhouse and other such structures.FORM I – Add-on Pollution Control Device(I-1) FACID:FORM IPage 1If data are not available or unknown, please enter NDI-2Please complete the following table for any air pollution control devices at your facility. Please provide ID and include on processdiagram. For each unit, please provide the most recent performance data you have.An example is provided.Air Pollution ControlDevice IDType of Control [e.g., fabricfilter/baghouse; cyclone;other (specify)]Points controlledby this control(Use ID’s fromForms B, C, andD)Type of Data Available [e.g.,performance test, manufacturer’sspecs or guarantee, engineeringcalculations, other (specify)]DesignEfficiencyUnits (include whetherefficiencies are for PM,PM10PM2.5, opacity)APCD-1 exampleCycloneR-1, R-2Manufacturer’s specifications40%PMAPCD-2 exampleFabric FilterS-1Manufacturer’s specifications90%PM and PM10Make additional copies, as necessary

### FORM I – Add-on Pollution Control Device

(I-1) FACID:

FORM I   Page 2 I-3. Provide a copy of the most re cent 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 c ontrol device listed in I-2.

Inlet Flow Pressure Drop Inlet Temperature APCD ID Max Units Min Max Units Min Max o C/ o F

I-5 For each cyclone, please co mplete the following table

APCD ID Particle Density Units

### FORM I – Add-on Pollution Control Device

(I-1) FACID:

FORM I  Page 3 I-6 . For each fabric filter/baghouse, pl ease 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 te chnology and the parameters that are relevant for operation of the controlR1R2R3D1D2P2P1P3-P9R1 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 P9are the receiving and storage units associated with the dryerP3 P4P7P8P9P5 P6APCD1APCD2APCD3

# 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, I llinois 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 Con trol, 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 conditione d 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 Ti tle 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 o r 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 contain ed in or specified on the attached 61 pages.

[Signed]

Director Environmental Protection DivisionTitle V Permit

ADM Valdosta Permit No.: 2075

- 185

- 0051

- V

- 02

- 0

i 

### Table of Contents

PART 1.0 FACILITY DESCRI PTION

................................ ................................ ................................ ............. 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 Emissi on 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 REQUIREMEN TS 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 Standa rds 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 Oper ational 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 Requir ements

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

................................ .......... 44
7.11 Stratospheric Ozone Protection Requir ements (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

................................ ................................ ................................ ............ 49Title 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 Sul fur 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 ReferencesTitle V Permit

ADM Valdosta Permit No.: 2075

- 185

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- V

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P age 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 f acility 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 C ompany, 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 bin s. 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 ar e 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 dehull ed 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 veget able 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 conve yed in a vapor tight conveyor to the soybean desolventizer

- toaster

- dryer

cooler (DTDC).Title V Permit

ADM Valdosta Permit No.: 2075

- 185

- 0051

- V

- 02

- 0

P age 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 th e 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 i n 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 sol ution 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 MM Btu/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 (S ource 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 s oybean 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 o il 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

P age 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 co nsists 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 boi l 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 evaporator s 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 con sists 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 firs t

- 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 re moved 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 operatio n to the first

- cut delinters.Title V Permit

ADM Valdosta Permit No.: 2075

- 185

- 0051

- V

- 02

- 0

P age 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, th rough 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 w ill 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) th rough (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 t he 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

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P age 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
Emi ssion Cap or Operating Limit

None applicable.Title V Permit

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P age 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 pe rmit 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)
N o. 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, Coole r) 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
Cond enser

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
ScrubberTitle V Permit

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P age 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 Re ceiving 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

C08 0 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 FilterTitle V Permit

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P age 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

C16 0 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

C19 0 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 He xane 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 G GGG
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 NATitle V Permit

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P age 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 52.2 1 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, Subpar t 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

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- .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

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- .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

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P age 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 Perm ittee 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 boile r (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
recircu lated 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 rate s 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)

-- 87 60 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

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P age 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: 63 0), 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 (NO
x ) emissions in excess of 106.80 tons during any twelve cons ecutive 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 (NO
x ) emissions in excess of 0.456 pounds of NO
x per thousand pounds of steam generated. [PSD avoidance and 391

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- .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 (SO 2 ) shall not equal or exceed 40.62 tons during any consecutive twelve months. The consum ption of fuel and vegetable oil shall not exceed 1,120,000 gallons during any twelve consecutive months. [PSD avoidance and 391

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- .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

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- .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 0.27Title V Permit

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P age 12 of 61 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 Bleachin g 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 sh all 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

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- .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

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- .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, suffe r, permit or allow the emission of fluoride from: [ Avoidance of 40 CFR 52.21 and 391

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- .03(2)(c)]

a. Either Boiler 115A or Boiler 115B in amounts equal to or exceeding 0.004 lbs/MMBTU, andTitle V Permit

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P age 13 of 61 b. Both Boiler 115A and Boiler 115B in amounts equal to or exc eeding 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

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- .03(2)(c)]

a. Either Boiler 115A or Boiler 115B in amounts e qual 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

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- .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

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- .03(2)(c); and 391

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- .02(2)(g) subsumed ]

3.3 Equipment Fed eral 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 h exane 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 o il 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

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P age 14 of 61 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, Sub part Dc

- "Standards of Performance for Small Industrial

- Commercial

Institutional 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) s hall 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, Sta ck 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

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- .02(2)(d)(3) subsumed]

a. Either Boiler 115A or Boiler 115B, any visible emissions of which the opa city 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 f rom: [ 40 CFR 60.43c(b)1 and 391

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- .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 Permitte e 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 e xceeding 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

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P age 15 of 61 3.3.9 The Permittee shall not cause, let, suffer, pe rmit 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 O 2 (3

- test run average), and

b. Both Boiler 115A and Boiler 115B, in am ounts equal to or exceeding 400 ppm by volume on a dry basis corrected to seven percent O 2 (3

- test run average).

The emission limits listed in this permit condition apply during all times of operation, including startup, shutdown, and malfunction. [PSD, 4 0 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

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- .03(2)(c)]

3.3.11 The Permittee shal l 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 excee ding 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 B oiler 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

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- .02(2)(b)]

3.4.2 The Permittee shall not discharge, or cause the discharge, into the atmos phere, from the soybean extraction processing equipment, particulate emissions (PM) in excess of the rate derived from the following equations:Title V Permit

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P age 16 of 61 a. E = 4.1 × P 0.67 for process input weight rate up to and including 30 tons per hour.

b. E = 55 × P 0.11

– 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 ho ur. [391

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- .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 × P 0.67 for process input weight rate up to and including 30 tons per hour.

b. E = 55 × P 0.11

– 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 ho ur. [391

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- .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

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

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- .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 × P 0.67 for process input weight rate up to and including 30 tons per hour.

b. E = 55 × P 0.11

– 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 ho ur. [391

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- .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

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P age 17 of 61 3.5 Equipment Stan dards 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 contr ol 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

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- .02(2)(a)10 and 391

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- .03(2)(c)]

3.5.2 The Permittee shall maintain an inventory of the fi lter bags such that an adequate supply of the clean bags is on hand to replace any defective bags in each baghouse. [391

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- .02(2)(a)10 and 391

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P age 18 of 61 PART 4.0 REQUIREMENTS FOR TESTING

4.1 General Testing Requirements

4.1.1 The Permittee sh all 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

t ests shall be performed and conducted using methods and procedures that have been previously specified or approved by the Division. [391

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- .02(6)(b)1(i)]

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

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- .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 d etermination 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. Metho d 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, o r 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
det ermination of opacity.

i. Method 10 or Method 10B for the determination of carbon monoxide concentration. [40 CFR 52.21]Title V Permit

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P age 19 of 61 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 (O 2 ) and carbon dioxide (CO 2 ) co ncentrations. 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 Bo iler 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

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P age 20 of 61 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

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- .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 completio n of said testing. [391

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- .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 thirt y

- six month intervals thereafter. The test results shall be submitted to the Division within 60 days of the completion of said testing. [391

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- .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 perfor mance tests shall be submitted to the Division within 60 days of the completion of the testing. [391

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- .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 la ter 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 testi ng. [391

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- .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 gr eater than the emission factors used to support the permitting conclusions, the Division reserves the right to reopen and modify this permit. [391

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- .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

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P age 21 of 61 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 de termine 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 nitroge n 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 co nducted 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 test s, 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. Suc h performance tests shall be conducted at maximum load for both boilers and using the worst

case 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 p er 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 s hall 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 simultan eous 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 P ermittee 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 independen tly. 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.Title V Permit

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P age 22 of 61 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

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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 p erformance specification(s) of the Division's monitoring requirements. [391

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- .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 f rom 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. Dat a 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

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- .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 i n 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.Title V Permit

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P age 23 of 61 d. Pressure drop from the follo wing 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 re corded 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 (Sou rce 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) rece iving 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 e mission 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 d escription 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

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- .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, thi s 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 calenda r 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.Title V Permit

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P age 24 of 61 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

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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 an d 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 pe rmit 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 co nducted at least once for each day or portion of each day of operation and shall be conducted using the following procedure: [391

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- .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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P age 25 of 61 For each source that exhibits visible emissions, the Permittee shall determine the caus e 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 impl ement 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 press ure 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: [3 91

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- .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 m ay 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 i solation 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 o utlet/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 (NO
x ) and the carbon monoxide (CO) from the emission units with Source Codes: 630, 640, 650, and HP1, using the following plan: [391

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- .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, C ombustion 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 b e determined using the following equation:Title V Permit

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P age 26 of 61 2 

### 9

. 20 9

. 20

O F C K E d d



### − =

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
C d = Concentration of NOx or CO (ppm by volume, dry basis)
F d = 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 da y of the test)]
O 2 = 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:

sd d Q C K E 60 =

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
C d = Concentration of NOx or CO (ppm by volume, dry basis) Q sd = Stack gas flow rate measured using Method 2 corrected to dry standard condition (dscf/m in)

d. The Permittee shall measure the NO
x 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 cal endar quarter that the unit is operated.Title V Permit

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P age 27 of 61 f. Following any measurement that is greater than the applicable NO
x or CO level listed in Condition 6.1.7 c., the Permittee shall conduct a new measurement within one unit

operating day. Following this measureme nt, 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 mi dnight 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)]Title V Permit

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P age 28 of 61 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 r etained for at least five (5) years following the date of entry. [391

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- .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) da ys, 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 wri tten 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

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- .02(6)(b)1(iv), 391

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- .03(10)(d)1(i), and 40 CFR 70.6(a)(3)(iii)(B)]

6.1.3 The Permitt ee 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
otherw ise 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

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- .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 m onitor 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 Proced ures for Testing and Monitoring Sources of Air Pollutants and shall contain the following: [391

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- .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 Sec tion 1.5(c) and (d) of the above referenced document, including any failure to follow required work practice procedures.Title V Permit

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P age 29 of 61 b. Total process operating time during each reporting period.

c. The magnitude of all excess emissions, exceedances and excursions compu ted 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 monitorin g 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 inform ation in the report are true, accurate, and complete.

6.1.5 Where applicable, the Permittee shall keep the following records: [391

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- .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) a nalyses 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 ma intenance 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 record s. [391

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- .03(10)(d)1(i) and 40 CFR 70.6 (a)(3)(ii)(B)]Title V Permit

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P age 30 of 61 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 repor ted: [391

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- .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 em issions 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, calc ulated 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 limitat ion 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 Cleav er

- 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).Title V Permit

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P age 31 of 61 viii. Any measurement of the NO
x 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 mo nth 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
emissi on 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 boil ers 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 re sults of the monitoring).Title V Permit

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P age 32 of 61 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 cond enser 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 NO x 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 f uel 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 g as 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 le ak.

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 t he 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 mont h 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

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P age 33 of 61 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 compli es 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 su pplier certifications submitted represent all of the fuel oil combusted during the quarter. [391

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- .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 quantit y 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, an d 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 C odes: 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 e xceed 2.5 tons per hour. [40 CFR 70.6(a)(3)(i) and 391

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- .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

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- .02(7)]

CO = [40 x Total Mo. Nat. Gas for SC 650 (MMft 3 )] + [35 x Total Mo. Nat. Gas for S C 640 (MMft 3 )] + [84 x Total Mo. Nat. Gas and Vent Gas for SC HP1 (MMft 3 )] + [84 x Total Mo. Nat. Gas for Grain dryers SCs 009 and 010 (MMft 3 )] + [5 x Total Mo. #2 Fuel Oil and Vegetable oil for SCs 640 and 650 (Mgal)] + [Total Mo. CO (lbs) for SC 630
cal culated 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 t otal 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 permitt ing procedures.Title V Permit

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P age 34 of 61 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 Wellon s boiler with Source
Code: 630 shall be calculated as follows: [391

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Z Monthly CO Emissions = Σ (X N /6)*[5.890

- (X N )*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 equati on 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

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- .02(7)]

NO
x = [36.3 x Total Mo. Nat. Gas for SC 650 (MMft 3 )] + [140 x Total Mo. Nat. Gas for SC 640 (MMft 3 )] + [100 x Total Mo. Nat. Gas an d Vent Gas for SC HP1 (MMft 3 )] + [100 x Total Mo. Nat. Gas for Grain dryers SCs 009 and 010 (MMft 3 )] + [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 Permi ttee 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 m onths. 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.Title V Permit

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P age 35 of 61 6.2.8 The Permittee shall maintain daily and monthly records of the amount of soybeans processed through the facili ty 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

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- .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 wit h 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 du ring the current month plus the cumulative amounts in the previous eleven consecutive months. [40 CFR 70.6(a)(3)(i) and 391

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- .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

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- .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 oi l 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 a nd 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 h exane 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 p rocess (gallons per day); and SP = Amount of soybeans processed daily (tons per day).Title V Permit

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P age 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 (mi llion 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 e quation:

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 compu te 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

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- .02(6)(b)(1)]Title V Permit

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P age 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, su bmitted 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

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- .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 comp liance 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 w ith §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

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P age 38 of 61 6.2.16 The Per mittee 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 fift eenth 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

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- .02(6)(b)1, 391

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- 1.03(2)(c), Avoidance of 40 CFR 52.21]

6.2.18 The Permitte e 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 Div ision 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

c ompliance with the emission limit in Condition 3.2.12. [391

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- .02(6)(b)1, 391

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- 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 Cod es: 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

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- .02(6)(b)1 and 391

- 3

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- .03(2)(c)]

a. VOC B115A (lbs) = VOC B115A EF (lbs/ton wood waste burned) * Wood Waste
Burned B115A (tons/month); and

b. VOC B115B (lbs) = VOC B115B EF (lbs/ton wood waste burned) * Wood Waste
Burned B11B (tons/month); and

c. Total VOC (lbs) = VOC B115A (lbs) + VOC B115B (lb s)

Where:

VOC B115A (lbs) = the monthly VOC emissions from Boiler 115A.

VOC B115A EF = the VOC Emission Factor for Boiler 115A.Title V Permit

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P age 39 of 61 Wood Waste Burned B115A = the amount of wood waste combusted in Boiler 115A determined from records required by Permit Conditi on 6.2.16.

VOC B115B (lbs) = the monthly VOC emissions from Boiler 115B.

VOC B115B EF = the VOC Emission Factor for Boiler 115B.

Wood Waste Burned B115B = the amount of wood waste combusted in Boiler 115B determined from records required by Permit Conditio n 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

- ap proved 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 m onth. 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

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- .02(6)(b)1, 391

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- 1.0 3(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

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- .02(6)(b)1, 391

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- 1.03(2)(c), and Avoidance of 40 CFR 52.21]

6.2.22 The Permittee shall use the following equations w hen 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 fiv e years from the date of record. [391

- 3

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- .02(6)(b)1 and 391

- 3

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- .03(2)(c)]

a. F B115A (lbs) = F B115A EF (lbs/ton wood waste burned) * Wood Waste Burned B115A (tons/month); and

b. F B115B (lbs) = F B115B EF (lbs/ton wood waste burned) * Wood Waste Burned B115 B (tons/month); and

c. Total F (lbs) = F B115A (lbs) + F B115B (lbs).

Where:

F B115A (lbs) = the monthly fluoride emissions from Boiler 115A.Title V Permit

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P age 40 of 61 F B115A EF = the Fluoride Emission Factor for Boiler 115A.

Wood Waste Burned B115A = the amount of wood waste com busted in Boiler 115A determined from records required by Permit Condition 6.2.16.

F B115B (lbs) = the monthly fluoride emissions from Boiler 115B.

F B115B EF = the Fluoride Emission Factor for Boiler 115B.

Wood Waste Burned B115B = the amount of wood wast e 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 S ource 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 maint ain compliance with the
emission limit in Permit Condition 3.2.14. [391

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- .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 cal culate 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 a cid 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

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- .02(6)(b)1, 391

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- 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

s hall 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

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- .02(6)(b)1 and 391

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- .03(2)(c)]

a. SAM B115A (lbs) = SAM B115A EF (lbs/ton w ood waste burned) * Wood Waste
Burned B115A (tons/month); and

b. SAM B115B (lbs) = SAM B115B EF (lbs/ton wood waste burned) * Wood Waste
Burned B11B (tons/month); and

c. Total SAM (lbs) = SAM B115A (lbs) + SAM B115B (lbs).

Where:Title V Permit

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P age 41 of 61 SAM B115A (lbs) = the monthl y sulfuric acid mist emissions from Boiler 115A.

SAM B115A EF = the Sulfuric Acid Mist Emission Factor for Boiler 115A.

Wood Waste Burned B115A = the amount of wood waste combusted in Boiler 115A determined from records required by Permit Condition 6.2.16.

SAM B115B (lbs) = the monthly sulfuric acid mist emissions from Boiler 115B.

SAM B115B EF = the sulfuric acid mist Emission Factor for Boiler 115B.

Wood Waste Burned B115B = the amount of wood waste combusted in Boiler 115B determined from records require d 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

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- .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 post marked 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

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- .02(6)(b)1, 391

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- 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
availabl e for inspection by or submittal to the Division for five years from the date of
record. [391

- 3

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- .02(6)(b)1 and 391

- 3

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- .03(2)(c)]

a. SO2 B115A (lbs) = SO2 B115A EF (lbs/ton wood waste burned) * Wood Waste
Burned B115A (tons/month); and

b. SO2 B115B (lbs) = SO2 B115B EF (lbs/ton wood waste burned) * Wood Waste
Burned B11B (tons/month); and

c. Total SO2 (lbs) = SO2 B115A (lbs) + SO2 B115B (lbs).Title V Permit

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P age 42 of 61 Where:

SO2 B115A (lbs) = the monthly sulfur dioxide emissions from the boiler with Source Code:
B115A.

SO2 B115A EF = the SO2 Emission Factor for Boiler 115A.

Wood Waste Burned B115A = the amount of wood waste combusted in Boiler 115A determined from records required by Permit Condition 6.2.16.

SO2 B115B (lbs) = the monthly SO2 emissions from Boiler 115B.

SO2 B115B EF = the SO2 Emission Factor for Boiler 115B

.

Wood Waste Burned B115B = 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 Per mit 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

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- .02(6)(b)1, 391

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- 1.03(2)(c), and Avoidance of 40 CFR 52.21]

6.2.30 The Permittee shall compare the applicable wood

- firing rate establi shed 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 wood

firing rate per Permit Condition 4.2.11. This notificatio n 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 neces sary 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 offic ials 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

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P age 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 d efined 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 o f 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

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- .03(1) and (2). The Permittee and the Division shall attach each such notice to their copy of this Permit. [391

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- .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 sh all 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

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- .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. T he 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

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- .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 chan ges 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

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P age 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

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- .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 Tempora ry Sources [391

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- .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

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- .03(10)(d )3 and 40 CFR 70.6(c)(4)]

Not Applicable.

7.8 Emissions Trading [391

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- .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

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- .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 pr ovided in 40 CFR 68.150 through 68.185. The RMP shall include a registration that reflects all covered

processes.Title V Permit

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P age 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 coordinate d 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 th e 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 e lements 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 ma nagement 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 provid ed 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

- 1515Title V Permit

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P age 46 of 61 COURIER & FEDEX

Risk Management Program (RMP) Reporting Center
C/O CSC Suite 300 8400 Corporate Drive
New Carroll ton, 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 Pro tection 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 pursu ant 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

- li ke 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 mo re 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 (re frigerant) 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

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P age 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
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2075

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- 2 October 12, 2004
2075

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- 3 December 8, 2004
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- 4 February 16, 2005
2075

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- 5 May 3, 2006
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- 6 September 19 , 2006
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- 7 January 10, 2007

7.13 Pollution Prevention

Not Applicable.

7.14 Specific Conditions

Not Applicable.Title V Permit

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P age 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

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- .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 s hall 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 renew al 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

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- .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 n ecessary to halt or reduce the Permitted activity in order to maintain compliance with the conditions of this Permit. [391

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- .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

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P age 49 of 61 8.3.4 Issuance of this Permit does not relieve the Permittee from the responsibility of obtaining any other permits, li censes, or approvals required by the Director or any other federal, state, or local agency. [391

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- .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

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- .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

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- .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
i ssuance. [391

- 3

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- .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 tha n cause, authorization to operate shall continue beyond the expiration date to the point of Permit modification, reissuance, or revocation. [391

- 3

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- .03(10)(e)3(iii)]

8.6 Transfer of Ownership or Operation

8.6.1 This Permit is not transferable by the Per mittee. 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 da te 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

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- .03(4)]

8.7 Property Rights

8.7.1 This Permit shall n ot convey property rights of any sort, or any exclusive privileges. [391

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P age 50 of 61 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 appli cation 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 forme d after reasonable inquiry, the statements and information in the document are true, accurate, and complete. [391

- 3

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- .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 corre cted information to the Division. [391

- 3

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- .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 Pe rmit, 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
furn ish such records directly to the EPA, if necessary, along with a claim of confidentiality. [391

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- .03(10)(d)1(i) and 40 CFR 70.6(a)(6)(v)]Title V Permit

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P age 51 of 61 8.10 Modifications

8.10.1 Prior to any source commencing a modification as defined in 391

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- .01(pp) that may

r esult in air pollution and not exempted by 391

- 3

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- .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, discuss ion, 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 ch ange, 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 Divisio n, unless otherwise notified by the Division. [391

- 3

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- .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 Permi t will be reopened for cause and revised accordingly under the following circumstances: [391

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- .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 cas e, 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 Perm it is due to expire; [391

- 3

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- .03(10)(e)6(i)(I)]

b. If any additional applicable requirements of the Acid Rain Program become applicable to the source; [391

- 3

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- .03(10)(e)6(i)(II)] (Acid Rain sources only)

c. The Director determines that the Permit conta ins a material mistake or inaccurate statements were made in establishing the emissions standards or other terms or conditions of the Permit; or [391

- 3

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- .03(10)(e)6(i)(III) and 40 CFR 70.7(f)(1)(iii)]

d. The Director determines that the Permit must be re vised or revoked to assure compliance with the applicable requirements. [391

- 3

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- .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

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- .03(10)(e)6(ii)]Title V Permit

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P age 52 of 61 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 remai n 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

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- .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 chang es 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

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- .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

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- .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;Title V Permit

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P age 53 of 61 c. During the period of the emergency, the Permittee took all reasonable steps to
minimize levels of emi ssions 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
limi tations 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 occurren ce of an emergency shall have the burden of proof. [391

- 3

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- .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

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- .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 writt en 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 po ssible 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
deter mining 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 mater ial information; andTitle V Permit

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P age 54 of 61 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 Div ision to perform the following: [391

- 3

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- .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, o r 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 th e 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 ass essment of civil penalties. [391

- 3

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- .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 emp loyed shall be allowed provided that: [391

- 3

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- .02(2)(a)7(i)]Title V Permit

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P age 55 of 61 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

p revented 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

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- .02(2)(a)7(ii)]

c. The provisions of this condition and Georgia Rule 391

- 3

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- .02(2)(a)7 shall app ly 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 applicab le 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

at mosphere. [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 spe cifically identified in the Permit. [391

- 3

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- .03(10)(d)6]

8.16.2 Any Permit condition identified as “State only enforceable” does not have a Permit shield.Title V Permit

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P age 56 of 61 8.17 Operational Practices

8.17.1 At all times, including periods of startup, shutdown, and malf unction, 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 mainte nance procedures or records, and inspection or
surveillance of the source. [391

- 3

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- .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 und er 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 m atter 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

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- .02(2)(d)]Title V Permit

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P age 57 of 61 8.19.3 The Permittee shall not cause, let, suffer, permit, or allow the emission from any fuel

burning 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 s ulfur, 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 cau se, 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
fro m new equipment:

E = 4.1P 0.67 ; for process input weight rate up to and including 30 tons per hour.
E = 55P 0.11

- 40; for process input weight rate above 30 tons per hour.

b. The following equation shall be used to calculate the allowable rates of emissio n from existing equipment:

E = 4.1P 0.67

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 th is 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 airbo rne 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;Title V Permit

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P age 58 of 61 b. Applicat ion 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. Ad equate 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 o ther 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 prov isions 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. T he 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 me asured 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 equippe d 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 spr ay 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 contai ners and shall not be disposed of by such a method as to allow excessive evaporation into the atmosphere.Title V Permit

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P age 59 of 61 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 e missions 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 e mit 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 pound s 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 800 o F; and

c. It has a secondary burner to control smoke and/or odors and maintain a temper ature of at least 1500 o F 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 St orage” 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

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- .02(2)(vv)(1)]Title V Permit

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P age 60 of 61 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 inte rnal 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

- resetta ble 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.Title V Permit

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P age 61 of 61 Attachments

A. List of Standard Abbreviations and List of Permit Specific Abbreviations
B. Ins ignificant Activities Checklist, Insignificant Activities Based on Emission Levels and Generic Emission Groups
C. List of ReferencesTitle V Permit

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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 Deteriorat ion
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 SO 2 (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 O rganic 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

H 2 O (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

M W Megawatt
NESHAP National Emission Standards for Hazardous Air
Pollutants
NO

x (NOx) Nitrogen Oxides
NSPS New Source Performance Standards
OCGA Official Code of Georgia Annotated

List of Permit Specific AbbreviationsTitle V Permit

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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 in significant 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, l imitation 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 Incinerator s, 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, an d/or 3 waste. 0

iii) Less than 4 million BTU/hr heat input firing type 4 waste. (Refer to 391

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- .03(10)(g)2.(ii) for descriptions of waste types) 0

3. Open burning in compliance with Georgia Rule 391

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- .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

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- .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. No n

- 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. 0Title V Permit

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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 project s, 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 collec tion 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 ar e 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 t otal 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 oven s. 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 conduct ed 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 blast ing, 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, pho tographic 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 m etal 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 s ystem. 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 ad hesives 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 proc esses where VOC emissions are less than 5 tons per year and HAP emissions are less than 1,000 pounds per year. 0Title V Permit

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Appendix Page 4 of 6 INSIGNIFICANT ACTIVITIES CHECKLIST Category Description of Insignificant Activity/Unit Quantity Storage Tanks and Equipment 1. All petrole um 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 stor ing 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 mil limeters 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 fro m Boiler Ash House to Dumpster 1Title V Permit

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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

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- .02 (2) (b), (e) &/or (n). Potential emissions of pa rticulate matter, from these sources based on TSP, are less than 25 tons per year per process line or unit in each group. An y emissions unit subject to a NESHAP, NSPS, or any specific Air Quality Permit Condition(s) are not included in this table.

Desc ription 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

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- .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 bu rning equipment with a rated heat input capacity of 1 million BTU/hr or less. 0Title V Permit

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Appendix Page 6 of 6 ATTACHMENT C

LIST OF REFERENCES

1. The Georgia Rules for Air Quality Control Chapter 391

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- 1. All Rules cited herein which begin with 391

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- 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, Environment al 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 Fee s

.

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 versi on 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 Applicati ons, 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).