1427-Aop-R12

RESPONSE TO COMMENTS

PLANTERS COTTON OIL MILL, INC. PERMIT #1427-AOP-RI2 AFIN: 35-00025

On October 19,2013, the Director ofthe Arkansas Department ofEnvironmental Quality gave notice ofa draft permitting decision for the above referenced facility. During the comment period, written comments on the draft permitting decision were submitted by the facility. The Department's response to these issues follows.

Note: The following page numbers and condition numbers refer to the draft permit. These references may have changed in the final permit based on changes made during the comment period.

Comment #1: Plantwide Condition #10 (and the Statement ofBasis #14): "Please remove the requirements for stack testing in its entirety. This stack test was performed on July 19,2012 and July 20, 2012."

Response to Comment #1:

Draft Plantwide Condition #10 has been removed from the final permit. The SOB has been updated to reflect the change.

Comment #2: Specific Condition #42: "Please change the opacity limit from 5% to 20%. Due to the high particulate emission rate, this source cannot meet the 5% limit."

Response to Comment #2: The opacity limit for SN-37, Meal Loading Unit, has been increased to 20% in Specific Condition #42. In addition, the facility will be required to conduct visible emissions readings on a daily basis per Specific Condition #43.

Page 1 of 1 ADEQ ARK ANSAS Department of Environmental Quality

February 6, 2014

John Jefferson Senior Vice-President Planters Cotton Oil Mill, Inc. 2901 Planters Drive Pine Bluff, AR 71601

Dear Mr. Jefferson:

The enclosed Permit No. 1427-AOP-R12 is your authority to construct, operate, and maintain the equipment and/or control apparatus as set forth in your application initially received on 12/16/2011.

After considering the facts and requirements ofA.C.A. §8-4-101 et seq., and implementing regulations, I have determined that Permit No. 1427-AOP-R12 for the construction, operation and maintenance ofan air pollution control system for Planters Cotton Oil Mill, Inc. to be issued and effective on the date specified in the permit, unless a Commission review has been properly requested under Arkansas Department ofPollution Control & Ecology Commission's Administrative Procedures, Regulation 8, within thirty (30) days after service ofthis decision.

The applicant or permittee and any other person submitting public comments on the record may request an adjudicatory hearing and Commission review ofthe final permitting decisions as provided under Chapter Six ofRegulation No.8, Administrative Procedures, Arkansas Pollution Control and Ecology Commission. Such a request shall be in the form and manner required by Regulation 8.603, including filing a written Request for Hearing with the APC&E Commission Secretary at 101 E. Capitol Ave., Suite 205, Little Rock, Arkansas 72201. Ifyou have any questions about filing the request, please call the Commission at 501-682-7890.

Sincerely,

Mike Bates Chief, Air Division

ARKANSAS DEPARTMENT OF ENVIRONMENTAL QUALITY 5301 NORTHSHORE DRIVE / NORTH UTILE ROCK / ARKANSAS 72118-5317 / TELEPHONE 501-682-0744 / FAX 501-682-0880 www.odeq.stote.or.us ADEQ OPERATING AIR PERMIT

Pursuant to the Regulations ofthe Arkansas Operating Air Permit Program, Regulation 26:

Permit No. : 1427-AOP-R12

IS ISSUED TO:

Planters Cotton Oil Mill, Inc. 2901 Planters Drive Pine Bluff, AR 71601 Jefferson County AFIN: 35-00025

THIS PERMIT AUTHORIZES THE ABOVE REFERENCED PERMITTEE TO INSTALL, OPERATE, AND MAINTAIN THE EQUIPMENT AND EMISSION UNITS DESCRIBED IN THE PERMIT APPLICATION AND ON THE FOLLOWING PAGES. THIS PERMIT IS VALID BETWEEN:

September 20,2011 AND September 19,2016

THE PERMITTEE IS SUBJECT TO ALL LIMITS AND CONDITIONS CONTAINED HEREIN.

Signed:

February 6, 2014 Mike Bates Date Chief, Air Division Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

Table ofContents SECTION I: FACILITY INFORMATION 5 SECTION II: INTRODUCTION 6 Summary ofPermit Activity 6 Process Description 6 Regulations 9 Emission Summary 10 SECTION III: PERMIT HISTORy 15 SECTION IV: SPECIFIC CONDITIONS 20 SN-Ol 1st Cut Linter Machines 20 SN-02, 03, & 04 2nd Cut Linter Machines 21 SN-05 & 14 Salvage Reclaim 22 SN-06-l2 and 48-51 Lint Cleaners 23 SN-13 Seed Cleaner 26 SN-15 Recycling System 28 SN-52 Recycling System 29 SN-16 & 17 Bailing Presses 30 SN-18 through 26 and 57 Seed Cleaners 31 SN-27 and 28 Rock Traps #1 and #2 34 SN-29 Stick and Burr Machine 36 SN-30 Motes Beater/Pre-lint Cleaner 38 SN-31 Decorticating/Separating 40 SN-32, 42, 43, 46, and 56 Solvent Extraction Plant 41 SN-34 Dump Enclosure 45 SN-35 Hammennill 46 SN-36 Meal Loading Enclosure 48 SN-37 Meal Loading Unit 49 SN-77 Hull Loading Unit 51 SN-39 and 40 Sacked Hull Houses 52 SN-44 and 45 Boilers #1 and #2 53 SN-47 Bulk House Cooling Fans 55 SN-55 and 61 Trash Beaters #1 and #2 58 SN-58 (RFD-l) & SN-59 (RFD-2) Rotary Drum Filters #1 and #2 59 SN-60 Portable Material Loading Units 61 SN-62 Protein Shakers (Cyclone PS-l) 62 SN-63 Trash Shaker Receiving 63 SN-64 Rotary Drum Filter (RDF-3) 64 SN-65 through SN-71 Hull Shaker Fans, Cascade Fans, and Hull Shaker/Cascade Fans 66 SN-73 Black Cotton Seed Tank 67 SN-74 Baghouse 69 SN-75 Pellet Mill Storage 71 SN-76 Cooling Tower 72 SN-78 Shipping Conveyor 74 SECTION V: COMPLIANCE PLAN AND SCHEDULE 75 SECTION VI: PLANTWIDE CONDITIONS 76

2 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFlN: 35-00025

Permit Shield 79 Title VI Provisions 81 SECTION VII: INSIGNIFICANT ACTIVITIES 83 SECTION VIII: GENERAL PROVISIONS 84 Appendix A: 40 CFR Part 60 Subpart De Appendix B: 40 CFR Part 63 Subpart GGGG Appendix C: ADEQ Continuous Emission Monitoring Systems Conditions

3 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

List ofAcronyms and Abbreviations

A.C.A. Arkansas Code Annotated AFIN ADEQ Facility Identification Number CFR Code ofFederal Regulations CO Carbon Monoxide HAP Hazardous Air Pollutant lb/hr Pound Per Hour MVAC Motor Vehicle Air Conditioner No. Number

NO x Nitrogen Oxide PM Particulate Matter

PM 10 Particulate Matter Smaller Than Ten Microns SNAP Significant New Alternatives Program (SNAP) S02 Sulfur Dioxide SSM Startup, Shutdown, and Malfunction Plan Tpy Tons Per Year UTM Universal Transverse Mercator VOC Volatile Organic Compound

4 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

SECTION I: FACILITY INFORMATION

PERMITTEE: Planters Cotton Oil Mill, Inc.

AFIN: 35-00025

PERMIT NUMBER: 1427-AOP-RI2

FACILITY ADDRESS: 2901 Planters Drive Pine Bluff, AR 71601

MAILING ADDRESS: 2901 Planters Drive Pine Bluff, AR 71601

COUNTY: Jefferson County

CONTACT NAME: John Jefferson

CONTACT POSITION: Senior Vice-President

TELEPHONE NUMBER: 870-545-3631

REVIEWING ENGINEER: Amanda Leamons

UTM North South (Y): Zone 15: 3787578.04 m

UTM East West (X): Zone 15: 592931.50m

5 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

SECTION II: INTRODUCTION

Summary ofPermit Activity

Planters Cotton Oil Mill (Planters) is located at 2901 Planters Drive in Pine Bluff, Arkansas where it currently produces vegetable oil from cottonseed separation and solvent extraction (NAICS 311223). This permit revision includes a modification to:

• Remove the English Boiler (SN-72) from the permit; • Permit a previously installed drag conveyor (SN-78); • Allow the facility the flexibility ofusing the seed houses to also store hulls; • Permit the rerouting ofSN-62 and SN-63 to the existing baghouse, SN-74; • Permit the previously installed Pellet Mill, SN-75; • Permit the previously installed Cooling Tower, SN-76; • Remove the cyclone from SN-38 in order to convert it from a Bulk Hull House to a Bulk Meal House; • Install a new auger type conveyor to direct meal from the Meal Storage Tanks to the Bulk Meal House; • Install a new Hull Loading Unit at Seed House #15; and • Convert the Hull Loading Enclosure (SN-37) to a Meal Loading Unit.

The above listed changes at the facility result in overall annual permitted emission limit decreases of9.5 tons PM, 7.3 tons PMIO, 17.6 tons S02, 7 tons VOC, 74.5 tons CO, 26.7 tons NO x and 4.3 tons combined HAP.

Process Description

Receiving and Storage:

The mill receives cottonseed by truck. Each truck is weighed and then sent to one ofthe seed dumps. The cottonseed is dumped from the trucks at a 45 degree angle into receiving pits. There are receiving pits at the Main Facility (also referred to as the Active Mill), the Lower Mill on Michigan Street, and the Old Mill on East s" Avenue across the railroad tracks.

Since pneumatic conveying could result in cottonseed damage, mechanical conveying is used to transfer the cottonseed from the receiving pits. A screw conveyor pushes the seed to the vertical elevators which transfer the seed to the elevated system ofbelt conveyors. The belt conveyors carry seed either to one ofthe feed storage houses or directly to the seed cleaning room for processing. Seed stored at the Lower Mill or the Old Mill is conveyed to the Main Facility for processing.

6 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

Cottonseed Cleaning:

Cottonseed is mechanically conveyed to the cleaning area where it is processed through seed cleaning units. These units remove leaves, twigs, pieces ofbolls, sand and other material picked up in the fields or in handling. Lint and trash are collected by cyclones. After cleaning, the seed is conveyed to the lint room.

Cottonseed Delinting and Lint Cleaning:

In the lint room, the delinting machines cut the short fibers offofthe seeds. The lint is removed by brushes or air and then collected and conveyed to the baling room.

The 1st cut delinters are used to remove the longest lint from the cottonseed. Cottonseed parts and other foreign materials (motes) that are caught in the lint are cleaned by the 1st cut lint cleaners. These machines beat, stir, and convey the lint over perforated metal. These motes are then combined with the motes from the separation room and cleaned in the motes cleaner.

The partially delinted cottonseed from the 1st cut delinters is conveyed to the 2nd cut delinters where the remaining lint is removed. Cottonseed parts and other foreign materials that are caught in the lint are cleaned by the 2nd cut delinters. The lint from the 2nd cut delinters along with recycle lint from the cleaners is cleaned in the 2nd cut delinters. The clean 1st and 2nd cut lint is conveyed to the baling room and baled. Finished bales oflint are sent to storage for shipment. The shale, pepper, and trash stream from each lint cleaner and the motes cleaner are combined and sent to hull storage. The lint once again goes to a beater and then to a baling press.

Hulling and Separating:

After the cottonseed is delinted through the 2nd cut linters, the black seed is transferred to a black seed storage tank for holding prior to processing. The black seed is then conveyed to the safety shaker in the hulling and separating area. The safety shaker removes loose lint and any miscellaneous material from the black seed. The lint is sent to the lint room. The fine hulls and meat are separated from the black seed by the safety shaker and sent to the huller room.

The huller and shaker cut the black seed open to release the meats. Meats are then directed to the meat stream. Hulls and uncut seed are sent to the hull and seed separator. Uncut seed is separated out and recycled to the huller and shaker. Any remaining meat is separated from the hulls in the single-drum and double-drum beaters and the purifier. Meats from these three machines are directed to the meat stream while the hulls are sent to hull storage.

Vegetable Oil Extraction:

Before entering the oil extraction unit, the cottonseed meats enter the flaking process where they are flattened into flakes in order to improve oil extraction. Meats pass through a series ofheavy cast iron rollers. The rollers reduce the meat flakes into thinner flakes. The flakes are then

7 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025 cooked in a cooker which is steam heated by a natural gas fired boiler. The cooker heats the flakes with added moisture so that they may be expanded into pellet shaped colletts and fed to the extractor.

In the solvent extraction plant, colletts are fed to a counter-current solvent extractor where oil is extracted by percolating solvent, consisting ofhexane, through cottonseed meats. The extractor is operated under slight negative pressure to aid in the feeding ofmeats and to prevent the escape ofhexane vapors. Two (2) streams ofsolvent are produced. The first stream consists ofsolvent and oil. The second consists ofmeal saturated with solvent.

Solvent/Oil Separation:

After extraction, the miseella, a mixture ofsolvent and oil, commonly known as miscella, is separated by distillation. During distillation, the first stage evaporator increases the oil concentration in the miscella to 65 percent. The miscella is then pumped to storage tanks where it is temporarily kept until further refinement.

The miscella is next treated in the miscella refinery with a caustic solution, such as sodium hydroxide. This action begins the separation ofthe heavy soaps from the light oil. The heavy soaps are removed from the miscella by centrifuge. At this point, the miscella is processed through the second stage evaporator and then the oil stripper which removes the remaining hexane. The refinery is hermetically sealed and the solvent vapors are processed through the condenser vent scrubber system. Centrifuge seal water and backwash are treated in a separate sump before treatment in the main sump. The oil, now stripped ofhexane, is pumped to a cooler to remove heat and moisture, and is then pumped to finished tanks prior to shipment.

SolventlMeal Separation:

The cottonseed colletts that are processed through the extractor become saturated with solvent. In order to reclaim the solvent and make the meal edible for animals, the flakes are fed to the Desolventizer/Toaster unit where steam is used to vaporize and strip out occluded solvent from the meal. The meal is transported to the storage tanks by a cyclone meal cooler unit which cools the meal as it is transported. Alternatively, the meal can be transferred to the bulk meal storage (SN-38) via the enclosed conveyor.

Hexane Recovery and Control:

The solvent-laden vapors from the distillation system are collected, condensed, and sent to a solvent water separator. This cooled condensate containing recovered solvent and solvent vapors is separated into solvent and water phases by gravity. The solvent layer is returned to solvent storage for re-use. The water layer is sent through a wastewater evaporator to recover heat energy and is then clarified in the main sump. The hexane remaining in the exhaust gas from the condensers is controlled with a mineral oil scrubbing system. Mineral oil is first used to remove hexane from the exhaust gases prior to release to the atmosphere. The solvent-laden mineral oil

8 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025 is stripped ofsolvent by steam in the stripping column. The solvent vapors are recycled to the solvent condenser.

Product Shipping:

Bulk materials are shipped from the facility for use in the animal feed and other industries. Recovered meal is shipped out by railcar and truck. Hulls are shipped out either sacked or in bulk. Planters incorporates the use offour (4) portable conveyors to load hulls, meal and seed to truck for shipment or processing (Insignificant Activities). Meal is loaded onto trucks using the Meal Loading Unit (SN-37) at the Bulk Meal House (SN-38). The Hull loading Unit (SN-77) at Seed Building #15 will load hulls onto trucks.

Pellet Mill and Storage Area:

The Pellet Mill (SN-75) is an enclosed system compression device, in which heat and pressure are used to compress and bind the raw material into a pellet shape. The vapor is routed to Rotary Drum Filter #1, SN-58, and the pellets are routed to the pellet storage silo.

Regulations

The following table contains the regulations applicable to this permit.

Regulations Arkansas Air Pollution Control Code, Regulation 18, effective June 18,2010 Regulations ofthe Arkansas Plan ofImplementationfor Air Pollution Control, Regulation 19, effective July 27, 2013 Regulations ofthe Arkansas Operating Air Permit Program, Regulation 26, effective November 18,2012 40 CFR Part 60 Subpart De - Standards ofPerformance for Small Industrial- Commercial-Institutional Steam Generating Units. Applicable to SN-44, 45, and 72. 40 CFR Part 63 Subpart GGGG, - National Emission Standards for Hazardous Air Pollutants (NESHAP) for Solvent Extraction for Vegetable Oil Production. Applicable to SN-32, 42, 43, 56, and 46.

9 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

Emission Summary

The following table is a summary ofemissions from the facility. This table, in itself, is not an enforceable condition ofthe permit.

EMISSION SUMMARY Source Emission Rates Description Pollutant Number lb/hr tpy PMIO 14.8 49.6 S02 0.2 0.2 Total Allowable Criteria Pollutant VOC 131.1 495.9 Emissions CO 3.6 15.4 NOx 4.2 18.4 Lead 0.000022 0.000092 PM 58.2 218.2 Hexane* 91.88 346.8 Total Allowable Non- Criteria Mercury* 1.08E-05 4.8E-05 Pollutant Emissions Arsenic* 8.4E-06 3.8E-05 Beryllium* 5.2E-07 2.2E-06 Cadmium* 4.6E-05 2.0E-04 Manganese* 1.6E-05 7.0E-05 15t Cut Linter Machines 01 (Cyclone A-I) 2na Cut Linter Machines 02 (Cyclone A-2) Emissions routed to SN-64, Rotary Drum Filter #3. 2nd Cut Linter Machines 03 (Cyclone A-3) 2nd Cut Linter Machines 04 (Cyclone A-4) Salvage Reclaim 05 Emissions routed to SN-64, Rotary Drum Filter #3. (Cyclone B) Lint Cleaner PM 0.6 2.4 6 (Cyclone C-1) PMIO 0.1 0.5 Lint Cleaner PM 0.6 2.4 7 (Cyclone C-2) PMIO 0.1 0.5 Lint Cleaner PM 0.6 2.4 8 (Cyclone C-3) PM IO 0.1 0.5 Lint Cleaner PM 0.6 2.4 9 (Cyclone C-4) PM 10 0.1 0.5 Lint Cleaner PM 0.6 2.4 10 (Cyclone C-5) PM 10 0.1 0.5 Lint Cleaner PM 0.6 2.4 11 (Cyclone C-6) PMIO 0.1 0.5

10 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

EMISSION SUMMARY Source Emission Rates Description Pollutant Number lb/hr tpy Lint Cleaner PM 0.6 2.4 12 (Cyclone C-7) PMIO 0.1 0.5 Seed Cleaner PM 1.6 6.8 13 (Cyclone SC-11) PMIO 0.1 0.2 Recycling System 15 Emissions routed to SN-64, Rotary Drum Filter #3 (Cyclone E-2) Bailing Presses 16 Emissions routed to SN-59, Rotary Drum Filter #2 (Cyclone F-1) Bailing Presses 17 Emissions routed to SN-59, Rotary Drum Filter #2 (Cyclones F-2 & F-3) Seed Cleaner PM 1.8 7.6 18 (Cyclone SC-1) PM 10 0.1 0.2 Seed Cleaner PM 1.8 7.6 19 (Cyclone SC-2) PMIO 0.1 0.2 Seed Cleaner PM 1.8 7.6 20 (Cyclone SC-3) PMIO 0.1 0.2 Seed Cleaner PM 1.8 7.6 21 (Cyclone SC-4) PMIO 0.1 0.2 Seed Cleaner PM 1.8 7.6 22 (Cyclone SC-5) PMIO 0.1 0.2 Seed Cleaner PM 1.8 7.6 23 (Cyclone SC-6) PMIO 0.1 0.2 Seed Cleaner PM 1.8 7.6 24 (Cyclone SC-7) PMIO 0.1 0.2 Seed Cleaner PM 1.8 7.6 25 (Cyclone SC-8) PMIO 0.1 0.2 Seed Cleaner PM 1.8 7.6 26 (Cyclone SC-9) PMIO 0.1 0.2 Rock Trap 1 PM 0.7 2.8 27 (Cyclone RTC-1) PMIO 0.7 2.8 Rock Trap 2 PM 0.9 3.8 28 (Cyclone RTC-2) PMIO 0.9 3.8 Stick & Burr Machine PM 0.9 3.6 29 (Cyclone MFC-1) PMIO 0.4 1.5 Motes Beater/Pre-lint PM 0.9 3.6 30 Cleaner PM 10 0.4 1.5 (Cyclone HC-13) Decorticating/Separating 31 Machines Emissions routed to SN-64, Rotary Drum Filter #3 (Cyclones H-1 thru H-5)

11 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

EMISSION SUMMARY Source Emission Rates Description Pollutant Number lb/hr tpy Solvent Plant MOS Vent VOC 41.0 156.0 32 (90% Control Efficiency) Hexane 28.90 109.20 34 Dump Enclosure Emissions routed to SN-59, Rotary Drum Filter #2 Hammermill PM 1.6 6.8 35 (Cyclone HM-18) PMIO 0.7 2.7 Meal Loading Enclosure 36 Emissions routed to SN-58, Rotary Drum Filter #1 (Cyclone 19) PM 4.3 6.9 37 Meal Loading Enclosure PMIO 1.5 2.4 Source emissions are now considered insignificant and 38 Bulk Meal House listed as a Group A-13 Insignificant Activity. Sacked Hull House 39 Emissions routed to SN-58, Rotary Drum Filter #1 (Cyclone H-22)

Sacked Hull House 40 Emissions routed to SN-58, Rotary Drum Filter #1 (Cyclone H-23)

PM 0.3 1.0 Dryer/Cooler Area PM 10 0.1 0.4 42 (Cyclone DC-26) VOC 7.5 28.3 Hexane 5.30 19.80 PM 0.3 1.0 Dryer/Cooler Area PM 0.1 43 IO 0.4 (Cyclone DC-25) VOC 7.5 28.3 Hexane 5.30 19.80 PM 0.2 0.7 PMIO 0.2 0.7 S02 0.1 0.1 VOC 0.2 0.5 CO 1.8 7.7 NO Boiler #1 x 2.1 9.2 44 Lead 1.1E-5 (20.92 MMBTU/hr) 4.6E-5 Arsenic 4.2E-6 1.9E-5 Beryllium 2.6E-7 1.1E-6 Cadmium 2.3E-5 1.0E-4 Hexane 0.04 0.20 Manganese 8.0E-6 3.5E-5 Mercury 5.4E-6 2.4E-5

12 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

EMISSION SUMMARY Source Emission Rates Description Pollutant Number lb/hr tpy PM 0.2 0.7 PMIO 0.2 0.7 S02 0.1 0.1 VOC 0.2 0.5 CO 1.8 7.7 NO 2.1 9.2 Boiler #2 x 45 Lead 1.1E-5 4.6E-5 (20.92 MMBTU/hr) Arsenic 4.2E-6 1.9E-5 Beryllium 2.6E-7 1.1E-6 Cadmium 2.3E-5 1.0E-4 Hexane 0.04 0.20 Manganese 8.0E-6 3.5E-5 Mercury 5.4E-6 2.4E-5 Solvent Plant Hexane VOC 67.2 254.0 46 Fugitive Losses Hexane 47.0 177.8 PM 6.9 30.0 47 Bulk Cooling Fans PM 10 2.4 10.6 Lint Cleaner PM 0.6 2.4 48 (Cyclone C-8) PMIO 0.1 0.5 Lint Cleaner PM 0.6 2.4 49 (Cyclone C-9) PMIO 0.1 0.5 Lint Cleaner PM 0.6 2.4 50 (Cyclone C-13) PMIO 0.1 0.5 Lint Cleaner PM 0.6 2.4 51 (Cyclone C-13) PMIO 0.1 0.5 Recycling System 52 Emissions routed to SN-64, Rotary Drum Filter #3 (Cyclone B-2) Trash Beater #1, 55 Bran & Pepper Emissions routed to SN-64, Rotary Drum Filter #3 (Cyclone B-1) PM 0.3 1.0 Dryer/Cooler Area PMIO 0.1 0.4 56 (Cyclone DC-25) VOC 7.5 28.3 Hexane 5.30 19.80 Seed Cleaner PM 1.8 7.6 57 (Cyclone SC-I0) PMIO 0.1 0.2 PM 1.2 5.1 58 Drum Filter (RDF-I) PMIO 0.5 2.1 PM 0.9 4.0 59 Drum Filter (RDF-2) PMIO 0.4 1.6

13 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

EMISSION SUMMARY Source Emission Rates Description Pollutant Number lb/hr tpy Trash Beater #2, 61 Lint & Motes Emissions routed to SN-64, Rotary Drum Filter #3 (Cyclone B-2) Protein Shakers 62 (Cyclone PS-1) Emissions routed to SN-74, Baghouse Trash Shaker Receiving 63 (Cyclone C-9) Rotary Drum Filter PM 3.1 13.6 64 (RDF-3) PM IO 1.3 5.5 Hull Shaker Fan #1 65 (Cyclone) Hull Shaker Fan #2 66 (Cyclone) Air Cascade Fan #1 67 (Cyclone) Air Cascade Fan #2 68 Emissions routed to SN-74, Baghouse (Cyclone) Air Cascade Fan #3 69 (Cyclone) Air Cascade Fan #4 70 (Cyclone) Air Cascade Fan #5 71 (Cyclone) 72 Boiler # 3 Removed from service PM 0.1 0.2 73 Black Cotton Seed Tank PM 10 0.1 0.1 PM 0.1 0.5 74 Baghouse PM IO 0.1 0.1 PM 0.2 0.7 75 Pellet Mill Storage PMIO 0.1 0.2 PM 4.1 18.0 76 Cooling Tower PM IO 0.7 2.7 PM 4.3 4.1 77 Hull Loading Unit PM IO 1.5 1.4 PM 0.5 0.9 78 Shipping Conveyor PM 10 0.2 0.3 * Emissions mcluded in VOC and PM IO totals.

14 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

SECTION III: PERMIT HISTORY

Permit #178-A was issued to Cook Industries, Inc., in 1973 to bring the facility into full compliance with the provisions ofthe Air Code. In this permit, the facility installed a bag type collector to control emissions generated during transfer ofcottonseed to storage and installed one bag type collector on the aspiration system to control emissions generated during hull and meal loading. Five medium efficiency cyclones were installed to replace several low efficiency cyclones controlling emissions from the beater rooms. Operating procedures were established to minimize emissions generated during operation ofthe pneumatic unloading system.

Permit #178-AR-l was issued on April 26, 1988, in order to change the ownership ofCook Industries ofPine Bluffto Planters Cotton Oil Mill, Inc. The facility was permitted for 3.9 tpy of NOx from the gas boiler and 1.4 tpy ofVOC from the hexane plant. Particulate matter emissions were indicated for seven other sources; however, the emissions were not quantified.

Permit #178-AR-2 was issued on July 11, 1991. In this permit, the facility was permitted at 209 tpy ofPM, 7 tpy ofNOx, and 225 tpy ofVOC.

Permit #1427-A was issued to Planters Cotton Oil Mill, Inc. on March 10, 1993, in order to allow the facility to construct a cotton oil mill that would process 800 tons per day ofcotton seed. Emissions were permitted at the following limits: PM, 245.7 tpy; SOx, 0.2 tpy; VOC, 98.4 tpy; CO, 8.8 tpy; and NOx, 35.0 tpy.

The previous mill operations are located approximately two miles away from this mill. With the exception oftwo seed operations, the operations ofthe old mill were dismantled.

Permit #1427-AR-l was issued July 11, 1996, to decrease the net emission limit ofparticulate matter from 247.5 tpy to 190.0 tpy based on testing. The SIC code for the facility was also corrected. In addition, the VOC limit was changed to 107.1 tpy to account for the 105.7 tpy of hexane that is emitted from the facility.

Permit #1427-AOP-RO was issued July 1, 1999. This was the initial Title V permit for this facility. This permit also addressed an emissions increase due to an increased throughput of cotton at the facility. The PM/PMIO limit was increased to 216.3 tpy and the VOC limit was increased to 252.7 tpy; the VOC emissions are primarily hexane at 252.1 tpy.

Permit #1427-AOP-Rl was issued February 3, 2000. This was the initial modification to the Title V air permit for this facility. This modification was issued in order to account for emissions increases from the installation ofnew equipment at the facility as well as to account for the reassignment ofsome ofthe equipment already present at the facility. The new equipment added in this modification consisted ofa new cyclone added to the seed cleaning process, two new decorticating/separating machines, and four new lint cleaners. The bran and pepper cyclone was omitted from the initial permit application, but was added with this modification. This modification resulted in an increase of 18.0 tpy ofPM/PM10 emissions.

15 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

Permit #1427-AOP-R2 was second modification to the Operating Air Permit for this facility. This modification was issued in order to allow for the installation ofa drum filter for the purpose ofreducing particulate emissions at the facility. Emissions from four currently permitted sources (SN-35, SN-36, SN-39, and SN-40) were routed to this new filter. This modification resulted in a reduction ofpermitted particulate matter emissions of 10.3 tons per year (tpy).

Permit #1427-AOP-R3 was third modification to the Operating Air Permit for this facility. The modification involved replacing the 2nd cut baling press and routing nuisance dust from the baling press and truck dump enclosure areas, as well as the air emissions from three existing sources (SN-16, SN-17, and SN-34), to a fabric drum filter (SN-59) for further particulate emissions reduction.

Permit #1427-AOP-R4, issued on November 18,2001 was the fourth modification to the Operating Air Permit for this facility. The modification involved installation ofa new seed cleaner and two additional linter machines, one 1st cut and one 3rd cut linter. Emissions from the new seed cleaner are routed to the SN-13 cyclone. The house cleaning operations were previously routed to SN-13; this operation was removed from service. Therefore, the only emissions routed through SN-13 come from the new seed cleaner. The two additional linter machines are routed to existing 1st and 3rd cut cyclones, SN-Ol and SN-04 respectively.

Permit #1427-AOP-R5, issued on April 2, 2003 was the fifth modification to the Operating Air Permit for this facility. Planters Cotton Oil Mill, Inc. made the following modifications in order to improve the quality ofthe finished lint product:

1. Convert 3rd cut linter machines into 2nd cut linter machines and upgrade cyclones SN-O 1, 02,03 and 04. This improved the quality ofthe finished product and it made the cyclones more efficient. 2. Replaced the current lint & mote beater with a new hi cell top cellulose section (SN-30) and this increased cleaning efficiency. 3. Divide the trash reclaiming load between the lint, bran & pepper in order to reduce the load and increase efficiency.

The existing trash reclaimer machine or trash shaker, using cyclone SN 55, for the Lint, Bran & Pepper, is currently overloaded and inefficient. Therefore, a new 60-inch trash reclaimer machine or trash shaker (SN-61) was added to divide the load between the Lint, Bran & Pepper. The load is divided as follows:

• Trash Beater # 1 (SN-55) Bran & Pepper will take approximately 38% ofthe existing load.

• Trash Beater #2 (SN-61) Lint & Motes will take approximately 62% ofthe existing load.

4. Removed 2nd cut linter machine cyclones SN-2a and SN-3a.

Note: There were no increases in emissions from the proposed modernization project.

16 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

On January 15, 2004 the Department issued a letter ofacceptance for a Title V Minor Modification to Permit #1427-AOP-R5 which proposed the installation ofa new rotary drum filter, designated as SN-64. This minor modification included the routing ofemissions from several existing cyclones to SN-64. The minor modification to Permit # 1427-AOP-R5 was not prepared and/or issued because it was requested in the Title V Renewal Application.

Permit #1427-AOP-R6, issued on February 9, 2004 was the sixth modification to the Operating Air Permit for this facility. This modification was issued after the Title V Operating Permit renewal application was submitted (December 22,2003). It was issued for the replacement ofan existing hot water boiler (SN-44) which blew up in October 2002 and an overhaul ofexisting boiler SN-45. A temporary boiler was taken out ofservice and removed from the site.

The modification included the installation oftwo (2) Protein Shakers with one (1) 54" cyclone, in the Separation Department, designated as SN-62. This minor modification was for the removal oflarger fiber particles and any remaining hulls from the meat stream, and will help maintain a high protein content, and will improve the equality ofthe finished meal product. The excess hulls and larger fibers removed from the meat will be mixed back into the finished hull product.

The increase in emissions for the proposed modifications is: PM @ 7.6 tpy, PMlO @ 10.2 tpy, VOC @ 2.4 tpy & CO @ 21.0 tpy. The NOx emissions decreased by 4.2 tpy.

Permit # 1427-AOP-R7 was issued on May 12,2005. The following items summarize changes in this permit renewal with modifications:

A Rotary Drum Filter (RDF-3), designated as SN-64, was installed in November 2004. Overall potential emissions ofparticulate matter (PM) and PM less than or equal to ten microns in diameter (PM\o) will decrease as a result ofthis change. The emissions from the following existing cyclones were re-routed to SN-64: SN-01 through SN-05, SN-14, SN-15, SN-31, SN 55, SN-61, (SN-62 and SN-63 not re-routed)

The PM and PM lO emission estimates for the facility's cyclones have been updated. This update is based on data from a study on cyclone emissions at cotton ginning facilities [Journal ofCotton Science 4:178-182 (2000)]. Although the study was not performed for cottonseed processing plants, the data was considered to be representative ofcyclone emissions at the Planters facility. There are no AP-42 emissions factors for cyclones at cottonseed processing plants.

Two (2) cyclones not listed in the previous permit are currently in operation are now being permitted: Mitchell Belt Feeder Cyclone (SN-29) and Hammermill Cyclone (SN-35).

Emission estimates for the solvent extraction plant have been updated in order to accurately reflect actual solvent loss. The proposed changes result in an increase in potential emission rates ofn-Hexane and volatile organic compounds (VOC) from the Mineral Oil Scrubber System

17 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

(MOS) Main Vent (SN-32), the Dryer/Cooler Area Cyclones (SN-42, SN-43, and SN-56), and the solvent plant fugitive emissions (SN-46).

Two (2) sources have been reclassified and are now included in the permit as insignificant activities: hull loading shed (previously permitted as SN-37), and the portable material loaders (Previously permitted as SN-60).

The emissions estimates for the boilers (SN-44 and SN-45) have been updated and are based upon the most recent data published in AP-42 for natural gas combustion.

The previous permit limit of300,000 tons ofcottonseed processed per year was increased to 350,000 tons per year. Cyclones and drum filters are being permitted to operate on a continuous basis. The annual hexane solvent replacement limits will continue to be verified via mass balance and associated recordkeeping. The permit limit for Hexane solvent make-up has been raised and the limit is included in the Plantwide Conditions.

Permit #1427-AOP-R8 was issued on May 23,2006 to Planters Cotton Oil Mill (Planters) as a modification primarily to install a boiler which would combust solid fuels.

The only actual increases in emissions from the facility were due to the construction ofBoiler #3 (SN-72), and the potential emissions were less than the PSD significance levels.

Due to the increased cost in natural gas fuel, Planters proposed to install a 25.0 MMBtu/hr, 500 HP shop assembled package water tube boiler to be designated as SN-72 which combusted solid fuel such as cotton seed hulls or cellulose fiber/polypropylene plastic mix {Balcone's Refuse Derived Fuel (RDF)} that is composed ofwaste materials resulting from Kimberly Clark's manufacturing operations. The RDF was provided in cube form from Balcones ofLittle Rock. SN-72 was subject to the MACT rules for boilers, 40 CFR 63, Subpart DDDDD. This boiler installation resulted in an increase in permitted emissions.

Planters was a major source of HAP emissions, namely hexane, and as such this boiler will be subject to 40 CFR 63, Subpart DDDDD; National Emission Standards for Hazardous Air Pollutants (NESHAP) for Industrial, Commercial and Institutional Boilers and Process Heaters.

Under Subpart DDDDD, this new boiler was considered as a large solid fuel boiler and had to meet the following emission requirements: 0.025 lbs PM/MMBtu or 0.0003 lbs TSM/MMBtu 0.02 lbs HClIMMBtu 0.000003 lbs Hg/MMBtu 400 ppm CO by volume Opacity was limited to a maximum of 10%

In accordance with Subpart DDDDD, Planters had performed an initial precursory fuel analysis for total selected metals (TSM), chloride and mercury. The fuel analysis revealed that the fuels

18 Planters Cotton Oil Mill, Inc. Permit #: l427-AOP-R12 AFIN: 35-00025 were in compliance with chloride and mercury but failed for TSM. Therefore, Planters installed an electrostatic precipitator (ESP) to meet the TSM limit.

The emissions from the Protein Shaker (SN-62) cyclone and the Trash Shaker Receiving (SN 63) cyclone were not routed to Rotary Drum Filter #3 (SN-64) when it was installed under the previous permit in 2004. These cyclones emitted directly to atmosphere. The increase in permitted emissions from these sources was 8.7 tpy PM IO and 21.0 tpy PM.

The Recycling Stream Cyclone (SN-52) cyclone emissions were routed to (SN-64). The reduction in permitted emissions from this source was 4.1 tpy PM IO and 10.3 tpy PM.

SN-65 thru SN-7l (Hull Shaker Fans and Cascade Fans) were not previously permitted and existed prior to the installation of (SN-64). These sources were routed into SN-64 upon its construction in 2004.

The n-hexane (HAP) content received by the facility was currently limited to 64%. Since hexane suppliers claimed this to be a tight limit, the permittee requested a 70% limit. This affected HAP emissions from sources SN-32, SN-42, SN-43, SN-46 and SN-56. Potential HAPs emissions increased by 29.1 tpy.

Permit #1427-AOP-R9 was issued on May 26, 2008. The modification was issued to allow the facility to increase the S02 emissions when combusting RDF at Boiler #3 (SN-72), remove language pertaining to 40 CFR Part 63, Subpart DDDDD, and add sawdust and wood shavings to the allowable fuels for Boiler #3. The changes resulted in an increase of 5.0 tons per year (tpy) ofPM, 1.6 tpy ofPMIO, 1.7 tpy ofS02, 0.9 tpy ofVOC, and 1.87 tpy ofHAPs.

Permit #1427-AOP-Rl0 was issued on September 25, 2009. The permit was modified to incorporate the applicable requirements of40 CFR Part 60, Subpart De for the existing #3 boiler (SN-72) and remove conditions associated with 40 CFR Part 63, Subpart DDDDD which was vacated by court mandate. Permitted emission limits remain unchanged.

Permit #1427-AOP-Rl1 was issued on September 20,2011. This permit renewal included several revisions to emission limits based on updated emission factors derived from similar source testing results at other facilities. Annual permitted emission limits increased 14.8 tons of S02, 5.1 tons ofVOC, 2.5 tons ofCO, 1.8 tons ofHexane while emission limits decreased 66.3 tons ofPM and 104 tons ofPMIO.

19 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

SECTION IV: SPECIFIC CONDITIONS

SN-Ol 1st Cut Linter Machines

Source Description

Eight 1st cut linter machines are used to remove the longest lint from the cottonseed. This source was installed in 1993. Emissions are controlled by Cyclone A-I. Emissions from this cyclone were routed to Rotary Drum Filter #3, SN-64. Therefore, SN-Ol is no a longer emission point.

20 Planters Cotton Oil Mill, Inc. Permit #: l427-AOP-RI2 AFIN: 35-00025

SN-02, 03, & 04 2nd Cut Linter Machines

Source Description

Twenty-two second cut machines are used to remove the remaining lint from the cottonseed. Emissions are controlled by Cyclone A-2, A-3 and A-4. Emissions from these cyclones are routed to Rotary Drum Filter #3, SN-64. Therefore, SN-02, 03 and 04 are no longer emission points.

21 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

SN-05 & 14 Salvage Reclaim

Source Description In the Salvage Reclaim, trash air streams from the lint cleaners are sent through Cyclone B and Cyclone E-l. Collected material is directed to lint beaters. Emissions from these cyclones are routed to Rotary Drum Filter #3, SN-64. Therefore, SN-05 and SN-14 are no longer emission points.

22 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

SN-06-12 and 48-51 Lint Cleaners

Source Description

Sources 06 through 12 are lint cleaners that were installed in 1993. Emissions are controlled by Cyclones C-l through C-7. In 1999 four additional lint cleaners with accompanying cyclones (C·I0, C-ll, C-12, and C-13) were installed in order to treat lint emissions from various points around the plant. Cleaners SN-49 and SN-50 were installed to handle the effluent from SN-03 and SN-02 respectively. Cleaners SN-48 and SN-51 were installed to handle the effluent from the salvage reclaim operations. Stack testing was performed on one ofthe seed cleaner cyclones and one ofthe lint cleaner cyclones on July 19 and 20,2012.

Specific Conditions

1. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by compliance with Plant Wide Conditions 7,8, and 9. [Regulation 19, §19.501 et seq. and 40 CFR Part 52, Subpart E]

SN Description Pollutant lb/hr tpy Lint Cleaner 06 PMIO 0.1 0.5 (Cyclone C-l) Lint Cleaner 07 PMIO 0.1 0.5 (Cyclone C-2) Lint Cleaner 08 PMIO 0.1 0.5 (Cyclone C-3) Lint Cleaner 09 PMIO 0.1 0.5 (Cyclone C-4) Lint Cleaner 10 PMIO 0.1 0.5 (Cyclone C-5) Lint Cleaner 11 PMIO 0.1 0.5 (Cyclone C-6) Lint Cleaner 12 PMIO 0.1 0.5 (Cyclone C-7) Lint Cleaner 48 PMIO 0.1 0.5 (Cyclone C-8) Lint Cleaner 49 PMIO 0.1 0.5 (Cyclone C-9) Lint Cleaner 50 PMIO 0.1 0.5 (Cyclone C-13) Lint Cleaner 51 PM 10 0.1 0.5 (Cyclone C-13)

23 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

2. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by compliance with Plant Wide Conditions 7,8, and 9. [Regulation 18, §18.801 and A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

SN Description Pollutant lb/hr tpy Lint Cleaner 06 PM 0.6 2.4 (Cyclone C-l) Lint Cleaner 07 PM 0.6 2.4 (Cyclone C-2) Lint Cleaner 08 PM 0.6 2.4 (Cyclone C-3) Lint Cleaner 09 PM 0.6 2.4 (Cyclone C-4) Lint Cleaner 10 PM 0.6 2.4 (Cyclone C-5) Lint Cleaner 11 PM 0.6 2.4 (Cyclone C-6) Lint Cleaner 12 PM 0.6 2.4 (Cyclone C-7) Lint Cleaner 48 PM 0.6 2.4 (Cyclone C-8) Lint Cleaner 49 PM 0.6 2.4 (Cyclone C-9) Lint Cleaner 50 PM 0.6 2.4 (Cyclone C-13) Lint Cleaner 51 PM 0.6 2.4 (Cyclone C-13)

3. Visible emissions may not exceed the limits specified in the following table ofthis permit as measured by EPA Reference Method 9.

SN Limit Regulatory Citation 06-12 & 5% §18.501 48-51

4. Weekly observations ofthe opacity from these sources shall be conducted by personnel familiar with the permittee's visible emissions. The permittee shall maintain personnel trained in EPA Reference Method 9. Ifvisible emissions which appear to be in excess of the permitted opacity are detected, the permittee shall immediately take action to identify the cause ofthe visible emissions, implement corrective action, and document that visible emissions did not appear to be in excess ofthe permitted opacity following the corrective action. The permittee shall maintain records which contain the following items in order

24 Planters Cotton Oil Mill, Inc. Permit #: l427-AOP-R12 AFIN: 35-00025

to demonstrate compliance with this specific condition. These records shall be updated weekly, kept on site, and made available to Department personnel upon request. a. The date and time ofthe observation; b. Ifvisible emissions which appeared to be above the permitted limit were detected; c. The cause ofthe exceedance ofthe opacity limit; d. The corrective action taken; e. Ifthe visible emissions appeared to be below the permitted limit after the corrective action was taken; and f. The name ofthe person conducting the opacity observations. [Regulation 19, §19.705, A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311, and 40 CFR 70.6]

25 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

SN-13 Seed Cleaner

Source Description

This was formally known as the House Cleaning area. The facility no longer operates the house cleaning process (SN-13). However, the exhaust from the new seed cleaner will be routed through this cyclone (SN-13).

Specific Conditions

5. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by compliance with Plant Wide Conditions 7,8, and 9. [Regulation 19, §19.501 et seq. and 40 CFR Part 52, Subpart E]

SN Description Pollutant lb/hr tpy 13 Seed Cleaner PMIO 0.1 0.2

6. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by compliance with Plant Wide Conditions 7, 8, and 9. [Regulation 18, §18.801 and AC.A §8-4-203 as referenced by AC.A. §8-4-304 and §8-4-311]

SN Description Pollutant Ib/hr tpy 13 Seed Cleaner PM 1.6 6.8

7. Visible emissions may not exceed the limits specified in the following table ofthis permit as measured by EPA Reference Method 9.

SN Limit Regulatory Citation 13 10% §18.801

8. Weekly observations ofthe opacity from SN-13 shall be conducted by personnel familiar with the permittee's visible emissions. The permittee shall maintain personnel trained in EPA Reference Method 9. Ifvisible emissions which appear to be in excess ofthe permitted opacity are detected, the permittee shall immediately take action to identify the cause ofthe visible emissions, implement corrective action, and document that visible emissions did not appear to be in excess ofthe permitted opacity following the corrective action. The permittee shall maintain records which contain the following items in order to demonstrate compliance with this specific condition. These records shall be updated weekly, kept on site, and made available to Department personnel upon request.

26 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

a. The date and time ofthe observation; b. Ifvisible emissions which appeared to be above the permitted limit were detected; c. The cause ofthe exceedance ofthe opacity limit; d. The corrective action taken; e. Ifthe visible emissions appeared to be below the permitted limit after the corrective action was taken; and f. The name ofthe person conducting the opacity observations. [Regulation 19, §19.705, A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311, and 40 CFR 70.6]

27 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

SN-15 Recycling System

Source Description

In the recycling system, motes from the lint cleaners are processed through Cyclones E-2 and B 2. The collected material is sent back to the delinters to have the lint removed. Emissions from this cyclone are routed to Rotary Drum Filter #3, SN-64. Therefore, SN-15 is no longer an emission point.

28 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

SN-52 Recycling System

Source Description

In the recycling system, motes from the lint cleaners are processed through Cyclone B-2. The collected material is sent back to the delinters to have the lint removed. SN-52 was installed in 1999. Emissions from this cyclone are routed to Rotary Drum Filter #3, SN-64. Therefore, SN 52 is no longer emission point.

29 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

SN-16 & 17 Bailing Presses

Source Description

Two bailing presses are used to bale the lint from the cottonseed. The two bailing press cyclone systems were replaced with two high efficiency cyclones with fans rated at 6,500 cubic feet per minute (cfm). Emissions from these cyclones are routed to the Rotary Drum Filter #2 (SN-59); therefore, SN-16 and SN-17 are no longer emission points.

30 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

SN-18 through 26 and 57 Seed Cleaners

Source Description

Ten (10) seed cleaners are used to remove leaves, twigs, and other trash from the seeds. Emissions are controlled by Cyclones SC-1 through SC-lO. SN-18 through SN-26 were installed in 1993 and SN-57 was installed in 1999. Stack testing was performed on one ofthe seed cleaner cyclones and one ofthe lint cleaner cyclones on July 19 and 20,2012.

Specific Conditions

9. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by compliance with Plant Wide Conditions 7, 8, and 9. [Regulation 19, §19.501 et seq. and 40 CFR Part 52, Subpart E]

SN Description Pollutant lb/hr tpy Seed Cleaner 18 PMIO 0.1 0.2 (Cyclone SC-1) Seed Cleaner 19 PM 10 0.1 0.2 (Cyclone SC-2) Seed Cleaner 20 PMIO 0.1 0.2 (Cyclone SC-3) Seed Cleaner 21 PMIO 0.1 0.2 (Cyclone SC-4) Seed Cleaner 22 PMIO 0.1 0.2 (Cyclone SC-5) Seed Cleaner 23 PMIO 0.1 0.2 (Cyclone SC-6) Seed Cleaner 24 PM 10 0.1 0.2 (Cyclone SC-7) Seed Cleaner 25 PMIO 0.1 0.2 (Cyclone SC-8) Seed Cleaner 26 PMIO 0.1 0.2 (Cyclone SC-9) Seed Cleaner 57 PMIO 0.1 0.2 (Cyclone SC-lO)

10. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by compliance with Plant Wide Conditions 7,8, and 9. [Regulation 18, §18.801 and A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

31 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

SN Description Pollutant lblhr tpy Seed Cleaner 18 PM 1.8 7.6 (Cyclone SC-l) Seed Cleaner 19 PM 1.8 7.6 (Cyclone SC-2) Seed Cleaner 20 PM 1.8 7.6 (Cyclone SC-3) Seed Cleaner 21 PM 1.8 7.6 (Cyclone SC-4) Seed Cleaner 22 PM 1.8 7.6 (Cyclone SC-5) Seed Cleaner 23 PM 1.8 7.6 (Cyclone SC-6) Seed Cleaner 24 PM 1.8 7.6 (Cyclone SC-7) Seed Cleaner 25 PM 1.8 7.6 (Cyclone SC-8) Seed Cleaner 26 PM 1.8 7.6 (Cyclone SC-9) Seed Cleaner 57 PM 1.8 7.6 (Cyclone SC-lO)

11. Visible emissions may not exceed the limits specified in the following table ofthis pennit as measured by EPA Reference Method 9.

SN Limit Regulatory Citation 18-26, & 5% §18.501 57

12. Weekly observations ofthe opacity from SN-18 through 26 and 57 shall be conducted by personnel familiar with the permittee's visible emissions. The permittee shall maintain personnel trained in EPA Reference Method 9. Ifvisible emissions which appear to be in excess ofthe permitted opacity are detected, the permittee shall immediately take action to identify the cause ofthe visible emissions, implement corrective action, and document that visible emissions did not appear to be in excess ofthe permitted opacity following the corrective action. The permittee shall maintain records which contain the following items in order to demonstrate compliance with this specific condition. These records shall be updated weekly, kept on site, and made available to Department personnel upon request. a. The date and time ofthe observation; b. Ifvisible emissions which appeared to be above the permitted limit were detected; c. The cause ofthe exceedance ofthe opacity limit;

32 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

d. The corrective action taken; e. Ifthe visible emissions appeared to be below the permitted limit after the corrective action was taken; and f. The name ofthe person conducting the opacity observations. [Regulation 19, §19.705, A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311, and 40 CFR 70.6]

33 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

SN-27 and 28 Rock Traps #1 and #2

Source Description

Rock traps #1 and #2 are used to remove some ofthe heavier trash from the cottonseed. They were both installed in 1993. Emissions are controlled by Cyclones RTC-l and RTC-2. Particulate matter emissions are based on stack tests for both SN-27 and SN-28. SN-27 was stack tested in December of2003 and SN-28 was tested in June of2005.

Specific Conditions

13. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by compliance with Plant Wide Conditions 7,8, and 9. [Regulation 19, §19.501 et seq. and 40 CFR Part 52, Subpart E]

SN Description Pollutant Ib/hr tpy 27 Rock Trap #1 PMIO 0.7 2.8 28 Rock Trap #2 PMIO 0.9 3.8

14. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by compliance with Plant Wide Conditions 7,8, and 9. [Regulation 18, §18.801 and A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

SN Description Pollutant Ib/hr tpy 27 Rock Trap #1 PM 0.7 2.8 28 Rock Trap #2 PM 0.9 3.8

15. Visible emissions may not exceed the limits specified in the following table ofthis permit as measured by EPA Reference Method 9.

SN Limit Regulatory Citation 27 5% §18.501 28 5% §18.501

16. Weekly observations ofthe opacity from SN-27 and SN-28 shall be conducted by personnel familiar with the permittee's visible emissions. The permittee shall maintain personnel trained in EPA Reference Method 9. Ifvisible emissions which appear to be in excess ofthe permitted opacity are detected, the permittee shall immediately take action to identify the cause ofthe visible emissions, implement corrective action, and document that visible emissions did not appear to be in excess ofthe permitted opacity following the corrective action. The permittee shall maintain records which contain the following

34 Planters Cotton Oil Mill, Inc. Permit #: l427-AOP-R12 AFIN: 35-00025

items in order to demonstrate compliance with this specific condition. These records shall be updated weekly, kept on site, and made available to Department personnel upon request. a. The date and time ofthe observation; b. Ifvisible emissions which appeared to be above the permitted limit were detected; c. The cause ofthe exceedance ofthe opacity limit; d. The corrective action taken; e. Ifthe visible emissions appeared to be below the permitted limit after the corrective action was taken; and f. The name ofthe person conducting the opacity observations. [Regulation 19, §19.705, A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-3ll, and 40 CFR 70.6]

35 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

SN-29 Stick and Burr Machine (Mitchell Belt Feeder)

Source Description

The Stick and Burr Machine previously called the Mitchell Belt Feeder is used to transport material collected from Cyclone MFC-l in the seed cleaning process. The unit was installed in 1993. The cyclone is rated at 2,400 cfm. SN-29 was tested on June 14,2005.

Specific Conditions

17. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by compliance with Plant Wide Conditions 7, 8, and 9. [Regulation 19, §19.501 et seq. and 40 CFR Part 52, Subpart E]

SN Description Pollutant lb/hr tpy 29 Stick & Burr Machine PM IO 0.4 1.5

18. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by compliance with Plant Wide Conditions 7, 8, and 9. [Regulation 18, §18.801 and A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

SN Description Pollutant lb/hr tpy 29 Stick & Burr Machine PM 0.9 3.6

19. Visible emissions may not exceed the limits specified in the following table ofthis permit as measured by EPA Reference Method 9.

SN Limit Regulatory Citation 29 10% §18.501

20. Weekly observations ofthe opacity from SN-29 shall be conducted by personnel familiar with the permittee's visible emissions. The permittee shall maintain personnel trained in EPA Reference Method 9. Ifvisible emissions which appear to be in excess ofthe permitted opacity are detected, the permittee shall immediately take action to identify the cause ofthe visible emissions, implement corrective action, and document that visible emissions did not appear to be in excess ofthe permitted opacity following the corrective action. The permittee shall maintain records which contain the following items in order to demonstrate compliance with this specific condition. These records shall be updated

36 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

weekly, kept on site, and made available to Department personnel upon request. a. The date and time ofthe observation; b. Ifvisible emissions which appeared to be above the permitted limit were detected; c. The cause ofthe exceedance ofthe opacity limit; d. The corrective action taken; e. Ifthe visible emissions appeared to be below the permitted limit after the corrective action was taken; and f. The name ofthe person conducting the opacity observations. [Regulation 19, §19.705, A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311, and 40 CFR 70.6]

37 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

SN-30 Motes Beater/Pre-lint Cleaner High-Cell Top Cellulose Section

Source Description

The lint and motes beater unit was not in use, and in order to incorporate efficient cleaning it was replaced with a new Hi-Cell Top Cellulose Section in April of2003. The installation ofthe Hi Cell Top Cellulose Section increased cleaning efficiency. Emissions are controlled by Cyclone HC-13, which is rated at 2,400 cfm. SN-30 was tested on June 13,2005.

Specific Conditions

21. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by compliance with Plant Wide Conditions 7, 8, and 9. [Regulation 19, §19.501 et seq. and 40 CFR Part 52, Subpart E]

SN Description Pollutant lb/hr tpy 30 Motes Beater/Pre-lint Cleaner PMIO 0.4 1.5

22. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by compliance with Plant Wide Conditions 7,8, and 9. [Regulation 18, §18.801 and A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

SN Description Pollutant lblhr tpy 30 Motes Beater/Pre-lint Cleaner PM 0.9 3.6

23. Visible emissions may not exceed the limits specified in the following table ofthis permit as measured by EPA Reference Method 9.

SN Limit Regulatory Citation 30 10% §18.501

24. Weekly observations ofthe opacity from SN-30 shall be conducted by personnel familiar with the permittee's visible emissions. The permittee shall maintain personnel trained in EPA Reference Method 9. Ifvisible emissions which appear to be in excess ofthe permitted opacity are detected, the permittee shall immediately take action to identify the cause ofthe visible emissions, implement corrective action, and document that visible emissions did not appear to be in excess ofthe permitted opacity following the corrective action. The permittee shall maintain records which contain the following items in order to demonstrate compliance with this specific condition. These records shall be updated

38 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

39 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

SN-31 Decorticating/Separating

Source Description

In this operation, ten (10) machines are used to remove the meats. The original eight machines were installed in 1993. Two additional machines were added in 1999 to bring the total to 10 machines. Emissions from these machines are vented through cyclones and routed to Rotary Drum Filter #3 (SN-64).

40 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

SN-32, 42, 43, 46, and 56 Solvent Extraction Plant

Source Description

SN-32 is the emission source ofthe solvent plant mineral oil scrubber main vent (MOS). SN-42, SN-43, and SN-56 are the emissions ofthe dryer/cooler area cyclones. SN-56 was added in 1999 to assist in the dryer/cooler area. The emissions from SN-46 are fugitive non point source emissions from the solvent extraction plant area. Also included at this site are two 10,000 gallon horizontal hexane tanks. These tanks are vented back into the solvent recovery/mineral oil system and are not vented to the atmosphere. These sources were installed in 1993.

VOC emissions are accounted for in the amount ofmake-up hexane that is bought each year. The emission rates are apportioned to each source by the amount of standard use.

Specific Conditions

25. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by compliance with Specific Conditions 31, 33, and 35. [Regulation 19, §19.501 et seq. and 40 CFR Part 52, Subpart E]

SN Description Pollutant lb/hr tpy Solvent Plant Mineral Oil 32 VOC 41.0 156.0 Scrubber (MOS) Main Vent Dryer/Cooler Area 42 VOC 7.5 28.3 (Cyclone DC-26) Dryer/Cooler Area 43 VOC 7.5 28.3 (Cyclone DC-25) 46 Solvent Plant - Fugitive Losses VOC 67.2 254.0 Dryer/Cooler Area 56 VOC 7.5 28.3 (Cyclone DC-27)

26. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by compliance with Specific Condition 33. [Regulation 19, §19.501 et seq. and 40 CFR Part 52, Subpart E]

SN Description Pollutant lb/hr toy Dryer/Cooler Area 42 PMIO 0.1 0.4 (Cyclone DC-26) Dryer/Cooler Area 43 PM10 0.1 0.4 (Cyclone DC-25)

41 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

SN Description Pollutant lb/hr tpy Dryer/Cooler Area 56 PMIO 0.1 0.4 (Cyclone DC-27)

27. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by compliance with Specific Condition 33. [Regulation 18, §18.801 and A.C.A. §8-4-203 as referenced by A.C.A. §8 4-304 and §8-4-311]

SN Description Pollutant lblhr tpy Dryer/Cooler Area 42 PM 0.3 1.0 (Cyclone DC-26) Dryer/Cooler Area 43 PM 0.3 1.0 (Cyclone DC-25) Dryer/Cooler Area 56 PM 0.3 1.0 (Cyclone DC-27)

28. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by compliance with Specific Conditions 31 and 33. [Regulation 18, §18.801 and A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

SN Description Pollutant lblhr tpy Solvent Plant Mineral Oil Scrubber 32 n-Hexane 28.9 109.2 (MOS) Main Vent Dryer/Cooler Area 42 n-Hexane 5.3 19.8 (Cyclone DC-26) Dryer/Cooler Area 43 n-Hexane 5.3 19.8 (Cyclone DC-25) 46 Solvent Plant - Fugitive Losses n-Hexane 47.0 177.8 Dryer/Cooler Area 56 n-Hexane 5.3 19.8 (Cyclone DC-27)

29. Visible emissions may not exceed the limits specified in the following table ofthis permit as measured by EPA Reference Method 9.

SN Limit Regulatory Citation 32 5% §18.501 42 5% §18.501 43 5% §18.501 56 5% §18.501

42 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

30. Weekly observations ofthe opacity from SN-32, SN-42, SN-43, and SN-56 shall be conducted by personnel familiar with the permittee's visible emissions. The permittee shall maintain personnel trained in EPA Reference Method 9. Ifvisible emissions which appear to be in excess ofthe permitted opacity are detected, the permittee shall immediately take action to identify the cause ofthe visible emissions, implement corrective action, and document that visible emissions did not appear to be in excess of the permitted opacity following the corrective action. The permittee shall maintain records which contain the following items in order to demonstrate compliance with this specific condition. These records shall be updated weekly, kept on site, and made available to Department personnel upon request. a. The date and time ofthe observation; b. Ifvisible emissions which appeared to be above the permitted limit were detected; c. The cause ofthe exceedance ofthe opacity limit; d. The corrective action taken; e. Ifthe visible emissions appeared to be below the permitted limit after the corrective action was taken; and f. The name ofthe person conducting the opacity observations. [Regulation 19, §19.705, AC.A §8-4-203 as referenced by §8-4-304 and §8-4-311, and 40 CFR 70.6] 31. The facility may only use those Hexane solvents that shall not cause the VOC and HAP emission limits set forth in Specific Conditions 25 and 28 to be exceeded. The facility shall use only those Hexane solvents that have a NormalHexane content equal to or less than 3.955 pounds per gallon during any consecutive 12-month operating period. The other Hexane isomers shall be limited to 1.691 pounds per gallon. There shall be no other HAPs used. Compliance shall be demonstrated through compliance with record keeping requirements set forth in Specific Condition 32 and as set forth in Plant Wide Conditions Error! Reference source not found. through 21. [Regulation 19, §19.705, Regulation 18, §18.1004, and AC.A §8-4-203 as referenced by §8-4-304 and §8-4-311] 32. Records demonstrating compliance with Specific Condition 31 shall be maintained on a twelve-month rolling total basis, updated monthly, kept on site and made available to the Department upon request. The permittee shall submit a semi-annual report including Hexane make-up as set forth in General Provision 7. [Regulation 19, §19.705, Regulation No. 18 §18.1004, and AC.A §8-4-203 as referenced by §8-4-304 and §8-4-311, and 40 CFR Part 52, Subpart E] 33. The annual make-up ofHexane solvent that shall not cause the VOC and HAP emission limits set forth in Specific Conditions 25 and 28 to be exceeded, shall be limited to 175,000 gallons per consecutive twelve month period. Compliance shall be demonstrated through compliance with record keeping requirements set forth in Specific Condition 34. [Regulation 19, §19.705, Regulation 18 §18.1004, AC.A. §8-4-203 as referenced by §8-4-304 and §8-4-311 and 40 CFR 70.6]

43 Planters Cotton Oil Mill, Inc. Permit #: l427-AOP-RI2 AFIN: 35-00025

34. Records demonstrating compliance with Specific Condition 33 shall be maintained on a twelve-month rolling total basis, updated monthly, kept on site and made available to the Department upon request. The permittee shall submit a semi-annual report on Hexane make-up as set forth in General Provision 7. [Regulation 19, §19.705, Regulation 18, §18.1004, A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311, and 40 CFR Part 52, Subpart E] 35. The mineral oil plant shall not be operated without the mineral oil absorber in use. [Regulation 18, §18.1004 and A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311]

44 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

SN-34 Dump Enclosure

Source Description

At the dump enclosure, seeds are dumped into a pit. This source was installed in 1993. Emissions from the dump enclosure are being routed to the Rotary Drum Filter (SN-59).

45 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

SN-35 Hammermill

Source Description

The hammermill is used to flatten the meats discharged from SN-42, SN-43 and SN-56. It was installed in 1993. Emissions are controlled by Cyclone HM-18.

Specific Conditions

36. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by compliance with Plant Wide Conditions 7,8, and 9. [Regulation 19, §19.501 et seq. and 40 CFR Part 52, Subpart E]

SN Description Pollutant lb/hr tpy 35 Hammermill PM 10 0.7 2.7

37. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by compliance with Plant Wide Conditions 7, 8, and 9. [Regulation 18, §18.801 and A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311 ]

SN Description Pollutant lb/hr tpy 35 Hammermill PM 1.6 6.8

38. Visible emissions may not exceed the limits specified in the following table ofthis permit as measured by EPA Reference Method 9.

SN Limit Regulatory Citation 35 10% §18.501

39. Weekly observations ofthe opacity from SN-35 shall be conducted by personnel familiar with the permittee's visible emissions. The permittee shall maintain personnel trained in EPA Reference Method 9. Ifvisible emissions which appear to be in excess ofthe permitted opacity are detected, the permittee shall immediately take action to identify the cause ofthe visible emissions, implement corrective action, and document that visible emissions did not appear to be in excess ofthe permitted opacity following the corrective action. The permittee shall maintain records which contain the following items in order to demonstrate compliance with this specific condition. These records shall be updated weekly, kept on site, and made available to Department personnel upon request. a. The date and time ofthe observation;

46 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

b. Ifvisible emissions which appeared to be above the permitted limit were detected; c. The cause ofthe exceedance ofthe opacity limit; d. The corrective action taken; e. Ifthe visible emissions appeared to be below the permitted limit after the corrective action was taken; and f. The name ofthe person conducting the opacity observations. [Regulation 19, §19.705, A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311, and 40 CFR 70.6]

47 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

SN-36 Meal Loading Enclosure

Source Description

Meal is loaded into trucks and railcars in the meal loading enclosure. This source was installed in 1993. Emissions are controlled by Cyclone 19. Emissions from this cyclone are routed to Rotary Drum Filter #1 (SN-58).

48 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

SN-37 Meal Loading Unit

Source Description

Meal is loaded into trucks by an auger within a partially enclosed shed located outside the Meal House. This source was installed in 1993 as a Hull Loading Enclosure and converted to the Meal Loading Unit in 2013.

Specific Conditions

40. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by compliance with Plant Wide Conditions 7,8, and 9. [Regulation 19, §19.501 et seq. and 40 CFR Part 52, Subpart E]

SN Description Pollutant lb/hr tpy

37 Meal Loading Unit PMIO 1.5 2.4

41. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by compliance with Plant Wide Conditions 7, 8, and 9. [Regulation 18, §18.801, and AC.A §8-4-203 as referenced by AC.A §8-4-304 and §8-4-311]

SN Description Pollutant lb/hr tpy

37 Meal Loading Unit PM 4.3 6.9

42. Visible emissions may not exceed the limits specified in the following table ofthis perrnit as measured by EPA Reference Method 9.

SN Limit Regulatory Citation 37 20% §18.501

43. Daily observations ofthe opacity from SN-37 shall be conducted by personnel familiar with the permittee's visible emissions. The permittee shall maintain personnel trained in EPA Reference Method 9. Ifvisible emissions which appear to be in excess ofthe permitted opacity are detected, the permittee shall immediately take action to identify the cause ofthe visible emissions, implement corrective action, and document that visible emissions did not appear to be in excess ofthe permitted opacity following the corrective action. The pennittee shall maintain records which contain the following items in order to demonstrate compliance with this specific condition. These records shall be updated weekly, kept on site, and made available to Department personnel upon request.

49 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

50 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

SN-77 Hull Loading Unit

Source Description

Hulls are loaded into trucks by an auger within a partially enclosed shed located outside Seed House #15.

Specific Conditions

44. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by Plant Wide Conditions 7, 8, and 9. [Regulation 19 §19.501 et seq. and 40 CFR Part 52, Subpart E]

SN Description Pollutant lb/hr tpy

77 Hull Loading Unit PM 10 1.5 1.4

45. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by Plant Wide Conditions 7, 8, and 9. [Regulation 18 §18.801 and A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311]

SN Description Pollutant lb/hr tpy 77 Hull Loading Unit PM 4.3 4.1

51 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

SN-39 and 40 Sacked Hull Houses

Source Description

The Sacked Hull House processes are similar to the Bulk Hull House except that the hulls are stored in a bin until they are fed to hull sacker machines. This process allows the hulls to be sold in smaller, sacked quantities. Cyclones H-22 and H-23 are used in this process. These sources were installed in 1993. Emissions from these cyclones are routed to Rotary Drum Filter (SN 58).

52 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

SN-44 and 45 Boilers #1 and #2

Source Description

SN-44 and SN-45 are natural gas fired boilers each rated at 20.922 MMBtu/hr. Boiler #1 (SN 44) was replaced in October of2002. Boiler #2 (SN-45) was overhauled in 2002.

Specific Conditions

46. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by permitting these sources at their maximum capacity. [Regulation 19, §19.501 et seq. and 40 CFR Part 52, Subpart E]

SN Description Pollutant lb/hr tpy PMIO 0.2 0.7 S02 0.1 0.1 VOC 0.2 0.5 44 Boiler #1 CO 1.8 7.7

NOx 2.1 9.2 Lead 1.1E-5 4.6E-5 PMIO 0.2 0.7 S02 0.1 0.1 VOC 0.2 0.5 45 Boiler #2 CO 1.8 7.7

NOx 2.1 9.2 Lead 1.1E-5 4.6E-5

47. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by permitting these sources at their maximum capacity. [Regulation 18, §18.801 and A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

SN Description Pollutant Ib/hr tpy PM 0.2 0.7 Arsenic 4.2E-6 1.9E-5 Beryllium 2.6E-7 1.1E-6 44 Boiler #1 Cadmium 2.3E-5 1.0E-4 Hexane 0.04 0.20 Manganese 8.0E-6 3.5E-5 Mercury 5.4E-6 2.4E-5

53 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

SN Description Pollutant lb/hr tpy PM 0.2 0.7 Arsenic 4.2E-6 1.9E-5 Beryllium 2.6E-7 1.1E-6 45 Boiler #2 Cadmium 2.3E-5 1.0E-4 Hexane 0.04 0.20 Manganese 8.0E-6 3.5E-5 Mercury 5.4E-6 2.4E-5

48. Visible emissions may not exceed the limits specified in the following table ofthis permit as measured by EPA Reference Method 9.

SN Limit Regulatory Citation 44&45 5% §18.501

49. Natural gas shall be the only source offuel used in SN-44 and SN-45. Pipeline natural gas is defined as a natural gas which contains 0.5 grains or less oftotal sulfur per 100 standard cubic feet, and pipeline natural gas must either be composed ofat least 70 percent methane by volume or have a gross calorific value between 950 and 1100 Btu per standard cubic foot. [Regulation 19, §19.705, AC.A §8-4-203 as referenced by §8-4 304 and §8-4-311, and 40 CFR 70.6]

50. SN-44 and SN-45 are affected units of40 CFR 60, Subpart Dc-Standards ofPerformance for Small Industrial-Commercial-Institutional Steam Generating Units because they were constructed after June 9,1989. [Regulation 19, §19.304 and 40 CFR 60, Subpart De Standards ofPerformance for Small Industrial-Commercial-Institutional Steam Generating Units Appendix A]

51. The owner or operator ofSN-44 and SN-45 shall record and maintain records ofthe amounts ofeach fuel combusted every month. All records offuel combusted shall be maintained by the owner or operator for a period oftwo years following the date ofsuch record. [Regulation 19, §19.304 and 40 CFR 60, §60.48c (g)(2)]

54 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

SN-47 Bulk House Cooling Fans

Source Description

SN-47 is the combined emissions ofnineteen seed cooling fans located at Planter's locations in town. Seed houses #5-# 10 are located at the Lower Mill (LM) on Michigan Street, seed houses #11-#13 are located at the Old Mill (OM) on East 5th Avenue and seed houses #14-#18 are located at the Active Mill (AM). The fans are used to blow air through the cottonseed in order to remove moisture. Cotton seed, meal, and hulls are all stored in the houses at different times. The fans are only used when the cottonseed is in the houses. These sources were installed in 1993. Source testing was performed on one ofthe fans in December of200 1.

Specific Conditions

52. The permittee shall not exceed the emission rates set forth in the following table. Emissions are based on equipment specifications. [Regulation 19, §19.501 et seq. and 40 CFR Part 52, Subpart E]

SN Description Pollutant lb/hr tpy LM Seed House #5 PM IO LM Seed House #6 PM IO LM Seed House #7 PM IO 47-LM LM Seed House #8 PM IO LM Seed House #9 PM IO LM Seed House #10 PM IO OM Seed House #11 PM IO OM Seed House #12-A PM IO 47-0M OM Seed House #12-B PM IO OM Seed House #13 PMIO 2.4 10.6

AM Seed House #14 PM lO AM Seed House #15-A PM IO AM Seed House #15-B PM IO AM Seed House #16-A PM IO 47-AM AM Seed House #16-B PM IO AM Seed House #17-A PM IO AM Seed House #17-B PM IO AM Seed House #18-A PMIO AM Seed House #18-B PM IO

53. The permittee shall not exceed the emission rates set forth in the following table. Emissions are based on equipment specifications. [Regulation 18, §18.801 and A C.A §8-4-203 as referenced by AC.A. §8-4-304 and §8-4-311]

55 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

SN Description Pollutant lb/hr tpy LM Seed House #5 PM LM Seed House #6 PM LM Seed House #7 PM 47-LM LM Seed House #8 PM LM Seed House #9 PM LM Seed House #10 PM OM Seed House #11 PM OM Seed House #12-A PM 47-0M OM Seed House #12-B PM OM Seed House #13 PM 6.9 30.0 AM Seed House #14 PM AM Seed House #15-A PM AM Seed House #15-B PM AM Seed House #16-A PM 47-AM AM Seed House #16-B PM AM Seed House #17-A PM AM Seed House #17-B PM AM Seed House #18-A PM AM Seed House #18-B PM

54. Visible emissions may not exceed the limits specified in the following table ofthis permit as measured by EPA Reference Method 9.

SN Limit Regulatory Citation 47-LM 5% §18.501 47-0M 5% §18.501 47-AM 5% §18.501

55. Weekly observations ofthe opacity from SN-47 shall be conducted by personnel familiar with the permittee's visible emissions. The permittee shall maintain personnel trained in EPA Reference Method 9. Ifvisible emissions which appear to be in excess ofthe permitted opacity are detected, the permittee shall immediately take action to identify the cause ofthe visible emissions, implement corrective action, and document that visible emissions did not appear to be in excess ofthe permitted opacity following the corrective action. The permittee shall maintain records which contain the following items in order to demonstrate compliance with this specific condition. These records shall be updated weekly, kept on site, and made available to Department personnel upon request. a. The date and time ofthe observation; b. Ifvisible emissions which appeared to be above the permitted limit were detected; c. The cause ofthe exceedance ofthe opacity limit; d. The corrective action taken;

56 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

e. Ifthe visible emissions appeared to be below the permitted limit after the corrective action was taken; and f. The name ofthe person conducting the opacity observations. [Regulation 19, §19.705, A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311, and 40 CFR 70.6]

57 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

SN-55 and 61 Trash Beaters #1 and #2

Source Description

Trash Beater #1 is controlled by the bran and pepper cyclone (Cyclone B-1) which collects wastes from the bran and pepper shaker unit. Trash Beater #2 is controlled by the lint and motes cyclone (Cyclone B-3) which collects trash that is removed by the lint and motes trash shaker. These sources divide the trash reclaiming load between the Lint, Bran & Pepper. These sources were installed in 1993. Emissions from these cyclones were routed to Rotary Drum Filter #3, SN-64.

58 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

SN-58 (RFD-l) & SN-59 (RFD-2) Rotary Drum Filters #1 and #2

Source Description

Source number SN-58 is an Outravacw Model 12-10 drum filter that was installed in 2000 in order to reduce particulate matter emissions from the facility. This drum filter was installed to pick up emissions from the Meal Loading Enclosure Cyclone (SN-36), Hull Loading Enclosure Cyclone (SN-39) and Sacked Hull House Cyclone (SN-40). The outlet for RDF-l is rated at 67,000 cfm.

Source number SN-59 was also installed in 2000 in order to reduce particulate matter emissions from the facility. This drum filter was installed to pick up emissions from the Baling Press Cyclones (SN-16 & 17). This drum filters' self-cleaning (stripper) system includes a cyclone and fan. The cyclone and fan discharges air to the drum filter and the material collected in the bottom ofthe stripper cyclone is pneumatically conveyed back to the process (i.e., the baling press room) after dropping through the airlock at the bottom ofthe cyclone. An air pickup system was added to the truck dump enclosure to control dust generated when trucks are unloaded. The outlet for RDF-2 is rated at 50,000 cfm.

Specific Conditions

56. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by compliance with Plant Wide Conditions 7, 8, and 9. [Regulation 19, §19.501 et seq. and 40 CFR Part 52, Subpart E]

SN Description Pollutant lb/hr tpy 58 Rotary Drum Filter #1 PM IO 0.5 2.1 59 Rotary Drum Filter #2 PMIO 0.4 1.6

57. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by Plant Wide Conditions 7, 8, and 9. [Regulation 18, §18.801 and A.C.A. §8-4-203 as referenced by A.C.A. §8-4 304 and §8-4-311]

SN Description Pollutant Ib/hr tpy 58 Rotary Drum Filter #1 PM 1.2 5.1 59 Rotary Drum Filter #2 PM 0.9 4.0

58. Visible emissions may not exceed the limits specified in the following table ofthis permit as measured by EPA Reference Method 9.

59 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

SN Limit Regulatory Citation 58 & 59 10% §18.501

59. Weekly observations ofthe opacity from SN-58 and SN-59 shall be conducted by personnel familiar with the permittee's visible emissions. The permittee shall maintain personnel trained in EPA Reference Method 9. Ifvisible emissions which appear to be in excess ofthe permitted opacity are detected, the permittee shall immediately take action to identify the cause ofthe visible emissions, implement corrective action, and document that visible emissions did not appear to be in excess ofthe permitted opacity following the corrective action. The permittee shall maintain records which contain the following items in order to demonstrate compliance with this specific condition. These records shall be updated weekly, kept on site, and made available to Department personnel upon request. g. The date and time ofthe observation; h. Ifvisible emissions which appeared to be above the permitted limit were detected;

1. The cause ofthe exceedance ofthe opacity limit; J. The corrective action taken; k. Ifthe visible emissions appeared to be below the permitted limit after the corrective action was taken; and 1. The name ofthe person conducting the opacity observations. [Regulation 19, §19.705, A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311, and 40 CFR 70.6]

60 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

SN-60 Portable Material Loading Units

Source Description

Portable mobile units are used to load cottonseed, meal, and lor hulls into trucks. The mobile conveyors can load a maximum of75 tons per hour each. A maximum of22,500 tons of material are loaded annually. These portable material loading units (SN-60) were reclassified as an Insignificant Activity (A-B) with the 2005 permit renewal (l427-AOP-R7). There are three larger units and one smaller unit in the black seed area.

61 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

SN-62 Protein Shakers (Cyclone PS-l)

Source Description

The Protein Shakers remove excess hulls and large fiber from the meat and are mixed back into the finished hull product. The addition oftwo (2) Protein Shakers helps maintain a higher protein content and improves the quality ofthe finished meal product. The exhausts from each Protein Shaker are routed through the Baghouse, SN-74. SN-62 unit was installed in 2004.

62 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

SN-63 Trash Shaker Receiving

Source Description

The trash shaker receiving cyclone is used to collect waste from the lint cleaners. The unit was installed in 1993. Emissions are controlled and routed through the Baghouse, SN-74.

63 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

SN-64 Rotary Drum Filter (RDF-3)

Source Description

Rotary Drum Filter #3 (SN-64), installed in 2005, reduces particulate emissions from the facility. It collects emissions from the 1st and 2nd Cut Linter Machines (SN-01 thru SN-04), Salvage Reclaim (SN-05 and SN-14), Recycling (SN-15), Recycling System (SN-52), Trash Beaters #1 and #2 (SN-55 and SN-61). The outlet for RDF-3 is rated at 170,000 cfm but tested at 181,200 cfm on June 15-16,2005.

Specific Conditions

60. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by compliance with Plant Wide Conditions 7,8, and 9. [Regulation 19, §19.501 et seq. and 40 CFR Part 52, Subpart E]

SN Description Pollutant lb/hr tpy 64 Rotary Drum Filter (RDF-3) PMIO 1.3 5.5

61. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by compliance with Plant Wide Conditions 7,8, and 9. [Regulation 18, §18.801 and A.C.A. §8-4-203 as referenced by A.c.A. §8-4-304 and §8-4-311]

SN Description Pollutant lb/hr tpy 64 Rotary Drum Filter (RDF-3) PM 3.1 13.6

62. Visible emissions may not exceed the limits specified in the following table ofthis permit as measured by EPA Reference Method 9.

SN Limit Regulatory Citation 64 10% §18.501

63. Weekly observations ofthe opacity from SN-64 shall be conducted by personnel familiar with the permittee's visible emissions. The permittee shall maintain personnel trained in EPA Reference Method 9. Ifvisible emissions which appear to be in excess ofthe permitted opacity are detected, the permittee shall immediately take action to identify the cause ofthe visible emissions, implement corrective action, and document that visible emissions did not appear to be in excess ofthe permitted opacity following the corrective action. The permittee shall maintain records which contain the following items in order to demonstrate compliance with this specific condition. These records shall be updated weekly, kept on site, and made available to Department personnel upon request.

64 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

m. The date and time ofthe observation; n. Ifvisible emissions which appeared to be above the permitted limit were detected; o. The cause ofthe exceedance ofthe opacity limit; p. The corrective action taken; q. Ifthe visible emissions appeared to be below the permitted limit after the corrective action was taken; and r. The name ofthe person conducting the opacity observations. [Regulation 19, §19.705, A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311, and 40 CFR 70.6]

65 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

SN-65 through SN-71 Hull Shaker Fans, Cascade Fans, and Hull Shaker/Cascade Fans

Source Description

Seven (7) fans (SNs-65 through 71) are used for additional air handling and aspiration in the processes at Planters. These emissions are controlled by high efficiency cyclones and previously ducted to Rotary Drum Filter #3 (RDF-3). To increase performance efficiency, these sources will now be routed to a dedicated baghouse (SN-74). Each cyclone is rated at 8,500 cfm.

66 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

SN-73 Black Cotton Seed Tank

Source Description

Clean cotton seed is stored in this tank prior to processing, when necessary. Black cotton seed is seed with all lint and debris removed. This tank is equipped with a bin vent filter.

Specific Conditions

64. The permittee shall not exceed the emission rates set forth in the following table. The emission limits are based an equipment capacity of8.5 tons ofseed per hour fed into the tank. [Regulation 19, §19.501 et seq. and 40 CFR Part 52, Subpart E]

SN Description Pollutant lb/hr tpy

73 Black Cotton Seed Tank PM10 0.1 0.1

65. The permittee shall not exceed the emission rates set forth in the following table. The emission limits are based an equipment capacity of 8.5 tons ofseed per hour fed into the tank. [Regulation 18, §18.801, and A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

SN Description Pollutant lb/hr tpy

73 Black Cotton Seed Tank PM 0.1 0.2

66. Visible emissions may not exceed the limits specified in the following table ofthis permit as measured by EPA Reference Method 9.

SNs Limit Regulatory Citation 73 5% §18.501

67. Weekly observations ofthe opacity from SN-73 shall be conducted by personnel familiar with the permittee's visible emissions. The permittee shall maintain personnel trained in EPA Reference Method 9. Ifvisible emissions which appear to be in excess ofthe permitted opacity are detected, the permittee shall immediately take action to identify the cause ofthe visible emissions, implement corrective action, and document that visible emissions did not appear to be in excess ofthe permitted opacity following the corrective action. The permittee shall maintain records which contain the following items in order to demonstrate compliance with this specific condition. These records shall be updated weekly, kept on site, and made available to Department personnel upon request.

67 Planters Cotton Oil Mill, Inc. Permit #: l427-AOP-R12 AFIN: 35-00025

s. The date and time ofthe observation; 1. Ifvisible emissions which appeared to be above the permitted limit were detected; u. The cause ofthe exceedance ofthe opacity limit; v. The corrective action taken; w. Ifthe visible emissions appeared to be below the permitted limit after the corrective action was taken; and x. The name ofthe person conducting the opacity observations. [Regulation 19, §19.705, A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311, and 40 CFR 70.6]

68 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

SN-74 Baghouse

Source Description

The baghouse controls emissions from the Protein Shakers (SN-62), Trash Shaker Receiving (SN-63), Hull Shaker Fans (SN-65 and SN-66), and Air Cascade Fans (SN-67 through SN-71). The baghouse was installed in 2012 and the source was tested in November of2012.

Specific Conditions

68. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by compliance with Plant Wide Conditions 7, 8, and 9. [Regulation 19 §19.501 et seq. and 40 CFR Part 52, Subpart E]

SN Description Pollutant lb/hr tpy

74 Baghouse PMlO 0.1 0.1

69. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by compliance with Plant Wide Conditions 7,8, and 9. [Regulation 18 §18.801 and A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-31l]

SN Description Pollutant lb/hr tpy 74 Baghouse PM 0.1 0.5

70. Visible emissions may not exceed the limits specified in the following table ofthis permit as measured by EPA Reference Method 9.

SN Limit Regulatory Citation 74 5% §18.501

71. Weekly observations ofthe opacity from SN-74 shall be conducted by personnel familiar with the permittee's visible emissions. The permittee shall maintain personnel trained in EPA Reference Method 9. Ifvisible emissions which appear to be in excess ofthe permitted opacity are detected, the permittee shall immediately take action to identify the cause ofthe visible emissions, implement corrective action, and document that visible emissions did not appear to be in excess ofthe permitted opacity following the corrective action. The permittee shall maintain records which contain the following items in order

69 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

to demonstrate compliance with this specific condition. These records shall be updated weekly, kept on site, and made available to Department personnel upon request. y. The date and time ofthe observation; z. Ifvisible emissions which appeared to be above the permitted limit were detected; aa. The cause ofthe exceedance ofthe opacity limit; bb. The corrective action taken; cc. Ifthe visible emissions appeared to be below the permitted limit after the corrective action was taken; and dd. The name ofthe person conducting the opacity observations. [Regulation 19, §19.705, A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311, and 40 CFR 70.6]

70 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

SN-75 Pellet Mill Storage

Source Description

The pellet mill is an enclosed system with one point routed to SN-58. Pellets are auger fed to a pelletizer then sent to storage silos. The storage silos have six vents to the atmosphere.

Specific Conditions

72. The permittee shall not exceed the emission rates set forth in the following table. Hourly and annual emissions are based on the capacity ofthe pelletizer. [Regulation 19 §19.501 et seq. and 40 CFR Part 52, Subpart E]

SN Description Pollutant lb/hr tpy

75 Pellet Mill Storage PM lO 0.1 0.2

73. The permittee shall not exceed the emission rates set forth in the following table. Hourly and annual emissions are based on the capacity ofthe pelletizer. [Regulation 18 §18.801 and A.c.A. §8-4-203 as referenced by §8-4-304 and §8-4-311]

SN Description Pollutant lb/hr tpy

75 Pellet Mill Storage PM 0.2 0.7

71 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

SN-76 Cooling Tower

Source Description

The cooling tower is located just east ofthe hexane system building. SN-76 is utilized for cooling the cottonseed oil and for cooling in hexane recovery.

Specific Conditions

74. The permittee shall not exceed the emission rates set forth in the following table. Hourly and annual emissions are based on the capacity ofthe equipment. [Regulation 19 §19.501 et seq. and 40 CFR Part 52, Subpart E]

SN Description Pollutant lblhr tpy

76 Cooling Tower PMIO 0.7 2.7

75. The permittee shall not exceed the emission rates set forth in the following table. Hourly and annual emissions are based on the capacity ofthe equipment. [Regulation 18 §18.801 and A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311]

SN Description Pollutant lb/hr tpy

76 Cooling Tower PM 4.1 18.0

76. Visible emissions may not exceed the limits specified in the following table ofthis permit as measured by EPA Reference Method 9.

SN Limit Regulatory Citation

76 20% §18.501

77. Weekly observations ofthe opacity from SN-76 shall be conducted by personnel familiar with the permittee's visible emissions. The permittee shall maintain personnel trained in EPA Reference Method 9. Ifvisible emissions in excess ofthe permitted levels are detected, the permittee shall immediately take action to identify the cause ofthe visible emissions in excess ofthe permit limit, implement corrective action, and document that visible emissions did not appear to be in excess ofthe permitted opacity following the corrective action. The permittee shall maintain records which contain the following items in order to demonstrate compliance with this specific condition. These records shall be updated weekly, kept on site, and made available to Department personnel upon request.

72 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

a. The date and time ofthe observation; b. Ifvisible emissions which appeared to be above the permitted limit were detected; c. The cause ofthe exceedance ofthe opacity limit; d. The corrective action taken; e. Ifvisible emissions appeared to be below the permitted limit after the corrective action was taken; and f. The name ofthe person conducting the opacity observations.

[Regulation 19, §19.705, A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311, and 40 CFR 70.6]

73 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

SN-78 Shipping Conveyor

Source Description

The Shipping Conveyor is a drag conveyor that was installed in the shipping area in 2010.

Specific Conditions

78. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by Specific Condition 80. [Regulation 19 §19.501 et seq. and 40 CFR Part 52, Subpart E]

SN Description Pollutant lb/hr tpy

78 Shipping Conveyor PM 10 0.2 0.3

79. The permittee shall not exceed the emission rates set forth in the following table. The permittee shall demonstrate compliance with this condition by Specific Condition 80. [Regulation 18 §18.80l and AC.A §8-4-203 as referenced by §8-4-304 and §8-4-3ll]

SN Description Pollutant lb/hr tpy

78 Shipping Conveyor PM 0.5 0.9

80. The permittee shall not exceed a throughput of20,000 tons ofhulls and meal, combined per consecutive twelve month period at SN-78. Compliance shall be demonstrated through the record keeping requirement set forth in Specific Condition 81. [Regulation 19, §19.705, AC.A §8-4-203 as referenced by AC.A §8-4-304 and §8-4-31l and 40 CFR 70.6]

81. Records demonstrating compliance with Specific Condition 80 shall be maintained on a twelve-month rolling total basis and updated monthly by the is" ofthe month following the month to which the records pertain. Records shall be kept on site and made available to the Department upon request. [Regulation 19, §19.705 and 40 CFR Part 52, Subpart E]

74 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

SECTION V: COMPLIANCE PLAN AND SCHEDULE

Planters Cotton Oil Mill, Inc. will continue to operate in compliance with those identified regulatory provisions. The facility will examine and analyze future regulations that may apply and determine their applicability with any necessary action taken on a timely basis.

75 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

SECTION VI: PLANTWIDE CONDITIONS

1. The permittee shall notify the Director in writing within thirty (30) days after commencing construction, completing construction, first placing the equipment and/or facility in operation, and reaching the equipment and/or facility target production rate. [Regulation 19, §19.704, 40 CFR Part 52, Subpart E, and A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

2. Ifthe permittee fails to start construction within eighteen months or suspends construction for eighteen months or more, the Director may cancel all or part ofthis permit. [Regulation 19, §19,410(B) and 40 CFR Part 52, Subpart E]

3. The permittee must test any equipment scheduled for testing, unless otherwise stated in the Specific Conditions ofthis permit or by any federally regulated requirements, within the following time frames: (1) new equipment or newly modified equipment within sixty (60) days ofachieving the maximum production rate, but no later than 180 days after initial startup ofthe permitted source or (2) operating equipment according to the time frames set forth by the Department or within 180 days ofpermit issuance ifno date is specified. The permittee must notify the Department ofthe scheduled date ofcompliance testing at least fifteen (15) business days in advance ofsuch test. The permittee shall submit the compliance test results to the Department within thirty (30) calendar days after completing the testing. [Regulation 19, §19.702 and/or Regulation 18 §18.l002 and A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

4. The permittee must provide:

a. Sampling ports adequate for applicable test methods; b. Safe sampling platforms; c. Safe access to sampling platforms; and d. Utilities for sampling and testing equipment.

[Regulation 19, §19.702 and/or Regulation 18, §18.1002 and A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

5. The permittee must operate the equipment, control apparatus and emission monitoring equipment within the design limitations. The permittee shall maintain the equipment in good condition at all times. [Regulation 19, §19.303 and A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

6. This permit subsumes and incorporates all previously issued air permits for this facility. [Regulation 26 and A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

7. The throughput ofcottonseed at the facility shall be limited to 350,000 tons per consecutive twelve month period. Compliance shall be demonstrated through record

76 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

keeping requirements set forth in Plant Wide Condition 8. [Regulation 19, §19.705, AC.A §8-4-203 as referenced by AC.A §8-4-304 and §8-4-311 and 40 CFR 70.6]

8. Records demonstrating compliance with Plant Wide Condition 7 shall be maintained on a twelve-month rolling total basis, updated monthly, kept on site and made available to the Department upon request. The permittee shall submit a semi-annual report including cottonseed throughput to the Department as set forth in General Provision 7. [Regulation 19, §19.705 and 40 CFR Part 52, Subpart E]

9. The cyclones and filters associated with this plant shall be maintained and operated in serviceable condition as prescribed by the manufacturer during operation ofthe sources at the facility. Each cyclone or filter shall be inspected no less than one time per week to ensure that it is in good working condition. Each inspection shall be documented. Records shall be maintained on a consecutive twelve month rolling schedule and shall be updated upon the completion ofeach weekly inspection, kept on site and made available to the Department upon request. [Regulation 18, §18.1104 and AC.A §8-4-203 as referenced by §8-4-304 and §8-4-311]

10. Planters Cotton Oil Mill shall comply with the requirements of40 CFR 63, Subpart GGGG - National Emission Standards for Hazardous Air Pollutants: Solvent Extraction for Vegetable Oil Production. These requirements include, but are not limited to the conditions listed in Plant Wide Conditions 11 through 22. [Regulation 19, §19.304 and 40 CFR 63]

11. For each operating month, the facility must calculate the compliance ratio which compares actual HAP loss to allowable HAP loss for the previous 12 operating months. An operating month, as defined in §63.2872, is any calendar month in which a source processes a listed oilseed, excluding any entire calendar month in which the source operated under an initial startup period subject to §63.2850(c)(2) r (d)(2) or a malfunction period subject to §63.2850(e)(2). [Regulation 19, §19.304 and 40 CFR §63.2840 (a)(I) and (a)(2)]

f * Actual Solvent Loss Compliance Ratio n 0.64 * L:((Oilseed)i * (SLF)J i=l

Where: f = The weighted average volume fraction ofHAP in solvent received during the previous 12 operating months, as determined in §63.2854, dimensionless.

0.64 = The average volume fraction ofHAP in solvent in the baseline performance data, dimensionless.

77 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 APIN: 35-00025

Actual Solvent Loss = Gallons ofactual solvent loss during previous 12 operating months, as determined in §63.2853.

Oilseed = Tons ofcottonseed processed during the previous 12 operating months, as shown in §63.2855.

SLP = Oil seed loss factor = 0.5 gal/ton

12. When calculating the compliance ratio, the facility may consider the conditions and exclusions in paragraphs (b)(l) through (6) of40 CPR §63.2840. [Regulation 19, §19.304 and 40 CPR §63.2840(b)]

13. Ifthe compliance ratio is less than or equal to 1.00, the facility was in compliance with the HAP emission requirements for the previous operating month. [Regulation 19, 19.304 and 40 CPR §63.2840(c)]

14. The facility shall develop and implement a plan for demonstrating compliance in accordance with 40 CPR §63.2851. This plan shall be kept on site and available to Department personnel upon request. [Regulation 19, §19.304 and 40 CPR §63.2850(a)(2)]

15. The facility shall develop a written startup, shutdown and malfunction (SSM) plan in accordance with the provisions in 40 CPR §63.2852. This plan shall be kept on site and available to Department personnel upon request. [Regulation 19, §19.304 and 40 CPR §63.2850 (a)(3)]

16. The facility shall maintain all the necessary records used to demonstrate compliance with 40 CPR Part 63 Subpart GGGG in accordance with §63.2862. [Regulation 19, §19.304 and 40 CFR §63.2850(4)]

17. The facility shall submit the reports in paragraphs (a) through (c): [Regulation 19, §19.304 and 40 CPR §63.2850(a)(5)]

a. Annual compliance certifications in accordance with §63.2861(a).

b. Periodic SSM reports in accordance with §63.2861(c) ifthe facility operates under a malfunction period. The report shall be submitted by the end ofthe month following the calendar month in which the malfunction period occurred.

c. Immediate SSM reports in accordance with §63.2861(d) ifthe facility operates during a malfunction period differently from the procedures in the SSM plan. An immediate SSM report consists ofa telephone call or facsimile transmission to the Department within 2 working days after starting actions inconsistent with the SSM plan followed by a letter within 7 working days after the end ofthe event.

78 Planters Cotton Oil Mill, Inc. Permit #: l427-AOP-R12 AFIN: 35-00025

18. Ifthe compliance ratio exceeds 1.00, the facility shall report by the end ofthe month following the calendar month in which the deviation was determined. The deviation notification shall include items (b) (1) through (4) of40 CFR §63.2861. [Regulation 19, §19.304 and 40 CFR §63.2861(b)]

19,. The facility shall prepare a plan for demonstrating compliance (as described in §63.2851) and a SSM plan (as described in §63.2852). Complete both plans before the compliance date for the facility and keep them on-site and readily available as long as the source is operational. [Regulation 19, §19.304 and 40 CFR §63.2862(b)]

20. Ifthe facility processes any listed oil seed, record the items in paragraphs(c)(1) through (5) of§63.2862. [Regulation 19, §19.304 and 40 CFR §63.2862(c)]

21. After the facility has processed listed oilseed for 12 operating months, and is not operating during an initial startup period as described in §63.2850(c)(2) or (d)(2), or a malfunction period as described in §63.2850(e)(2), record the items in paragraphs (d)(1) through (5) of §63.2862 by the end ofthe calendar month following each operating month. [Regulation 19, §19.304 and 40 CFR §63.2862(d)]

22. For each SSM event subject to an initial startup period as described in §63.2850(c)(2) or (d)(2), or a malfunction period as described in §63.2850(e)(2), record the items in paragraphs (a) through (c) by the end ofthe calendar month following each month in which the initial startup period or malfunction period occurred. [Regulation 19, §19.304 and 40 CFR §63.2862(e)]

a. A description and date ofthe SSM event, its duration, and reason it qualifies as an initial startup or malfunction.

b. An estimate ofthe solvent loss in gallons for the duration ofthe initial startup or malfunction period with supporting documentation.

c. A checklist or other mechanism to indicate whether the SSM plan was followed during the initial startup or malfunction period.

Permit Shield

23. Compliance with the conditions ofthis permit shall be deemed compliance with all applicable requirements, as ofthe date ofpermit issuance, included in and specifically identified in the following table ofthis condition. The permit specifically identifies the following as applicable requirements based upon the information submitted by the permittee in an application dated November 12,2009.

Applicable Regulations

Source No. I Regulation Description

79 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

Source No. Regulation Description Facility Arkansas Regulation 19 Compilation ofRegulations ofthe Arkansas State Implementation Plan for Air Pollution Control Facility Arkansas Regulation 26 Regulations ofthe Arkansas Operating Air Permit Program SN-44 & 45 40 CFR 60, Subpart De. Boilers SN-44 and SN-45 have heat input New Source Performance capacities>10 MMBtulhr and were installed Standards for Industrial- after 6/9/1989. The only substantial Commercial-Institutional requirement is monthly fuel usage Steam Generating Units recordkeeping pursuant to 60.48c(g). Solvent 40 CFR Part 63 Subpart Facility is subject. Existing facility Extraction GGGG. National Emission compliance deadline was 4/12/2004. Plant (SN- Standards for Hazardous Air 32,42,43, Pollutants: Solvent 56 and 46) Extraction for Vegetable Oil Production

The permit specifically identifies the following as inapplicable based upon information submitted by the permittee in an application dated November 12,2009.

Inapplicable Regulations

Source No. Regulation Description Facility 40 CFR Part 60, Subpart Subpart Kb exempts storage tanks covered Kb. Standards of under 40 CFR Part 63 Subpart GGGG. Performance for Volatile Organic Liquid Storage Cottonseed oil and all other tanks at facility Vessels have a design capacity < 75 m" and/or store liquids with maximum true vapor pressures < 3.5 kilopascals Facility 40 CFR Part 63 Subpart HAP (i.e., hexane) storage emissions EEEE. National Emission regulated under Part 63 Subpart GGGG. Standards for Hazardous Air Pollutants (NESHAP): Organic Liquids Distribution Facility 40 CFR Part 64. Emission units at the facility are not subject to Compliance Assurance CAM. Cyclones and drum filters are Monitoring considered "inherent process equipment" under the CAM rule. The cyclones are part of pneumatic conveying systems, and the drum filters collect product for sale. These units are not pollution control devices.

80 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

Title VI Provisions

24. The permittee must comply with the standards for labeling ofproducts using ozone depleting substances. [40 CFR Part 82, Subpart E]

a. All containers containing a class I or class II substance stored or transported, all products containing a class I substance, and all products directly manufactured with a class I substance must bear the required warning statement ifit is being introduced to interstate commerce pursuant to §82.106. b. The placement ofthe required warning statement must comply with the requirements pursuant to §82.108. c. The form ofthe label bearing the required warning must comply with the requirements pursuant to §82.l1 O. d. No person may modify, remove, or interfere with the required warning statement except as described in §82.l12.

25. The permittee must comply with the standards for recycling and emissions reduction, except as provided for MVACs in Subpart B. [40 CFR Part 82, Subpart F]

a. Persons opening appliances for maintenance, service, repair, or disposal must comply with the required practices pursuant to §82.156. b. Equipment used during the maintenance, service, repair, or disposal ofappliances must comply with the standards for recycling and recovery equipment pursuant to §82.l58. c. Persons performing maintenance, service repair, or disposal ofappliances must be certified by an approved technician certification program pursuant to §82.161. d. Persons disposing ofsmall appliances, MVACs, and MVAC like appliances must comply with record keeping requirements pursuant to §82.166. ("MVAC like appliance" as defined at §82.152) e. Persons owning commercial or industrial process refrigeration equipment must comply with leak repair requirements pursuant to §82.156. f. Owners/operators ofappliances normally containing 50 or more pounds of refrigerant must keep records ofrefrigerant purchased and added to such appliances pursuant to §82.166.

26. Ifthe permittee manufactures, transforms, destroys, imports, or exports a class I or class II substance, the permittee is subject to all requirements as specified in 40 CFR Part 82, Subpart A, Production and Consumption Controls.

27. Ifthe permittee performs a service on motor (fleet) vehicles when this service involves ozone depleting substance refrigerant (or regulated substitute substance) in the motor vehicle air conditioner (MVAC), the permittee is subject to all the applicable

81 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-R12 AFIN: 35-00025

requirements as specified in 40 CFR part 82, Subpart B, Servicing ofMotor Vehicle Air Conditioners.

The term "motor vehicle" as used in Subpart B does not include a vehicle in which final assembly ofthe vehicle has not been completed. The term "MVAC" as used in Subpart B does not include the air tight sealed refrigeration system used as refrigerated cargo, or the system used on passenger buses using HCFC 22 refrigerant.

28. The permittee can switch from any ozone depleting substance to any alternative listed in the Significant New Alternatives Program (SNAP) promulgated pursuant to 40 CFR Part 82, Subpart G.

82 Planters Cotton Oil Mill, Inc. Permit #: l427-AOP-RI2 AFIN: 35-00025

SECTION VII: INSIGNIFICANT ACTIVITIES

The following sources are insignificant activities. Any activity that has a state or federal applicable requirement shall be considered a significant activity even ifthis activity meets the criteria of §26.304 ofRegulation 26 or listed in the table below. Insignificant activity determinations rely upon the information submitted by the permittee in applications dated November 12, 2009 and May 16,2013.

Description Category Cottonseed Oil Tanks A-3 Hexane Tanks (not vented) A-13 Miscella Tanks (not vented) A-13 Portable Material Loaders (SN-60) A-13 Air Dryer for Pellet Cooler A-13 Cooker Cooling Air Exhaust A-13 Clay tanks (2) with bin vent filters A-13 Bulk Meal House A-13 Meal Conveyor to Bulk Meal House A-13

83 Planters Cotton Oil Mill, Inc. Permit #: l427-AOP-R12 AFIN: 35-00025

SECTION VIII: GENERAL PROVISIONS

1. Any terms or conditions included in this permit which specify and reference Arkansas Pollution Control & Ecology Commission Regulation 18 or the Arkansas Water and Air Pollution Control Act (A.C.A. §8-4-101 et seq.) as the sole origin of and authority for the terms or conditions are not required under the Clean Air Act or any ofits applicable requirements, and are not federally enforceable under the Clean Air Act. Arkansas Pollution Control & Ecology Commission Regulation 18 was adopted pursuant to the Arkansas Water and Air Pollution Control Act (AC.A §8-4-101 et seq.). Any terms or conditions included in this permit which specify and reference Arkansas Pollution Control & Ecology Commission Regulation 18 or the Arkansas Water and Air Pollution Control Act (AC.A §8-4-101 et seq.) as the origin ofand authority for the terms or conditions are enforceable under this Arkansas statute. [40 CFR 70.6(b)(2)]

2. This permit shall be valid for a period offive (5) years beginning on the date this permit becomes effective and ending five (5) years later. [40 CFR 70.6(a)(2) and Regulation 26 §26.701(B)]

3. The permittee must submit a complete application for permit renewal at least six (6) months before permit expiration. Permit expiration terminates the permittee's right to operate unless the permittee submitted a complete renewal application at least six (6) months before permit expiration. Ifthe permittee submits a complete application, the existing permit will remain in effect until the Department takes final action on the renewal application. The Department will not necessarily notify the permittee when the permit renewal application is due. [Regulation 26 §26.406]

4. Where an applicable requirement ofthe Clean Air Act, as amended, 42 U.S.C. 7401, et seq. (Act) is more stringent than an applicable requirement ofregulations promulgated under Title IV ofthe Act, the permit incorporates both provisions into the permit, and the Director or the Administrator can enforce both provisions. [40 CFR 70.6(a)(l)(ii) and Regulation 26 §26.701(A)(2)]

5. The permittee must maintain the following records ofmonitoring information as required by this permit.

a. The date, place as defined in this permit, and time of sampling or measurements; b. The date(s) analyses performed; c. The company or entity performing the analyses; d. The analytical techniques or methods used; e. The results ofsuch analyses; and f. The operating conditions existing at the time ofsampling or measurement.

[40 CFR 70.6(a)(3)(ii)(A) and Regulation 26 §26.70l(C)(2)]

84 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

6. The permittee must retain the records ofall required monitoring data and support information for at least five (5) years from the date ofthe monitoring sample, measurement, report, or application. Support information includes all calibration and maintenance records and all original strip chart recordings for continuous monitoring instrumentation, and copies ofall reports required by this permit. [40 CFR 70.6(a)(3)(ii)(B) and Regulation 26 §26.701(C)(2)(b)]

7. The permittee must submit reports ofall required monitoring every six (6) months. Ifthe permit establishes no other reporting period, the reporting period shall end on the last day ofthe month six months after the issuance ofthe initial Title V permit and every six months thereafter. The report is due on the first day ofthe second month after the end of the reporting period. The first report due after issuance ofthe initial Title V permit shall contain six months ofdata and each report thereafter shall contain 12 months ofdata. The report shall contain data for all monitoring requirements in effect during the reporting period. Ifa monitoring requirement is not in effect for the entire reporting period, only those months ofdata in which the monitoring requirement was in effect are required to be reported. The report must clearly identify all instances ofdeviations from permit requirements. A responsible official as defined in Regulation No. 26, §26.2 must certify all required reports. The permittee will send the reports to the address below:

Arkansas Department ofEnvironmental Quality Air Division ATTN: Compliance Inspector Supervisor 5301 Northshore Drive North Little Rock, AR 72118-5317

[40 CFR 70.6(a)(3)(iii)(A) and Regulation 26 §26.701(C)(3)(a)]

8. The permittee shall report to the Department all deviations from permit requirements, including those attributable to upset conditions as defined in the permit. a. For all upset conditions (as defined in RegulationI9, § 19.601), the permittee will make an initial report to the Department by the next business day after the discovery ofthe occurrence. The initial report may be made by telephone and shall include:

I. The facility name and location; ii. The process unit or emission source deviating from the permit limit; 111. The permit limit, including the identification ofpollutants, from which deviation occurs; IV. The date and time the deviation started; v. The duration ofthe deviation; VI. The average emissions during the deviation; VB. The probable cause ofsuch deviations; VBI. Any corrective actions or preventive measures taken or being taken to prevent such deviations in the future; and

85 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

IX. The name ofthe person submitting the report.

The permittee shall make a full report in writing to the Department within five (5) business days ofdiscovery ofthe occurrence. The report must include, in addition to the information required by the initial report, a schedule ofactions taken or planned to eliminate future occurrences and/or to minimize the amount the permit's limits were exceeded and to reduce the length oftime the limits were exceeded. The permittee may submit a full report in writing (by facsimile, overnight courier, or other means) by the next business day after discovery ofthe occurrence, and the report will serve as both the initial report and full report.

b. For all deviations, the permittee shall report such events in semi-annual reporting and annual certifications required in this permit. This includes all upset conditions reported in 8a above. The semi-annual report must include all the information as required by the initial and full reports required in 8a.

[Regulation 19 §19.601 and §19.602, Regulation 26 §26.701(C)(3)(b), and 40 CFR 70.6(a)(3)(iii)(B)]

9. Ifany provision ofthe permit or the application thereofto any person or circumstance is held invalid, such invalidity will not affect other provisions or applications hereof which can be given effect without the invalid provision or application, and to this end, provisions ofthis Regulation are declared to be separable and severable. [40 CFR 70.6(a)(5), Regulation 26 §26.701(E), and A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311]

10. The permittee must comply with all conditions ofthis Part 70 permit. Any permit noncompliance with applicable requirements as defined in Regulation 26 constitutes a violation ofthe Clean Air Act, as amended, 42 U.S.C. §7401, et seq. and is grounds for enforcement action; for permit termination, revocation and reissuance, for permit modification; or for denial ofa permit renewal application. [40 CFR 70.6(a)(6)(i) and Regulation 26 §26.701(F)(I)]

11. It shall not be a defense for a permittee in an enforcement action that it would have been necessary to halt or reduce the permitted activity to maintain compliance with the conditions ofthis permit. [40 CFR 70.6(a)(6)(ii) and Regulation 26 §26.701(F)(2)]

12. The Department may modify, revoke, reopen and reissue the permit or terminate the permit for cause. The filing of a request by the permittee for a permit modification, revocation and reissuance, termination, or ofa notification ofplanned changes or anticipated noncompliance does not stay any permit condition. [40 CFR 70.6(a)(6)(iii) and Regulation 26 §26.701(F)(3)]

13. This permit does not convey any property rights ofany sort, or any exclusive privilege. [40 CFR 70.6(a)(6)(iv) and Regulation 26 §26.701(F)(4)]

86 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

14. The permittee must furnish to the Director, within the time specified by the Director, any information that the Director may request in writing to determine whether cause exists for modifying, revoking and reissuing, or terminating the permit or to determine compliance with the permit. Upon request, the permittee must also furnish to the Director copies of records required by the permit. For information the permittee claims confidentiality, the Department may require the permittee to furnish such records directly to the Director along with a claim ofconfidentiality. [40 CFR 70.6(a)(6)(v) and Regulation 26 §26.701(F)(5)]

15. The permittee must pay all permit fees in accordance with the procedures established in Regulation 9. [40 CFR 70.6(a)(7) and Regulation 26 §26.701(G)]

16. No permit revision shall be required, under any approved economic incentives, marketable permits, emissions trading and other similar programs or processes for changes provided for elsewhere in this permit. [40 CFR 70.6(a)(8) and Regulation 26 §26.701(H)]

17. Ifthe permit allows different operating scenarios, the permittee shall, contemporaneously with making a change from one operating scenario to another, record in a log at the permitted facility a record ofthe operational scenario. [40 CFR 70.6(a)(9)(i) and Regulation 26 §26.701(I)(l)]

18. The Administrator and citizens may enforce under the Act all terms and conditions in this permit, including any provisions designed to limit a source's potential to emit, unless the Department specifically designates terms and conditions ofthe permit as being federally unenforceable under the Act or under any ofits applicable requirements. [40 CFR 70.6(b) and Regulation 26 §26.702(A) and (B)]

19. Any document (including reports) required by this permit must contain a certification by a responsible official as defined in Regulation 26, §26.2. [40 CFR 70.6(c)(l) and Regulation 26 §26.703(A)]

20. The permittee must allow an authorized representative ofthe Department, upon presentation ofcredentials, to perform the following: [40 CFR 70.6(c)(2) and Regulation 26 §26.703(B)] a. Enter upon the permittee's premises where the permitted source is located or emissions related activity is conducted, or where records must be kept under the conditions ofthis permit; b. Have access to and copy, at reasonable times, any records required under the conditions ofthis permit; c. Inspect at reasonable times any facilities, equipment (including monitoring and air pollution control equipment), practices, or operations regulated or required under this permit; and

87 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

d. As authorized by the Act, sample or monitor at reasonable times substances or parameters for assuring compliance with this permit or applicable requirements.

21. The permittee shall submit a compliance certification with the terms and conditions contained in the permit, including emission limitations, standards, or work practices. The permittee must submit the compliance certification annually. Ifthe permit establishes no other reporting period, the reporting period shall end on the last day ofthe anniversary month ofthe initial Title V permit. The report is due on the first day ofthe second month after the end ofthe reporting period. The permittee must also submit the compliance certification to the Administrator as well as to the Department. All compliance certifications required by this permit must include the following: [40 CFR 70.6(c)(5) and Regulation 26 §26.703(E)(3)] a. The identification ofeach term or condition ofthe permit that is the basis ofthe certification; b. The compliance status; c. Whether compliance was continuous or intermittent; d. The methodes) used for determining the compliance status ofthe source, currently and over the reporting period established by the monitoring requirements ofthis permit; and e. Such other facts as the Department may require elsewhere in this permit or by §114(a)(3) and §504(b) ofthe Act.

22. Nothing in this permit will alter or affect the following: [Regulation 26 §26.704(C)] a. The provisions ofSection 303 ofthe Act (emergency orders), including the authority ofthe Administrator under that section; b. The liability ofthe permittee for any violation ofapplicable requirements prior to or at the time ofpermit issuance; c. The applicable requirements ofthe acid rain program, consistent with §408(a) of the Act; or d. The ability ofEPA to obtain information from a source pursuant to §114 ofthe Act.

23. This permit authorizes only those pollutant emitting activities addressed in this permit. [A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311]

24. The permittee may request in writing and at least 15 days in advance ofthe deadline, an extension to any testing, compliance or other dates in this permit. No such extensions are authorized until the permittee receives written Department approval. The Department may grant such a request, at its discretion in the following circumstances: a. Such an extension does not violate a federal requirement; b. The permittee demonstrates the need for the extension; and c. The permittee documents that all reasonable measures have been taken to meet the current deadline and documents reasons it cannot be met.

88 Planters Cotton Oil Mill, Inc. Permit #: 1427-AOP-RI2 AFIN: 35-00025

[Regulation 18 §18.314(A), Regulation 19 §19.416(A), Regulation 26 §26.1013(A), AC.A §8-4-203 as referenced by §8-4-304 and §8-4-311, and 40 CFR Part 52, Subpart E]

25. The permittee may request in writing and at least 30 days in advance, temporary emissions and/or testing that would otherwise exceed an emission rate, throughput requirement, or other limit in this permit. No such activities are authorized until the permittee receives written Department approval. Any such emissions shall be included in the facility's total emissions and reported as such. The Department may grant such a request, at its discretion under the following conditions: a. Such a request does not violate a federal requirement; b. Such a request is temporary in nature; c. Such a request will not result in a condition ofair pollution; d. The request contains such information necessary for the Department to evaluate the request, including but not limited to, quantification ofsuch emissions and the date/time such emission will occur; e. Such a request will result in increased emissions less than five tons ofany individual criteria pollutant, one ton ofany single HAP and 2.5 tons oftotal HAPs; and f. The permittee maintains records ofthe dates and results ofsuch temporary emissions/testing.

[Regulation 18 §18.314(B), Regulation 19 §19.416(B), Regulation 26 §26.1013(B), AC.A §8-4-203 as referenced by §8-4-304 and §8-4-311, and 40 CFR Part 52, Subpart E]

26. The permittee may request in writing and at least 30 days in advance, an alternative to the specified monitoring in this permit. No such alternatives are authorized until the permittee receives written Department approval. The Department may grant such a request, at its discretion under the following conditions: a. The request does not violate a federal requirement; b. The request provides an equivalent or greater degree ofactual monitoring to the current requirements; and c. Any such request, ifapproved, is incorporated in the next permit modification application by the permittee.

[Regulation 18 §18.314(C), Regulation 19 §19.416(C), Regulation 26 §26.1013(C), AC.A §8-4-203 as referenced by §8-4-304 and §8-4-311, and 40 CFR Part 52, Subpart E]

89 Appendix A

40 CFR Part 60 Subpart De - Standards ofPerformance for Small Industrial-Commercial Institutional Steam Generating Units. Title 40: Protection of Environment PART 60-STANDARDS OF PERFORMANCE FOR NEW STATIONARY SOURCES

Subpart Dc-Standards of Performance for Small Industrial-Commercial-Institutional Steam Generating Units

Source: 72 FR 32759, June 13, 2007, unless otherwise noted.

§ 60.40c Applicability and delegation of authority.

(a) Except as provided in paragraphs (d), (e), (f), and (g) of this section, the affected facility to which this subpart applies is each steam generating unit for which construction, modification, or reconstruction is commenced after June 9, 1989 and that has a maximum design heat input capacity of 29 megawatts (MW) (100 million British thermal units per hour (MMBtu/h)) or less, but greater than or equal to 2.9 MW (10 MMBtu/h).

(b) In delegating implementation and enforcement authority to a State under section 111(c) of the Clean Air Act, §60.48c(a)(4) shall be retained by the Administrator and not transferred to a State.

(c) Steam generating units that meet the applicability requirements in paragraph (a) of this section are not subject to the sulfur dioxide (S02) or particulate matter (PM) emission limits, performance testing requirements, or monitoring requirements under this subpart (§60.42c, 60.43c, 60.44c, 60.45c, 60.46c, or 60.47c) during periods of combustion research, as defined in §60.41c.

(d) Any temporary change to an existing steam generating unit for the purpose of conducting combustion research is not considered a modification under §60.14.

(e) Affected facilities ( i.e. heat recovery steam generators and fuel heaters) that are associated with stationary combustion turbines and meet the applicability requirements of subpart KKKK of this part are not subject to this subpart. This subpart will continue to apply to all other heat recovery steam generators, fuel heaters, and other affected facilities that are capable of combusting more than or equal to 2.9 MW (10 MMBtu/h) heat input of fossil fuel but less than or equal to 29 MW (100 MMBtu/h) heat input of fossil fuel. If the heat recovery steam generator, fuel heater, or other affected facility is subject to this subpart, only emissions resulting from combustion of fuels in the steam generating unit are SUbject to this subpart. (The stationary combustion turbine emissions are subject to subpart GG or KKKK, as applicable, of this part.)

(f) Any affected facility that meets the applicability requirements of and is subject to subpart AAAA or subpart CCCC of this part is not subject to this subpart.

(g) Any facility that meets the applicability requirements and is SUbject to an EPA approved State or Federal section 111(d)/129 plan implementing SUbpart BBBB of this part is not subject to this subpart.

A-l (h) Affected facilities that also meet the applicability requirements under subpart J or subpart Ja of this part are subject to the PM and NOx standards under this subpart and the S02 standards under subpart J or subpart Ja of this part, as applicable.

(i) Temporary boilers are not subject to this subpart.

[72 FR 32759, June 13, 2007, as amended at 74 FR 5090, Jan. 28, 2009 and 77 FR 9461, Feb. 16,2012]

§ 60.41c Definitions.

As used in this subpart, all terms not defined herein shall have the meaning given them in the Clean Air Act and in subpart A of this part.

Annual capacity factor means the ratio between the actual heat input to a steam generating unit from an individual fuel or combination of fuels during a period of 12 consecutive calendar months and the potential heat input to the steam generating unit from all fuels had the steam generating unit been operated for 8,760 hours during that 12-month period at the maximum design heat input capacity. In the case of steam generating units that are rented or leased, the actual heat input shall be determined based on the combined heat input from all operations of the affected facility during a period of 12 consecutive calendar months.

Coal means all solid fuels classified as anthracite, bituminous, subbituminous, or lignite by the American Society of Testing and Materials in ASTM D388 (incorporated by reference, see §60.17), coal refuse, and petroleum coke. Coal-derived synthetic fuels derived from coal for the purposes of creating useful heat, including but not limited to solvent refined coal, gasified coal not meeting the definition of natural gas, coal-oil mixtures, and coal-water mixtures, are also included in this definition for the purposes of this subpart.

Coal refuse means any by-product of coal mining or coal cleaning operations with an ash content greater than 50 percent (by weight) and a heating value less than 13,900 kilojoules per kilogram (kJ/kg) (6,000 Btu per pound (Btu/lb) on a dry basis.

Cogeneration steam generating unit means a steam generating unit that simultaneously produces both electrical (or mechanical) and thermal energy from the same primary energy source.

Combined cycle system means a system in which a separate source (such as a stationary gas turbine, internal combustion engine, or kiln) provides exhaust gas to a steam generating unit.

Combustion research means the experimental firing of any fuel or combination of fuels in a steam generating unit for the purpose of conducting research and development of more efficient combustion or more effective prevention or control of air pollutant emissions from combustion, provided that, during these periods of research and development, the heat generated is not used for any purpose other than preheating combustion air for use by that steam generating unit ( i.e. , the heat generated is released to the atmosphere without being

A-2 used for space heating, process heating, driving pumps, preheating combustion air for other units, generating electricity, or any other purpose).

Conventional technology means wet flue gas desulfurization technology, dry flue gas desulfurization technology, atmospheric fluidized bed combustion technology, and oil hydrodesulfurization technology.

Distillate oil means fuel oil that complies with the specifications for fuel oil numbers 1 or 2, as defined by the American Society for Testing and Materials in ASTM 0396 (incorporated by reference, see §60.17), diesel fuel oil numbers 1 or 2, as defined by the American Society for Testing and Materials in ASTM 0975 (incorporated by reference, see §60.17), kerosine, as defined by the American Society of Testing and Materials in ASTM 03699 (incorporated by reference, see §60.17), biodiesel as defined by the American Society of Testing and Materials in ASTM 06751 (incorporated by reference, see §60.17), or biodiesel blends as defined by the American Society of Testing and Materials in ASTM 07467 (incorporated by reference, see §60.17).

Dry flue gas desulfurization technology means a S02controi system that is located between the steam generating unit and the exhaust vent or stack, and that removes sulfur oxides from the combustion gases of the steam generating unit by contacting the combustion gases with an alkaline reagent and water, whether introduced separately or as a premixed slurry or solution and forming a dry powder material. This definition includes devices where the dry powder material is subsequently converted to another form. Alkaline reagents used in dry flue gas desulfurization systems include, but are not limited to, lime and sodium compounds.

Duct burner means a device that combusts fuel and that is placed in the exhaust duct from another source (such as a stationary gas turbine, internal combustion engine, kiln, etc.) to allow the firing of additional fuel to heat the exhaust gases before the exhaust gases enter a steam generating unit.

Emerging technology means any S02controi system that is not defined as a conventional technology under this section, and for which the owner or operator of the affected facility has received approval from the Administrator to operate as an emerging technology under §60.48c(a)(4).

Federally enforceable means all limitations and conditions that are enforceable by the Administrator, including the requirements of 40 CFR parts 60 and 61, requirements within any applicable State implementation plan, and any permit requirements established under 40 CFR 52.21 or under 40 CFR 51.18 and 51.24.

Fluidized bed combustion technology means a device wherein fuel is distributed onto a bed (or series of beds) of limestone aggregate (or other sorbent materials) for combustion; and these materials are forced upward in the device by the flow of combustion air and the gaseous products of combustion. Fluidized bed combustion technology includes, but is not limited to, bubbling bed units and circulating bed units.

A-3 Fuel pretreatment means a process that removes a portion of the sulfur in a fuel before combustion of the fuel in a steam generating unit.

Heat input means heat derived from combustion of fuel in a steam generating unit and does not include the heat derived from preheated combustion air, recirculated flue gases, or exhaust gases from other sources (such as stationary gas turbines, internal combustion engines, and kilns).

Heat transfer medium means any material that is used to transfer heat from one point to another point.

Maximum design heat input capacity means the ability of a steam generating unit to combust a stated maximum amount of fuel (or combination of fuels) on a steady state basis as determined by the physical design and characteristics of the steam generating unit.

Natural gas means:

(1) A naturally occurring mixture of hydrocarbon and nonhydrocarbon gases found in geologic formations beneath the earth's surface, of which the principal constituent is methane; or

(2) Liquefied petroleum (LP) gas, as defined by the American Society for Testing and Materials in ASTM 01835 (incorporated by reference, see §60.17); or

(3) A mixture of hydrocarbons that maintains a gaseous state at ISO conditions. Additionally, natural gas must either be composed of at least 70 percent methane by volume or have a gross calorific value between 34 and 43 megajoules (MJ) per dry standard cubic meter (910 and 1,150 Btu per dry standard cubic foot).

Noncontinental area means the State of Hawaii, the Virgin Islands, Guam, American Samoa, the Commonwealth of Puerto Rico, or the Northern Mariana Islands.

Oil means crude oil or petroleum, or a liquid fuel derived from crude oil or petroleum, including distillate oil and residual oil.

Potential sulfur dioxide emission rate means the theoretical S02emissions (nanograms per joule (ng/J) or Ib/MMBtu heat input) that would result from combusting fuel in an uncleaned state and without using emission control systems.

Process heater means a device that is primarily used to heat a material to initiate or promote a chemical reaction in which the material participates as a reactant or catalyst.

Residual oil means crude oil, fuel oil that does not comply with the specifications under the definition of distillate oil, and all fuel oil numbers 4, 5, and 6, as defined by the American Society for Testing and Materials in ASTM 0396 (incorporated by reference, see §60.17).

A-4 Steam generating unit means a device that combusts any fuel and produces steam or heats water or heats any heat transfer medium. This term includes any duct burner that combusts fuel and is part of a combined cycle system. This term does not include process heaters as defined in this subpart.

Steam generating unit operating day means a 24-hour period between 12:00 midnight and the following midnight during which any fuel is combusted at any time in the steam generating unit. It is not necessary for fuel to be combusted continuously for the entire 24-hour period.

Temporary boiler means a steam generating unit that combusts natural gas or distillate oil with a potential S02 emissions rate no greater than 26 ng/J (0.060 Ib/MMBtu), and the unit is designed to, and is capable of, being carried or moved from one location to another by means of, for example, wheels, skids, carrying handles, dollies, trailers, or platforms. A steam generating unit is not a temporary boiler if anyone of the following conditions exists:

(1) The equipment is attached to a foundation.

(2) The steam generating unit or a replacement remains at a location for more than 180 consecutive days. Any temporary boiler that replaces a temporary boiler at a location and performs the same or similar function will be included in calculating the consecutive time period.

(3) The equipment is located at a seasonal facility and operates during the full annual operating period of the seasonal facility, remains at the facility for at least 2 years, and operates at that facility for at least 3 months each year.

(4) The equipment is moved from one location to another in an attempt to circumvent the residence time requirements of this definition.

Wet flue gas desulfurization technology means an S02controi system that is located between the steam generating unit and the exhaust vent or stack, and that removes sulfur oxides from the combustion gases of the steam generating unit by contacting the combustion gases with an alkaline slurry or solution and forming a liquid material. This definition includes devices where the liquid material is subsequently converted to another form. Alkaline reagents used in wet flue gas desulfurization systems include, but are not limited to, lime, limestone, and sodium compounds.

Wet scrubber system means any emission control device that mixes an aqueous stream or slurry with the exhaust gases from a steam generating unit to control emissions of PM or S02.

Wood means wood, wood residue, bark, or any derivative fuel or residue thereof, in any form, including but not limited to sawdust, sanderdust, wood chips, scraps, slabs, millings, shavings, and processed pellets made from wood or other forest residues.

[72 FR 32759, June 13, 2007, as amended at 74 FR 5090, Jan. 28, 2009 and 77 FR 9461, Feb. 16,2012]

A-S § 60.42c Standard for sulfur dioxide (502),

(a) Except as provided in paragraphs (b), (c), and (e) of this section, on and after the date on which the performance test is completed or required to be completed under §60.8, whichever date comes first, the owner or operator of an affected facility that combusts only coal shall neither: cause to be discharged into the atmosphere from the affected facility any gases that contain 802 in excess of 87 ng/J (0.20 Ib/MMBtu) heat input or 10 percent (0.10) of the potential 802 emission rate (90 percent reduction), nor cause to be discharged into the atmosphere from the affected facility any gases that contain 802 in excess of 520 ng/J (1.2 Ib/MMBtu) heat input. If coal is combusted with other fuels, the affected facility shall neither: cause to be discharged into the atmosphere from the affected facility any gases that contain 802in excess of 87 ng/J (0.20 Ib/MMBtu) heat input or 10 percent (0.10) of the potential 802 emission rate (90 percent reduction), nor cause to be discharged into the atmosphere from the affected facility any gases that contain 802 in excess of the emission limit is determined pursuant to paragraph (e)(2) of this section.

(b) Except as provided in paragraphs (c) and (e) of this section, on and after the date on which the performance test is completed or required to be completed under §60.8, whichever date comes first, the owner or operator of an affected facility that:

(1) Combusts only coal refuse alone in a fluidized bed combustion steam generating unit shall neither:

(i) Cause to be discharged into the atmosphere from that affected facility any gases that contain 802 in excess of 87 ng/J (0.20 Ib/MMBtu) heat input or 20 percent (0.20) of the potential 802 emission rate (80 percent reduction); nor

(ii) Cause to be discharged into the atmosphere from that affected facility any gases that contain 802in excess of 802in excess of 520 ng/J (1.2 Ib/MMBtu) heat input. If coal is fired with coal refuse, the affected facility subject to paragraph (a) of this section. If oil or any other fuel (except coal) is fired with coal refuse, the affected facility is subject to the 87 ng/J (0.20 Ib/MMBtu) heat input 802emissions limit or the 90 percent 802reduction requirement specified in paragraph (a) of this section and the emission limit is determined pursuant to paragraph (e)(2) of this section.

(2) Combusts only coal and that uses an emerging technology for the control of 802 emissions shall neither:

(i) Cause to be discharged into the atmosphere from that affected facility any gases that contain 802in excess of 50 percent (0.50) of the potential 802emission rate (50 percent reduction); nor

(ii) Cause to be discharged into the atmosphere from that affected facility any gases that contain 802 in excess of 260 ng/J (0.60 Ib/MMBtu) heat input. If coal is combusted with other fuels, the affected facility is subject to the 50 percent 802reduction requirement specified in this paragraph and the emission limit determined pursuant to paragraph (e)(2) of this section.

A-6 (c) On and after the date on which the initial performance test is completed or required to be completed under §60.8, whichever date comes first, no owner or operator of an affected facility that combusts coal, alone or in combination with any other fuel, and is listed in paragraphs (c)(1), (2), (3), or (4) of this section shall cause to be discharged into the atmosphere from that affected facility any gases that contain 802 in excess of the emission limit determined pursuant to paragraph (e)(2) of this section. Percent reduction requirements are not applicable to affected facilities under paragraphs (c)(1), (2), (3), or (4).

(1) Affected facilities that have a heat input capacity of 22 MW (75 MMBtu/hr) or less;

(2) Affected facilities that have an annual capacity for coal of 55 percent (0.55) or less and are subject to a federally enforceable requirement limiting operation of the affected facility to an annual capacity factor for coal of 55 percent (0.55) or less;

(3) Affected facilities located in a noncontinental area; or

(4) Affected facilities that combust coal in a duct burner as part of a combined cycle system where 30 percent (0.30) or less of the heat entering the steam generating unit is from combustion of coal in the duct burner and 70 percent (0.70) or more of the heat entering the steam generating unit is from exhaust gases entering the duct burner.

(d) On and after the date on which the initial performance test is completed or required to be completed under §60.8, whichever date comes first, no owner or operator of an affected facility that combusts oil shall cause to be discharged into the atmosphere from that affected facility any gases that contain 802 in excess of 215 ng/J (0.50 Ib/MMBtu) heat input from oil; or, as an alternative, no owner or operator of an affected facility that combusts oil shall combust oil in the affected facility that contains greater than 0.5 weight percent sulfur. The percent reduction requirements are not applicable to affected facilities under this paragraph.

(e) On and after the date on which the initial performance test is completed or required to be completed under §60.8, whichever date comes first, no owner or operator of an affected facility that combusts coal, oil, or coal and oil with any other fuel shall cause to be discharged into the atmosphere from that affected facility any gases that contain 802 in excess of the following:

(1) The percent of potential 802 emission rate or numerical 802 emission rate required under paragraph (a) or (b)(2) of this section, as applicable, for any affected facility that

(i) Combusts coal in combination with any other fuel;

(ii) Has a heat input capacity greater than 22 MW (75 MMBtu/h); and

(iii) Has an annual capacity factor for coal greater than 55 percent (0.55); and

(2) The emission limit determined according to the following formula for any affected facility that combusts coal, oil, or coal and oil with any other fuel:

A-7 Where:

Es= 802 emission limit, expressed in ng/J or Ib/MMBtu heat input;

Ka= 520 ng/J (1.2 Ib/MMBtu);

Kb= 260 ng/J (0.60 Ib/MMBtu);

Ke= 215 ng/J (0.50 Ib/MMBtu);

Ha= Heat input from the combustion of coal, except coal combusted in an affected facility subject to paragraph (b)(2) of this section, in Joules (J) [MMBtu];

Hb= Heat input from the combustion of coal in an affected facility subject to paragraph (b)(2) of this section, in J (MMBtu); and

He= Heat input from the combustion of oil, in J (MMBtu).

(f) Reduction in the potential 802 emission rate through fuel pretreatment is not credited toward the percent reduction requirement under paragraph (b)(2) of this section unless:

(1) Fuel pretreatment results in a 50 percent (0.50) or greater reduction in the potential 802 emission rate; and

(2) Emissions from the pretreated fuel (without either combustion or post-combustion 802 control) are equal to or less than the emission limits specified under paragraph (b)(2) of this section.

(g) Except as provided in paragraph (h) of this section, compliance with the percent reduction requirements, fuel oil sulfur limits, and emission limits of this section shall be determined on a 30-day rolling average basis.

(h) For affected facilities listed under paragraphs (h)(1), (2), (3), or (4) of this section, compliance with the emission limits or fuel oil sulfur limits under this section may be determined based on a certification from the fuel supplier, as described under §60.48c(f), as applicable.

(1) Distillate oil-fired affected facilities with heat input capacities between 2.9 and 29 MW (10 and 100 MMBtu/hr).

(2) Residual oil-fired affected facilities with heat input capacities between 2.9 and 8.7 MW (10 and 30 MMBtu/hr).

A-8 (3) Coal-fired affected facilities with heat input capacities between 2.9 and 8.7 MW (10 and 30 MMBtu/h).

(4) Other fuels-fired affected facilities with heat input capacities between 2.9 and 8.7 MW (10 and 30 MMBtu/h).

(i) The 502 emission limits, fuel oil sulfur limits, and percent reduction requirements under this section apply at all times, including periods of startup, shutdown, and malfunction.

U) For affected facilities located in noncontinental areas and affected facilities complying with the percent reduction standard, only the heat input supplied to the affected facility from the combustion of coal and oil is counted under this section. No credit is provided for the heat input to the affected facility from wood or other fuels or for heat derived from exhaust gases from other sources, such as stationary gas turbines, internal combustion engines, and kilns.

[72 FR 32759, June 13, 2007, as amended at 74 FR 5090, Jan. 28, 2009 and 77 FR 9461, Feb. 16,2012]

§ 60.43c Standard for particulate matter (PM).

(a) On and after the date on which the initial performance test is completed or required to be completed under §60.8, whichever date comes first, no owner or operator of an affected facility that commenced construction, reconstruction, or modification on or before February 28,2005, that combusts coal or combusts mixtures of coal with other fuels and has a heat input capacity of 8.7 MW (30 MMBtu/h) or greater, shall cause to be discharged into the atmosphere from that affected facility any gases that contain PM in excess of the following emission limits:

(1) 22 ng/J (0.051 Ib/MMBtu) heat input if the affected facility combusts only coal, or combusts coal with other fuels and has an annual capacity factor for the other fuels of 10 percent (0.10) or less.

(2) 43 ng/J (0.10 Ib/MMBtu) heat input if the affected facility combusts coal with other fuels, has an annual capacity factor for the other fuels greater than 10 percent (0.10), and is subject to a federally enforceable requirement limiting operation of the affected facility to an annual capacity factor greater than 10 percent (0.10) for fuels other than coal.

(b) On and after the date on which the initial performance test is completed or required to be completed under §60.8, whichever date comes first, no owner or operator of an affected facility that commenced construction, reconstruction, or modification on or before February 28, 2005, that combusts wood or combusts mixtures of wood with other fuels (except coal) and has a heat input capacity of 8.7 MW (30 MMBtu/h) or greater, shall cause to be discharged into the atmosphere from that affected facility any gases that contain PM in excess of the following emissions limits:

(1) 43 ng/J (0.10 Ib/MMBtu) heat input if the affected facility has an annual capacity factor for wood greater than 30 percent (0.30); or

A-9 (2) 130 ng/J (0.30 Ib/MMBtu) heat input if the affected facility has an annual capacity factor for wood of 30 percent (0.30) or less and is subject to a federally enforceable requirement limiting operation of the affected facility to an annual capacity factor for wood of 30 percent (0.30) or less.

(c) On and after the date on which the initial performance test is completed or required to be completed under §60.8, whichever date comes first, no owner or operator of an affected facility that combusts coal, wood, or oil and has a heat input capacity of 8.7 MW (30 MMBtu/h) or greater shall cause to be discharged into the atmosphere from that affected facility any gases that exhibit greater than 20 percent opacity (6-minute average), except for one 6-minute period per hour of not more than 27 percent opacity. Owners and operators of an affected facility that elect to install, calibrate, maintain, and operate a continuous emissions monitoring system (CEMS) for measuring PM emissions according to the requirements of this subpart and are subject to a federally enforceable PM limit of 0.030 Ib/MMBtu or less are exempt from the opacity standard specified in this paragraph (c).

(d) The PM and opacity standards under this section apply at all times, except during periods of startup, shutdown, or malfunction.

(e)(1) On and after the date on which the initial performance test is completed or is required to be completed under §60.8, whichever date comes first, no owner or operator of an affected facility that commences construction, reconstruction, or modification after February 28,2005, and that combusts coal, oil, wood, a mixture of these fuels, or a mixture of these fuels with any other fuels and has a heat input capacity of 8.7 MW (30 MMBtu/h) or greater shall cause to be discharged into the atmosphere from that affected facility any gases that contain PM in excess of 13 ng/J (0.030 Ib/MMBtu) heat input, except as provided in paragraphs (e)(2), (e)(3), and (e)(4) of this section.

(2) As an alternative to meeting the requirements of paragraph (e)(1) of this section, the owner or operator of an affected facility for which modification commenced after February 28, 2005, may elect to meet the requirements of this paragraph. On and after the date on which the initial performance test is completed or required to be completed under §60.8, whichever date comes first, no owner or operator of an affected facility that commences modification after February 28, 2005 shall cause to be discharged into the atmosphere from that affected facility any gases that contain PM in excess of both:

(i) 22 ng/J (0.051 Ib/MMBtu) heat input derived from the combustion of coal, oil, wood, a mixture of these fuels, or a mixture of these fuels with any other fuels; and

(ii) 0.2 percent of the combustion concentration (99.8 percent reduction) when combusting coal, oil, wood, a mixture of these fuels, or a mixture of these fuels with any other fuels.

(3) On and after the date on which the initial performance test is completed or is required to be completed under §60.8, whichever date comes first, no owner or operator of an affected facility that commences modification after February 28, 2005, and that combusts over 30 percent wood (by heat input) on an annual basis and has a heat input capacity of 8.7 MW (30

A-l0 MM8tu/h) or greater shall cause to be discharged into the atmosphere from that affected facility any gases that contain PM in excess of 43 ng/J (0.10 Ib/MM8tu) heat input.

(4) An owner or operator of an affected facility that commences construction, reconstruction, or modification after February 28, 2005, and that combusts only oil that contains no more than 0.50 weight percent sulfur or a mixture of 0.50 weight percent sulfur oil with other fuels not subject to a PM standard under §60.43c and not using a post-combustion technology (except a wet scrubber) to reduce PM or S02emissions is not subject to the PM limit in this section.

[72 FR 32759, June 13, 2007, as amended at 74 FR 5091, Jan. 28, 2009 and 77 FR 9461, Feb. 16, 2012]

§ 60.44c Compliance and performance test methods and procedures for sulfur dioxide.

(a) Except as provided in paragraphs (g) and (h) of this section and §60.8(b), performance tests required under §60.8 shall be conducted following the procedures specified in paragraphs (b), (c), (d), (e), and (f) of this section, as applicable. Section 60.8(f) does not apply to this section. The 30-day notice required in §60.8(d) applies only to the initial performance test unless otherwise specified by the Administrator.

(b) The initial performance test required under §60.8 shall be conducted over 30 consecutive operating days of the steam generating unit. Compliance with the percent reduction requirements and S02emission limits under §60.42c shall be determined using a 30-day average. The first operating day included in the initial performance test shall be scheduled within 30 days after achieving the maximum production rate at which the affect facility will be operated, but not later than 180 days after the initial startup of the facility. The steam generating unit load during the 30-day period does not have to be the maximum design heat input capacity, but must be representative of future operating conditions.

(c) After the initial performance test required under paragraph (b) of this section and §60.8, compliance with the percent reduction requirements and S02emission limits under §60.42c is based on the average percent reduction and the average S02emission rates for 30 consecutive steam generating unit operating days. A separate performance test is completed at the end of each steam generating unit operating day, and a new 30-day average percent reduction and S02 emission rate are calculated to show compliance with the standard.

(d) If only coal, only oil, or a mixture of coal and oil is combusted in an affected facility, the procedures in Method 19 of appendix A of this part are used to determine the hourly S02emission rate (Eho) and the 30-day average S02emission rate (Eao). The hourly averages used to compute the 30-day averages are obtained from the CEMS. Method 19 of appendix A of this part shall be used to calculate Eaowhen using daily fuel sampling or Method 68 of appendix A of this part.

(e) If coal, oil, or coal and oil are combusted with other fuels:

A-ll (1) An adjusted Eho(Ehoo) is used in Equation 19-19 of Method 19 of appendix A of this part to compute the adjusted Eao(Eaoo). The Ehoo is computed using the following formula:

Where:

Ehoo =Adjusted Eho, ng/J (lb/MMBtu);

Eho=Hourly S02emission rate, ng/J (lb/MMBtu);

Ew=S02concentration in fuels other than coal and oil combusted in the affected facility, as determined by fuel sampling and analysis procedures in Method 9 of appendix A of this part, ng/J (lb/MMBtu). The value Ewfor each fuel lot is used for each hourly average during the time that the lot is being combusted. The owner or operator does not have to measure Ewifthe owner or operator elects to assume Ew= O.

Xk=Fraction of the total heat input from fuel combustion derived from coal and oil, as determined by applicable procedures in Method 19 of appendix A of this part.

(2) The owner or operator of an affected facility that qualifies under the provisions of §60.42c(c) or (d) (where percent reduction is not required) does not have to measure the parameters Ewor Xkif the owner or operator of the affected facility elects to measure emission rates of the coal or oil using the fuel sampling and analysis procedures under Method 19 of appendix A of this part.

(f) Affected facilities subject to the percent reduction requirements under §60.42c(a) or (b) shall determine compliance with the S02emission limits under §60.42c pursuant to paragraphs (d) or (e) of this section, and shall determine compliance with the percent reduction requirements using the following procedures:

(1) If only coal is combusted, the percent of potential S02emission rate is computed using the following formula:

%P =100(1 - %R r %R!) , 100)(l_ 100

Where:

%Ps=Potential S02emission rate, in percent;

%Rg=S02removai efficiency of the control device as determined by Method 19 of appendix A of this part, in percent; and

A-12 %Rf= S02 removai efficiency of fuel pretreatment as determined by Method 19 of appendix A of this part, in percent.

(2) If coal, oil, or coal and oil are combusted with other fuels, the same procedures required in paragraph (f)(1) of this section are used, except as provided for in the following:

(i) To compute the %Ps, an adjusted %Rg(%Rgo) is computed from Eaoo from paragraph (e)(1) of this section and an adjusted average S02iniet rate (Eaio) using the following formula:

%R 0 =100 (1- E: 1 f E:

Where:

%Rgo = Adjusted %Rg, in percent;

Eaoo = Adjusted Eao, ng/J (lb/MMBtu); and

Eaio = Adjusted average S02iniet rate, ng/J (lb/MMBtu).

(ii) To compute Eaio, an adjusted hourly S02iniet rate (EhiO) is used. The EhiO is computed using the following formula:

Where:

EhiO = Adjusted Ehi, ng/J (lb/MMBtu);

Ehi= Hourly S02iniet rate, ng/J (lb/MMBtu);

Ew= S02concentration in fuels other than coal and oil combusted in the affected facility, as determined by fuel sampling and analysis procedures in Method 19 of appendix A of this part, ng/J (lb/MMBtu). The value Ewfor each fuel lot is used for each hourly average during the time that the lot is being combusted. The owner or operator does not have to measure Ewif the owner or operator elects to assume Ew= 0; and

Xk= Fraction of the total heat input from fuel combustion derived from coal and oil, as determined by applicable procedures in Method 19 of appendix A of this part.

(g) For oil-fired affected facilities where the owner or operator seeks to demonstrate compliance with the fuel oil sulfur limits under §60.42c based on shipment fuel sampling, the initial performance test shall consist of sampling and analyzing the oil in the initial tank of oil to be fired in the steam generating unit to demonstrate that the oil contains 0.5 weight percent

A-13 sulfur or less. Thereafter, the owner or operator of the affected facility shall sample the oil in the fuel tank after each new shipment of oil is received, as described under §60.46c(d)(2).

(h) For affected facilities subject to §60.42c(h)(1), (2), or (3) where the owner or operator seeks to demonstrate compliance with the S02standards based on fuel supplier certification, the performance test shall consist of the certification from the fuel supplier, as described in §60.48c(f), as applicable.

(i) The owner or operator of an affected facility seeking to demonstrate compliance with the S02standards under §60.42c(c)(2) shall demonstrate the maximum design heat input capacity of the steam generating unit by operating the steam generating unit at this capacity for 24 hours. This demonstration shall be made during the initial performance test, and a subsequent demonstration may be requested at any other time. If the demonstrated 24-hour average firing rate for the affected facility is less than the maximum design heat input capacity stated by the manufacturer of the affected facility, the demonstrated 24-hour average firing rate shall be used to determine the annual capacity factor for the affected facility; otherwise, the maximum design heat input capacity provided by the manufacturer shall be used.

U) The owner or operator of an affected facility shall use all valid S02emissions data in calculating %Psand Ehounder paragraphs (d), (e), or (f) of this section, as applicable, whether or not the minimum emissions data requirements under §60.46c(f) are achieved. All valid emissions data, including valid data collected during periods of startup, shutdown, and malfunction, shall be used in calculating %Psor Ehopursuant to paragraphs (d), (e), or (f) of this section, as applicable.

[72 FR 32759, June 13,2007, as amended at 74 FR 5091, Jan. 28, 2009]

§ 60.45c Compliance and performance test methods and procedures for particulate matter.

(a) The owner or operator of an affected facility subject to the PM and/or opacity standards under §60.43c shall conduct an initial performance test as required under §60.8, and shall conduct subsequent performance tests as requested by the Administrator, to determine compliance with the standards using the following procedures and reference methods, except as specified in paragraph (c) of this section.

(1) Method 1 of appendix A of this part shall be used to select the sampling site and the number of traverse sampling points.

(2) Method 3A or 38 of appendix A-2 of this part shall be used for gas analysis when applying Method 5 or 58 of appendix A-3 of this part or 17 of appendix A-6 of this part.

(3) Method 5, 58, or 17 of appendix A of this part shall be used to measure the concentration of PM as follows:

A-14 (i) Method 5 of appendix A of this part may be used only at affected facilities without wet scrubber systems.

(ii) Method 17 of appendix A of this part may be used at affected facilities with or without wet scrubber systems provided the stack gas temperature does not exceed a temperature of 160 °C (320 OF). The procedures of Sections 8.1 and 11.1 of Method 58 of appendix A of this part may be used in Method 17 of appendix A of this part only if Method 17 of appendix A of this part is used in conjunction with a wet scrubber system. Method 17 of appendix A of this part shall not be used in conjunction with a wet scrubber system if the effluent is saturated or laden with water droplets.

(iii) Method 58 of appendix A of this part may be used in conjunction with a wet scrubber system.

(4) The sampling time for each run shall be at least 120 minutes and the minimum sampling volume shall be 1.7 dry standard cubic meters (dscm) [60 dry standard cubic feet (dscf)] except that smaller sampling times or volumes may be approved by the Administrator when necessitated by process variables or other factors.

(5) For Method 5 or 58 of appendix A of this part, the temperature of the sample gas in the probe and filter holder shall be monitored and maintained at 160 ±14 °C (320±25 OF).

(6) For determination of PM emissions, an oxygen (02) or carbon dioxide (C02) measurement shall be obtained simultaneously with each run of Method 5, 58, or 17 of appendix A of this part by traversing the duct at the same sampling location.

(7) For each run using Method 5, 58, or 17 of appendix A of this part, the emission rates expressed in ng/J (lb/MM8tu) heat input shall be determined using:

(i) The O2 or CO2 measurements and PM measurements obtained under this section,

(ii) The dry basis F factor, and

(iii) The dry basis emission rate calculation procedure contained in Method 19 of appendix A of this part.

(8) Method 9 of appendix A-4 of this part shall be used for determining the opacity of stack emissions.

(b) The owner or operator of an affected facility seeking to demonstrate compliance with the PM standards under §60.43c(b)(2) shall demonstrate the maximum design heat input capacity of the steam generating unit by operating the steam generating unit at this capacity for 24 hours. This demonstration shall be made during the initial performance test, and a subsequent demonstration may be requested at any other time. If the demonstrated 24-hour average firing rate for the affected facility is less than the maximum design heat input capacity stated by the manufacturer of the affected facility, the demonstrated 24-hour average firing rate shall be

A-iS used to determine the annual capacity factor for the affected facility; otherwise, the maximum design heat input capacity provided by the manufacturer shall be used.

(c) In place of PM testing with Method 5 or 58 of appendix A-3 of this part or Method 17 of appendix A-6 of this part, an owner or operator may elect to install, calibrate, maintain, and operate a CEMS for monitoring PM emissions discharged to the atmosphere and record the output of the system. The owner or operator of an affected facility who elects to continuously monitor PM emissions instead of conducting performance testing using Method 5 or 58 of appendix A-3 of this part or Method 17 of appendix A-6 of this part shall install, calibrate, maintain, and operate a CEMS and shall comply with the requirements specified in paragraphs (c)(1) through (c)(14) of this section.

(1) Notify the Administrator 1 month before starting use of the system.

(2) Notify the Administrator 1 month before stopping use of the system.

(3) The monitor shall be installed, evaluated, and operated in accordance with §60.13 of subpart A of this part.

(4) The initial performance evaluation shall be completed no later than 180 days after the date of initial startup of the affected facility, as specified under §60.8 of subpart A of this part or within 180 days of notification to the Administrator of use of CEMS if the owner or operator was previously determining compliance by Method 5, 58, or 17 of appendix A of this part performance tests, whichever is later.

(5) The owner or operator of an affected facility shall conduct an initial performance test for PM emissions as required under §60.8 of subpart A of this part. Compliance with the PM emission limit shall be determined by using the CEMS specified in paragraph (d) of this section to measure PM and calculating a 24-hour block arithmetic average emission concentration using EPA Reference Method 19 of appendix A of this part, section 4.1.

(6) Compliance with the PM emission limit shall be determined based on the 24-hour daily (block) average of the hourly arithmetic average emission concentrations using CEMS outlet data.

(7) At a minimum, valid CEMS hourly averages shall be obtained as specified in paragraph (c)(7)(i) of this section for 75 percent of the total operating hours per 30-day rolling average.

(i) At least two data points per hour shall be used to calculate each 1-hour arithmetic average.

(ii) [Reserved]

(8) The 1-hour arithmetic averages required under paragraph (c)(7) of this section shall be expressed in ng/J or Ib/MM8tu heat input and shall be used to calculate the boiler operating day daily arithmetic average emission concentrations. The 1-hour arithmetic averages shall be calculated using the data points required under §60.13(e)(2) of subpart A of this part.

A-16 (9) All valid CEMS data shall be used in calculating average emission concentrations even if the minimum CEMS data requirements of paragraph (c)(7) of this section are not met.

(10) The CEMS shall be operated according to Performance Specification 11 in appendix 8 of this part.

(11) During the correlation testing runs of the CEMS required by Performance Specification 11 in appendix 8 of this part, PM and 02(or CO2) data shall be collected concurrently (or within a 30- to 60-minute period) by both the continuous emission monitors and performance tests conducted using the following test methods.

(i) For PM, Method 5 or 58 of appendix A-3 of this part or Method 17 of appendix A-6 of this part shall be used; and

(ii) For 02 (or CO2), Method 3A or 38 of appendix A-2 of this part, as applicable shall be used.

(12) Quarterly accuracy determinations and daily calibration drift tests shall be performed in accordance with procedure 2 in appendix F of this part. Relative Response Audit's must be performed annually and Response Correlation Audits must be performed every 3 years.

(13) When PM emissions data are not obtained because of CEMS breakdowns, repairs, calibration checks, and zero and span adjustments, emissions data shall be obtained by using other monitoring systems as approved by the Administrator or EPA Reference Method 19 of appendix A of this part to provide, as necessary, valid emissions data for a minimum of 75 percent of total operating hours on a 30-day rolling average.

(14) As of January 1, 2012, and within 90 days after the date of completing each performance test, as defined in §60.8, conducted to demonstrate compliance with this subpart, you must submit relative accuracy test audit ( i.e., reference method) data and performance test ( i.e., compliance test) data, except opacity data, electronically to EPA's Central Data Exchange (COX) by using the Electronic Reporting Tool (ERT) (see http://www.epa.gov/ttn/chief/ert/ert tool.html/) or other compatible electronic spreadsheet. Only data collected using test methods compatible with ERT are subject to this requirement to be submitted electronically into EPA's WebFIRE database.

(d) The owner or operator of an affected facility seeking to demonstrate compliance under §60.43c(e)(4) shall follow the applicable procedures under §60.48c(f). For residual oil-fired affected facilities, fuel supplier certifications are only allowed for facilities with heat input capacities between 2.9 and 8.7 MW (10 to 30 MM8tu/h).

[72 FR 32759, June 13, 2007, as amended at 74 FR 5091, Jan. 28, 2009 and 77 FR 9461, Feb. 16, 2012]

A-17 § 60.46c Emission monitoring for sulfur dioxide.

(a) Except as provided in paragraphs (d) and (e) of this section, the owner or operator of an affected facility subject to the S02 emission limits under §60.42c shall install, calibrate, maintain, and operate a CEMS for measuring S02 concentrations and either O2or CO2 concentrations at the outlet of the S02 control device (or the outlet of the steam generating unit if no S02controi device is used), and shall record the output of the system. The owner or operator of an affected facility subject to the percent reduction requirements under §60.42c shall measure S02concentrations and either O2or CO2concentrations at both the inlet and outlet of the S02controi device.

(b) The 1-hour average S02emission rates measured by a CEMS shall be expressed in ng/J or Ib/MM8tu heat input and shall be used to calculate the average emission rates under §60.42c. Each 1-hour average S02 emission rate must be based on at least 30 minutes of operation, and shall be calculated using the data points required under §60.13(h)(2). Hourly S02 emission rates are not calculated if the affected facility is operated less than 30 minutes in a 1-hour period and are not counted toward determination of a steam generating unit operating day.

(1) All CEMS shall be operated in accordance with the applicable procedures under Performance Specifications 1, 2, and 3 of appendix 8 of this part.

(2) Quarterly accuracy determinations and daily calibration drift tests shall be performed in accordance with Procedure 1 of appendix F of this part.

(3) For affected facilities subject to the percent reduction requirements under §60.42c, the span value of the S02CEMS at the inlet to the S02controi device shall be 125 percent of the maximum estimated hourly potential S02emission rate of the fuel combusted, and the span value of the S02CEMS at the outlet from the S02controi device shall be 50 percent of the maximum estimated hourly potential S02emission rate of the fuel combusted.

(4) For affected facilities that are not subject to the percent reduction requirements of §60.42c, the span value of the S02CEMS at the outlet from the S02controi device (or outlet of the steam generating unit if no S02controi device is used) shall be 125 percent of the maximum estimated hourly potential S02emission rate of the fuel combusted.

(d) As an alternative to operating a CEMS at the inlet to the S02controi device (or outlet of the steam generating unit if no S02controi device is used) as required under paragraph (a) of this section, an owner or operator may elect to determine the average S02emission rate by sampling the fuel prior to combustion. As an alternative to operating a CEMS at the outlet from the S02controi device (or outlet of the steam generating unit if no S02controi device is used) as required under paragraph (a) of this section, an owner or operator may elect to determine the average S02emission rate by using Method 68 of appendix A of this part. Fuel sampling

A-18 shall be conducted pursuant to either paragraph (d)(1) or (d)(2) of this section. Method 6B of appendix A of this part shall be conducted pursuant to paragraph (d)(3) of this section.

(1) For affected facilities combusting coal or oil, coal or oil samples shall be collected daily in an as-fired condition at the inlet to the steam generating unit and analyzed for sulfur content and heat content according the Method 19 of appendix A of this part. Method 19 of appendix A of this part provides procedures for converting these measurements into the format to be used in calculating the average SOzinput rate.

(2) As an alternative fuel sampling procedure for affected facilities combusting oil, oil samples may be collected from the fuel tank for each steam generating unit immediately after the fuel tank is filled and before any oil is combusted. The owner or operator of the affected facility shall analyze the oil sample to determine the sulfur content of the oil. If a partially empty fuel tank is refilled, a new sample and analysis of the fuel in the tank would be required upon filling. Results of the fuel analysis taken after each new shipment of oil is received shall be used as the daily value when calculating the 30-day rolling average until the next shipment is received. If the fuel analysis shows that the sulfur content in the fuel tank is greater than 0.5 weight percent sulfur, the owner or operator shall ensure that the sulfur content of subsequent oil shipments is low enough to cause the 30-day rolling average sulfur content to be 0.5 weight percent sulfur or less.

(3) Method 6B of appendix A of this part may be used in lieu of GEMS to measure SOzat the inlet or outlet of the SOzcontrol system. An initial stratification test is required to verify the adequacy of the Method 6B of appendix A of this part sampling location. The stratification test shall consist of three paired runs of a suitable SOzand GOzmeasurement train operated at the candidate location and a second similar train operated according to the procedures in §3.2 and the applicable procedures in section 7 of Performance Specification 2 of appendix B of this part. Method 6B of appendix A of this part, Method 6A of appendix A of this part, or a combination of Methods 6 and 3 of appendix A of this part or Methods 6G and 3A ofappendix A of this part are suitable measurement techniques. If Method 6B of appendix A of this part is used for the second train, sampling time and timer operation may be adjusted for the stratification test as long as an adequate sample volume is collected; however, both sampling trains are to be operated similarly. For the location to be adequate for Method 6B of appendix A of this part 24-hour tests, the mean of the absolute difference between the three paired runs must be less than 10 percent (0.10).

(e) The monitoring requirements of paragraphs (a) and (d) of this section shall not apply to affected facilities subject to §60.42c(h) (1), (2), or (3) where the owner or operator of the affected facility seeks to demonstrate compliance with the SOzstandards based on fuel supplier certification, as described under §60.48c(f), as applicable.

(f) The owner or operator of an affected facility operating a GEMS pursuant to paragraph (a) of this section, or conducting as-fired fuel sampling pursuant to paragraph (d)(1) of this section, shall obtain emission data for at least 75 percent of the operating hours in at least 22 out of 30 successive steam generating unit operating days. If this minimum data requirement is not met with a single monitoring system, the owner or operator of the affected facility shall supplement

A-19 the emission data with data collected with other monitoring systems as approved by the Administrator.

§ 60.47c Emission monitoring for particulate matter.

(a) Except as provided in paragraphs (c), (d), (e), and (f) of this section, the owner or operator of an affected facility combusting coal, oil, or wood that is subject to the opacity standards under §60.43c shall install, calibrate, maintain, and operate a continuous opacity monitoring system (CaMS) for measuring the opacity of the emissions discharged to the atmosphere and record the output of the system. The owner or operator of an affected facility subject to an opacity standard in §60.43c(c) that is not required to use a CaMS due to paragraphs (c), (d), (e), or (f) of this section that elects not to use a CaMS shall conduct a performance test using Method 9 of appendix A-4 of this part and the procedures in §60.11 to demonstrate compliance with the applicable limit in §60.43c by April 29, 2011, within 45 days of stopping use of an existing CaMS, or within 180 days after initial startup of the facility, whichever is later, and shall comply with either paragraphs (a)(1), (a)(2), or (a)(3) of this section. The observation period for Method 9 of appendix A-4 of this part performance tests may be reduced from 3 hours to 60 minutes if all 6-minute averages are less than 10 percent and all individual 15-second observations are less than or equal to 20 percent during the initial 60 minutes of observation.

(1) Except as provided in paragraph (a)(2) and (a)(3) of this section, the owner or operator shall conduct subsequent Method 9 of appendix A-4 of this part performance tests using the procedures in paragraph (a) of this section according to the applicable schedule in paragraphs (a)(1)(i) through (a)(1)(iv) of this section, as determined by the most recent Method 9 of appendix A-4 of this part performance test results.

(i) If no visible emissions are observed, a subsequent Method 9 of appendix A-4 of this part performance test must be completed within 12 calendar months from the date that the most recent performance test was conducted or within 45 days of the next day that fuel with an opacity standard is combusted, whichever is later;

(ii) If visible emissions are observed but the maximum 6-minute average opacity is less than or equal to 5 percent, a subsequent Method 9 of appendix A-4 of this part performance test must be completed within 6 calendar months from the date that the most recent performance test was conducted or within 45 days of the next day that fuel with an opacity standard is combusted, whichever is later;

(iii) If the maximum 6-minute average opacity is greater than 5 percent but less than or equal to 10 percent, a subsequent Method 9 of appendix A-4 of this part performance test must be completed within 3 calendar months from the date that the most recent performance test was conducted or within 45 days of the next day that fuel with an opacity standard is combusted, whichever is later; or

A-20 (iv) If the maximum 6-minute average opacity is greater than 10 percent, a subsequent Method 9 of appendix A--4 of this part performance test must be completed within 45 calendar days from the date that the most recent performance test was conducted.

(2) If the maximum 6-minute opacity is less than 10 percent during the most recent Method 9 of appendix A--4 of this part performance test, the owner or operator may, as an alternative to performing subsequent Method 9 of appendix A--4 of this part performance tests, elect to perform subsequent monitoring using Method 22 of appendix A-7 of this part according to the procedures specified in paragraphs (a)(2)(i) and (ii) of this section.

(i) The owner or operator shall conduct 10 minute observations (during normal operation) each operating day the affected facility fires fuel for which an opacity standard is applicable using Method 22 of appendix A-7 of this part and demonstrate that the sum of the occurrences of any visible emissions is not in excess of 5 percent of the observation period ( i.e. , 30 seconds per 10 minute period). If the sum of the occurrence of any visible emissions is greater than 30 seconds during the initial 10 minute observation, immediately conduct a 30 minute observation. If the sum of the occurrence of visible emissions is greater than 5 percent of the observation period ( i.e., 90 seconds per 30 minute period), the owner or operator shall either document and adjust the operation of the facility and demonstrate within 24 hours that the sum of the occurrence of visible emissions is equal to or less than 5 percent during a 30 minute observation ( i.e., 90 seconds) or conduct a new Method 9 of appendix A--4 of this part performance test using the procedures in paragraph (a) of this section within 45 calendar days according to the requirements in §60.45c(a)(8).

(ii) If no visible emissions are observed for 10 operating days during which an opacity standard is applicable, observations can be reduced to once every 7 operating days during which an opacity standard is applicable. If any visible emissions are observed, daily observations shall be resumed.

(3) If the maximum 6-minute opacity is less than 10 percent during the most recent Method 9 of appendix A--4 of this part performance test, the owner or operator may, as an alternative to performing subsequent Method 9 of appendix A--4 performance tests, elect to perform subsequent monitoring using a digital opacity compliance system according to a site-specific monitoring plan approved by the Administrator. The observations shall be similar, but not necessarily identical, to the requirements in paragraph (a)(2) of this section. For reference purposes in preparing the monitoring plan, see OAQPS "Determination of Visible Emission Opacity from Stationary Sources Using Computer-Based Photographic Analysis Systems." This document is available from the U.S. Environmental Protection Agency (U.S. EPA); Office of Air Quality and Planning Standards; Sector Policies and Programs Division; Measurement Policy Group (0243-02), Research Triangle Park, NC 27711. This document is also available on the Technology Transfer Network (TTN) under Emission Measurement Center Preliminary Methods.

(b) All COMS shall be operated in accordance with the applicable procedures under Performance Specification 1 of appendix B of this part. The span value of the opacity COMS shall be between 60 and 80 percent.

A-21 (c) Owners and operators of an affected facilities that burn only distillate oil that contains no more than 0.5 weight percent sulfur and/or liquid or gaseous fuels with potential sulfur dioxide emission rates of 26 ng/J (0.060 Ib/MMBtu) heat input or less and that do not use a post combustion technology to reduce S02 or PM emissions and that are subject to an opacity standard in §60.43c(c) are not required to operate a COMS if they follow the applicable procedures in §60.48c(f).

(d) Owners or operators complying with the PM emission limit by using a PM CEMS must calibrate, maintain, operate, and record the output of the system for PM emissions discharged to the atmosphere as specified in §60.45c(c). The CEMS specified in paragraph §60.45c(c) shall be operated and data recorded during all periods of operation of the affected facility except for CEMS breakdowns and repairs. Data is recorded during calibration checks, and zero and span adjustments.

(e) Owners and operators of an affected facility that is subject to an opacity standard in §60.43c(c) and that does not use post-combustion technology (except a wet scrubber) for reducing PM, S02, or carbon monoxide (CO) emissions, burns only gaseous fuels or fuel oils that contain less than or equal to 0.5 weight percent sulfur, and is operated such that emissions of CO discharged to the atmosphere from the affected facility are maintained at levels less than or equal to 0.15 Ib/MMBtu on a boiler operating day average basis is not required to operate a COMS. Owners and operators of affected facilities electing to comply with this paragraph must demonstrate compliance according to the procedures specified in paragraphs (e)(1) through (4) of this section; or

(1) You must monitor CO emissions using a CEMS according to the procedures specified in paragraphs (e)(1)(i) through (iv) of this section.

(i) The CO CEMS must be installed, certified, maintained, and operated according to the provisions in §60.58b(i)(3) of subpart Eb of this part.

(ii) Each 1-hour CO emissions average is calculated using the data points generated by the CO CEMS expressed in parts per million by volume corrected to 3 percent oxygen (dry basis).

(iii) At a minimum, valid 1-hour CO emissions averages must be obtained for at least 90 percent of the operating hours on a 30-day rolling average basis. The 1-hour averages are calculated using the data points required in §60.13(h)(2).

(iv) Quarterly accuracy determinations and daily calibration drift tests for the CO CEMS must be performed in accordance with procedure 1 in appendix F of this part.

(2) You must calculate the 1-hour average CO emissions levels for each steam generating unit operating day by multiplying the average hourly CO output concentration measured by the CO CEMS times the corresponding average hourly flue gas flow rate and divided by the corresponding average hourly heat input to the affected source. The 24-hour average CO emission level is determined by calculating the arithmetic average of the hourly CO emission levels computed for each steam generating unit operating day.

A-22 (3) You must evaluate the preceding 24-hour average CO emission level each steam generating unit operating day excluding periods of affected source startup, shutdown, or malfunction. If the 24-hour average CO emission level is greater than 0.15 Ib/MMBtu, you must initiate investigation of the relevant equipment and control systems within 24 hours of the first discovery of the high emission incident and, take the appropriate corrective action as soon as practicable to adjust control settings or repair equipment to reduce the 24-hour average CO emission level to 0.15 Ib/MMBtu or less.

(4) You must record the CO measurements and calculations performed according to paragraph (e) of this section and any corrective actions taken. The record of corrective action taken must include the date and time during which the 24-hour average CO emission level was greater than 0.15 Ib/MMBtu, and the date, time, and description of the corrective action.

(f) An owner or operator of an affected facility that is subject to an opacity standard in §60.43c(c) is not required to operate a COMS provided that the affected facility meets the conditions in either paragraphs (f)(1), (2), or (3) of this section.

(1) The affected facility uses a fabric filter (baghouse) as the primary PM control device and, the owner or operator operates a bag leak detection system to monitor the performance of the fabric filter according to the requirements in section §60.48Da of this part.

(2) The affected facility uses an ESP as the primary PM control device, and the owner or operator uses an ESP predictive model to monitor the performance of the ESP developed in accordance and operated according to the requirements in section §60.48Da of this part.

(3) The affected facility burns only gaseous fuels and/or fuel oils that contain no greater than 0.5 weight percent sulfur, and the owner or operator operates the unit according to a written site-specific monitoring plan approved by the permitting authority. This monitoring plan must include procedures and criteria for establishing and monitoring specific parameters for the affected facility indicative of compliance with the opacity standard. For testing performed as part of this site-specific monitoring plan, the permitting authority may require as an alternative to the notification and reporting requirements specified in §§60.8 and 60.11 that the owner or operator submit any deviations with the excess emissions report required under §60.48c(c).

(g) Owners and operators of an affected facility that is subject to an opacity standard in §60.43c(c) and that burns only gaseous fuels or fuel oils that contain less than or equal to 0.5 weight percent sulfur and operates according to a written site-specific monitoring plan approved by the permitting authority is not required to operate a COMS. This monitoring plan must include procedures and criteria for establishing and monitoring specific parameters for the affected facility indicative of compliance with the opacity standard.

[72 FR 32759, June 13, 2007, as amended at 74 FR 5091, Jan. 28, 2009 and 77 FR 9461, Feb. 16,2012]

§ 60.48c Reporting and recordkeeping requirements.

A-23 (a) The owner or operator of each affected facility shall submit notification of the date of construction or reconstruction and actual startup, as provided by §60.7 of this part. This notification shall include:

(1) The design heat input capacity of the affected facility and identification of fuels to be combusted in the affected facility.

(2) If applicable, a copy of any federally enforceable requirement that limits the annual capacity factor for any fuel or mixture of fuels under §60.42c, or §60.43c.

(3) The annual capacity factor at which the owner or operator anticipates operating the affected facility based on all fuels fired and based on each individual fuel fired.

(4) Notification if an emerging technology will be used for controlling S02 emissions. The Administrator will examine the description of the control device and will determine whether the technology qualifies as an emerging technology. In making this determination, the Administrator may require the owner or operator of the affected facility to submit additional information concerning the control device. The affected facility is subject to the provisions of §60.42c(a) or (b)(1), unless and until this determination is made by the Administrator.

(b) The owner or operator of each affected facility subject to the S02 emission limits of §60.42c, or the PM or opacity limits of §60.43c, shall submit to the Administrator the performance test data from the initial and any subsequent performance tests and, if applicable, the performance evaluation of the CEMS and/or COMS using the applicable performance specifications in appendix B of this part.

(c) In addition to the applicable requirements in §60.7, the owner or operator of an affected facility subject to the opacity limits in §60.43c(c) shall submit excess emission reports for any excess emissions from the affected facility that occur during the reporting period and maintain records according to the requirements specified in paragraphs (c)(1) through (3) of this section, as applicable to the visible emissions monitoring method used.

(1) For each performance test conducted using Method 9 of appendix A-4 of this part, the owner or operator shall keep the records including the information specified in paragraphs (c)(1 )(i) through (iii) of this section.

(i) Dates and time intervals of all opacity observation periods;

(ii) Name, affiliation, and copy of current visible emission reading certification for each visible emission observer participating in the performance test; and

(iii) Copies of all visible emission observer opacity field data sheets;

(2) For each performance test conducted using Method 22 of appendix A-4 of this part, the owner or operator shall keep the records including the information specified in paragraphs (c)(2)(i) through (iv) of this section.

A-24 (i) Dates and time intervals of all visible emissions observation periods;

(ii) Name and affiliation for each visible emission observer participating in the performance test;

(iii) Copies of all visible emission observer opacity field data sheets; and

(iv) Documentation of any adjustments made and the time the adjustments were completed to the affected facility operation by the owner or operator to demonstrate compliance with the applicable monitoring requirements.

(3) For each digital opacity compliance system, the owner or operator shall maintain records and submit reports according to the requirements specified in the site-specific monitoring plan approved by the Administrator

(d) The owner or operator of each affected facility subject to the S02 emission limits, fuel oil sulfur limits, or percent reduction requirements under §6D.42c shall submit reports to the Administrator.

(e) The owner or operator of each affected facility subject to the S02 emission limits, fuel oil sulfur limits, or percent reduction requirements under §6D.42c shall keep records and submit reports as required under paragraph (d) of this section, including the following information, as applicable.

(1) Calendar dates covered in the reporting period.

(2) Each 3D-day average S02emission rate (ng/J or Ib/MMBtu), or 3D-day average sulfur content (weight percent), calculated during the reporting period, ending with the last 3D-day period; reasons for any noncompliance with the emission standards; and a description of corrective actions taken.

(3) Each 3D-day average percent of potential S02emission rate calculated during the reporting period, ending with the last 3D-day period; reasons for any noncompliance with the emission standards; and a description of the corrective actions taken.

(4) Identification of any steam generating unit operating days for which S020r diluent (020r CO2) data have not been obtained by an approved method for at least 75 percent of the operating hours; justification for not obtaining sufficient data; and a description of corrective actions taken.

(5) Identification of any times when emissions data have been excluded from the calculation of average emission rates; justification for excluding data; and a description of corrective actions taken if data have been excluded for periods other than those during which coal or oil were not combusted in the steam generating unit.

A-25 (6) Identification of the F factor used in calculations, method of determination, and type of fuel combusted.

(7) Identification of whether averages have been obtained based on GEMS rather than manual sampling methods.

(8) If a GEMS is used, identification of any times when the pollutant concentration exceeded the full span of the GEMS.

(9) If a GEMS is used, description of any modifications to the GEMS that could affect the ability of the GEMS to comply with Performance Specifications 2 or 3 of appendix B of this part.

(10) If a GEMS is used, results of daily GEMS drift tests and quarterly accuracy assessments as required under appendix F, Procedure 1 of this part.

(11) If fuel supplier certification is used to demonstrate compliance, records of fuel supplier certification as described under paragraph (f)(1), (2), (3), or (4) of this section, as applicable. In addition to records of fuel supplier certifications, the report shall include a certified statement signed by the owner or operator of the affected facility that the records of fuel supplier certifications submitted represent all of the fuel combusted during the reporting period.

(f) Fuel supplier certification shall include the following information:

(1) For distillate oil:

(i) The name of the oil supplier;

(ii) A statement from the oil supplier that the oil complies with the specifications under the definition of distillate oil in §60.41 c; and

(iii) The sulfur content or maximum sulfur content of the oil.

(2) For residual oil:

(i) The name of the oil supplier;

(ii) The location of the oil when the sample was drawn for analysis to determine the sulfur content of the oil, specifically including whether the oil was sampled as delivered to the affected facility, or whether the sample was drawn from oil in storage at the oil supplier's or oil refiner's facility, or other location;

(iii) The sulfur content of the oil from which the shipment came (or of the shipment itself); and

(iv) The method used to determine the sulfur content of the oil.

(3) For coal:

A-26 (i) The name of the coal supplier;

(ii) The location of the coal when the sample was collected for analysis to determine the properties of the coal, specifically including whether the coal was sampled as delivered to the affected facility or whether the sample was collected from coal in storage at the mine, at a coal preparation plant, at a coal supplier's facility, or at another location. The certification shall include the name of the coal mine (and coal seam), coal storage facility, or coal preparation plant (where the sample was collected);

(iii) The results of the analysis of the coal from which the shipment came (or of the shipment itself) including the sulfur content, moisture content, ash content, and heat content; and

(iv) The methods used to determine the properties of the coal.

(4) For other fuels:

(i) The name of the supplier of the fuel;

(ii) The potential sulfur emissions rate or maximum potential sulfur emissions rate of the fuel in ng/J heat input; and

(iii) The method used to determine the potential sulfur emissions rate of the fuel.

(g)(1) Except as provided under paragraphs (g)(2) and (g)(3) of this section, the owner or operator of each affected facility shall record and maintain records of the amount of each fuel combusted during each operating day.

(2) As an alternative to meeting the requirements of paragraph (g)(1) of this section, the owner or operator of an affected facility that combusts only natural gas, wood, fuels using fuel certification in §60.48c(f) to demonstrate compliance with the 502 standard, fuels not subject to an emissions standard (excluding opacity), or a mixture of these fuels may elect to record and maintain records of the amount of each fuel combusted during each calendar month.

(3) As an alternative to meeting the requirements of paragraph (g)(1) of this section, the owner or operator of an affected facility or multiple affected facilities located on a contiguous property unit where the only fuels combusted in any steam generating unit (including steam generating units not subject to this subpart) at that property are natural gas, wood, distillate oil meeting the most current requirements in §60.42C to use fuel certification to demonstrate compliance with the 502 standard, and/or fuels, excluding coal and residual oil, not subject to an emissions standard (excluding opacity) may elect to record and maintain records of the total amount of each steam generating unit fuel delivered to that property during each calendar month.

(h) The owner or operator of each affected facility subject to a federally enforceable requirement limiting the annual capacity factor for any fuel or mixture of fuels under §60.42c or §60.43c shall calculate the annual capacity factor individually for each fuel combusted. The

A-27 annual capacity factor is determined on a 12-month rolling average basis with a new annual capacity factor calculated at the end of the calendar month.

(i) All records required under this section shall be maintained by the owner or operator of the affected facility for a period of two years following the date of such record.

0) The reporting period for the reports required under this subpart is each six-month period. All reports shall be submitted to the Administrator and shall be postmarked by the 30th day following the end of the reporting period.

[72 FR 32759, June 13, 2007, as amended at 74 FR 5091, Jan. 28, 2009]

A-28 Appendix B

40 CFR Part 63 Subpart GGGG, - National Emission Standards for Hazardous Air Pollutants (NESHAP) for Solvent Extraction for Vegetable Oil Production. usINFORMATIONGOVERNMEN:;;. GPO

Environmental Protection Agency §63.2830

Citation SUbject Explanation

§63.10(b)(2)(i)-(ii), (iv), Records related to SSM .... No, §§63.998(d)(3) and 63.998(c)(1)(ii)(D) (v). through (G) specify recordkeeping require ments for periods of SSM. §63.10(b)(2)(iii) . Records related to maintenance of air pollution Yes. control equipment §63.10(b)(2)(vi), (x), and CMS Records . Only for CEMS; requirements for CPMS are (xi). specified in referenced subparts G and SS of this part 63. §63.10(b)(2)(vii)-(ix) . Records. Yes. § 63.10(b)(2)(xii) . Records Yes. § 63.10(b)(2)(xiii) Records. Only for CEMS. § 63.10(b)(2)(xiv) Records Yes. §63.10(b)(3) . Records Yes. §63.1 O(c)(1 )-(6),(9)-(15) Records . Only for CEMS. Recordkeeping requirements for CPMS are specified in referenced subparts G and SS of this part 63. § 63.10(c)(7)-(8) . Records . No. Recordkeeping requirements are specified in §63.2525. §63.10(d)(1) General Reporting Requirements . Yes. §63.10(d)(2) Report of Performance Test Results .. Yes. § 63.10(d)(3) Reporting Opacify or VE Observations . No. Subpart FFFF does not contain opacify or VE limits. §63.10(d)(4) Progress Reports . Yes. §63.10(d)(5)(i) Periodic Startup, Shutdown, and Malfunction Re- No, § 63.2520(e)(4) and (5) specify the SSM reports. porting requirements. § 63.10(d)(5)(ii) . Immediate SSM Reports .. No. §63.10(e)(1) Additional CEMS Reports .. Yes. § 63.10(e)(2)(i) ..... Additional CMS Reports. Only for CEMS. §63.10(e)(2)(li) . Additional COMS Reports .. No. Subpart FFFF does not require COMS. § 63.10(e)(3) .... Reports . No. Reporting requirements are specified in §63.2520. § 63.10(e)(3)(i)-(liI) .,. Reports .. No. Reporting requirements are specified in § 63.2520. §63.10(e)(3)(iv)-(v) . Excess Emissions Reports .... No. Reporting requirements are specified 10 §63.2520. §63.10(e)(3)(iv)-(v) .... Excess Emissions Reports. No. Reporting requirements are specified in §63.2520. § 63.10(e)(3)(vi)-(viii) . Excess Emissions Report and Summary Report No. Reporting requirements are specified in §63.2520. §63.10(e)(4) '" Reporting COMS data . No. Subpart FFFF does not contain opacity or VE limits. §63.10(f) Waiver for Recordkeeping/Reporting . Yes. §63.11 . Conirol device requirements for flares and work Yes. practice requirements for equipment leaks. §63.12 . Delegation Yes. §63.13 . Addresses Yes. §63.14 Incorporationby Reference Yes. §63.15. Avaiiability of Information Yes.

[68 FR 63888, Nov. 10, 2003, as amended at 70 FR 38561, July 1, 2005; 71 FR 20463, Apr. 20, 2006; 71 FR 40341, July 14, 2006; 73 FR 72816, Dec. 22, 2008]

subpart GGGG-National Emis WHAT THIS SUBPART COVERS sion Standards for Hazardous § 63.2830 What is the purpose of this Air Pollutants: Solvent Extrac subpart? tion for Vegetable Oil Produc This subpart establishes national tion emission standards for hazardous air pollutants (NESHAP) for emissions SOURCE; 66 FR 19011, Apr. 12, 2001, unless during vegetable oil production, This otherwise noted. subpart limits hazardous air pollutant (HAP) emissions from specified vege table oil production processes, This subpart also establishes requirements to demonstrate initial and continuous compliance with the emission stand ards.

349 §63.2831 40 CFRCh. I (7-1-09 Edition)

§ 63.2831 Where can I find definitions (iii) Flax; of key words used in this subpart? (iv) Peanut; You can find definitions of key words (v) Rapeseed (for example, canola); used in this subpart in §63.2872, (vi) Safflower; (vii) Soybean; and § 63.2832 Am I subject to this subpart? (viii) Sunflower, (a) You are an affected source subject (b) You are not subject to this sub to this subpart if you meet all of the part if your vegetable oil production criteria listed in paragraphs (a nl ) and process meets any of the criteria listed (2) of this section: in paragraphs (b)(I) through (4) of this (1) You own or operate a vegetable oil section: production process that is a major (1) It uses only mechanical extrac source of HAP emissions or is collo tion techniques that use no organic cated within a plant site with other solvent to remove oil from a listed oil sources that are individually or collec seed. tively a major source of HAP emis (2) It uses only batch solvent extrac sions. tion and batch desolventizing equip (i) A vegetable oil production process is ment. defined in §63.2872. In general, it is the (3) It processes only agricultural collection of continuous process equip products that are not listed oilseeds as ment and activities that produce crude defined in §63.2872. vegetable oil and meal products by re (4) It functions only as a research and moving oil from oilseeds listed in Table 1 to §63.2840 through direct contact development facility and is not a major with an organic solvent, such as a source. hexane isomer blend, (c) As listed in §63.1(c)(5) of the Gen (ii) A major source of HAP emissions eral Provisions, if your HAP emissions is a plant site that emits or has the po increase such that you become a major tential to emit any single HAP at a source, then you are subject to all of rate of 10 tons (9.07 megagrams) or the requirements of this subpart. more per year or any combination of HAP at a rate of 25 tons (22.68 §63.2833 Is my source categorized as megagrams) or more per year. existing or new? (2) Your vegetable oil production (a) This subpart applies to each exist- process processes any combination of ing and new affected source. You must eight types of oilseeds listed in para- categorize your vegetable oil produc graphs (a)(2)(i) through (viii) of this tion process as either an existing or a section: new source in accordance with the cri- (i) Corn germ; teria in Table 1 of this section, as fol- (ii) Cottonseed; lows:

TABLE 1 TO § 63,2833-CATEGORIZING YOUR SOURCE AS EXISTING OR NEW

If your affected source... And il... Then your affected source...

(1) was constructed or began construc reconstruction has not occurred . is an existing source. tion before May 26, 2000. (2) began reconstruction, as defined in (i) reconstruction was part of a sched remains an existing source. § 63.2, on or after May 26, 2000. uled plan to comply with the existing source requirements of this subpart; and. (ii) reconstruction was completed no later than 3 years after the effective date of this subpart. (3) began a significant modification. as the modification does not constitute re remains an existing source. defined in § 63.2872, at any time on an construction. existing source. (4) began a significant modification. as the modification does not constitute re remains a newsource. defined in § 63.2872, at any time on a construction. new source. (5) began reconstruction on or after May reconstruction was completed later than is a new source 26,2000. 3 years after the effective date of this subpart.

350 Environmental Protection Agency §63.2834

TABLE 1 TO §63.2833-CATEGORIZING YOUR SOURCE AS EXISTING OR NEw-Continued

If your affected source... And if... Then your affected source...

(6) began construction on or after May is a new source. 26,2000.

(b) Reconstruction of a source. Any af existing equipment within the affected fected source is reconstructed if com source that significantly affects sol ponents are replaced so that the cri vent losses from the affected source. teria in the definition of reconstruction Examples include adding or replacing in §63.2 are satisfied. In general, a veg extractors, desolventizer-toasters (con etable oil production process is recon ventional and specialty), and meal structed if the fixed capital cost of the dryer-coolers. All other significant new components exceeds 50 percent of modifications must meet the criteria the fixed capital cost for constructing listed in paragraphs (c)(l)(i) and (ii) of a new vegetable oil production process, this section: and it is technically and economically (i) The fixed capital cost of the modi feasible for the reconstructed source to fication represents a significant per meet the relevant new source require centage of the fixed capital cost of ments of this subpart. The effect of re building a comparable new vegetable construction on the categorization of oil production process. your existing and new affected source (ii) It does not constitute reconstruc is described in paragraphs (b)(l) and (2) tion as defined in § 63.2. of this section: (2) A significant modification has no (1) After reconstruction of an exist effect on the categorization of your ing source, the affected source is recat source as existing and new. An existing egorized as a new source and becomes source remains categorized as an exist subject to the new source requirements ing source and subject to the existing of this subpart. source requirements of this subpart. A (2) After reconstruction of a new new source remains categorized as a source, the affected source remains new source and subject to the new categorized as a new source and re source requirements of this subpart. mains subject to the new source re (d) Changes in the type of oilseed quirements of this subpart. processed by your affected source does (c) Significant modification of a source. not affect the categorization of your A significant modification to an af source as new or existing. Recatego fected source is a term specific to this rizing an affected source from existing subpart and is defined in § 63.2872. to new occurs only when you add or (1) In general, a significant modifica modify process equipment within the tion to your source consists of adding source which meets the definition of re new equipment or the modification of construction.

§ 63.2834 When do I have to comply with the standards in this subpart? You must comply with this subpart in accordance with one of the schedules in Table 1 of this section, as follows:

TABLE 1 OF §63.2834-COMPLIANCE DATES FOR EXISTING AND NEW SOURCES

If your affected source is categorized And if... Then your compliance date is... as...

(a) an existing source .. 3 years after the effective date of this subpart. (b) a new source ...... you startup your affected source before the effective date of this subpart. the effective date of this subpart. (c) a new source you startup your affected source on or your startup date. after the effective date of this subpart.

351 §63.2840 40 CFR Ch. I (7-1-09 Edition)

STANDARDS calculate a compliance ratio which compares your actual HAP loss to your § 63.2840 What emission requirements allowable HAP loss for the previous 12 must I meet? operating months as shown in Equa For each facility meeting the appli tion 1 of this section. An operating cability criteria in §63.2832, you must month, as defined in §63.2872, is any comply with either the requirements calendar month in which a source proc specified in paragraphs (a) through (d), esses a listed oilseed, excluding any en or the requirements in paragraph (e) of tire calendar month in which the this section. source operated under an initial start (a)(l) The emission requirements up period subject to §63.2850(c)(2) or limit the number of gallons of HAP (d)(2) or a malfunction period subject lost per ton of listed oilseeds processed. to §63.2850(e)(2). Equation 1 of this sec For each operating month, you must tion follows:

· R' Actual Hap Loss CampI lance atio =------"--- (Eq. 1) Allowable Hap Loss

(2) Equation 1 of this section can also section. Equation 2 of this section fol be expressed as a function of total sol lows: vent loss as shown in Equation 2 of this

f * Actual Solvent Loss Compliance Ratio =----n------(Eq. 2) 0.64 * I ((Oilseed)j* (SLF)j) i=l

Where; Actual Solvent Loss = Gallons of actual sol f = The weighted average volume fraction of vent loss during previous 12 operating HAP in solvent received during the pre months. as determined in §63.2853. vious 12 operating months, as determined Oilseed =Tons of each oilseed type "i" proc essed during the previous 12 operating in §63.2854, dimensionless. months. as shown in §63.2855. 0.64 = The average volume fraction of HAP in SLF = The corresponding solvent loss factor solvent in the baseline performance data, (gal/ton) for oilseed "i" listed in Table 1 of dimensionless. this section, as follows;

TABLE 1 OF §63.284Q-OILSEED SOLVENT Loss FACTORS FOR DETERMINING ALLOWABLE HAP Loss

Oilseed solvent loss factor (gal/ton) Type of oilseed process A source that... Existing New sources sources

(i) Corn Germ. Wet Milling . processes corn germ that has been separated 0.4 0.3 from other corn components using a "wet" proc ess of centrifuging a slurry steeped in a dilute sulfurous acid solution. (ii) Corn Germ. Dry Milling . processes corn germ that has been separated 0.7 0.7 from the other corn components using a "dry" process of mechanical chafing and air sifting. (iii) Cottonseed. Large processes 120.000 tons or more of a combination 0.5 0.4 of cottonseed and other listed oilseeds during all normal operating periods in a 12 operating month period.

352 Environmental Protection Agency §63.2840

TABLE 1 OF §63.284Q-OILSEED SOLVENT Loss FACTORS FOR DETERMINING ALLOWABLE HAP Loss-Continued

Oilseed solvent loss factor (gaVton) Type of oilseed process A source that... Existing New sources sources

(iv) Cottonseed, Small ...... processes less than 120,000 tons of a comblna 0.7 0.4 tion of cottonseed and other listed oilseeds duro ing all normal operating periods in a 12 oper ating month period. (v) Flax .. processes flax . . 0.6 0.6 (vi) Peanuts .. processes peanuts . 1.2 0.7 (vii) Rapeseed .. processes rapeseed . 0.7 0.3 (viii) Safflower . processes safflower . 0.7 0.7 (ix) Soybean, Conventional .. uses a conventional style desolventizer to produce 0.2 0.2 crude soybean oil products and soybean animal feed products. (x) Soybean, Specialty .. uses a special style desolventizer to produce soy· 1.7 1.5 bean meal products for human and animal con sumption. (Xi) Soybean, Combination Plant with Low Spe processes soybeans in both specialty and conven 0.25 0.25 cialty Production. tional desolventizers and the quantity of soy beans processed in specialty desolventizers dur ing normal operating periods is less than 3.3 percent of total soybeans processed during all normal operating periods in a 12 operating month period. The corresponding solvent ioss factor is an overall value and applies to the total quantity of soybeans processed .. (xii) Sunflower .. . processes sunflower 0.4 0.3

(b) When your source has processed §63,2872, exclude from the compliance listed oilseed for 12 operating months, ratio determination any solvent and calculate the compliance ratio by the oilseed information recorded for the end of each calendar month following initial startup period. an operating month using Equation 2 (5) If your source is subject to a mal of this section. When calculating your function period as defined in §63.2872, compliance ratio, consider the condi exclude from the compliance ratio de tions and exclusions in paragraphs termination any solvent and oilseed in (b)(l) through (6) of this section: formation recorded for the malfunction (1) If your source processes any quan period. tity of listed oilseeds in a calendar (6) For sources processing cottonseed month and the source is not operating or specialty soybean, the solvent loss under an initial startup period or mal factor you use to determine the com function period subject to §63.2850, pliance ratio may change each oper then you must categorize the month as ating month depending on the tons of an operating month, as defined in oilseed processed during all normal op §63.2872. erating periods in a 12 operating month (2) The 12-month compliance ratio period. may include operating months occur (c) If the compliance ratio is less ring prior to a source shutdown and op than or equal to 1.00, your source was erating months that follow after the in compliance with the HAP emission source resumes operation. requirements for the previous oper (3) If your source shuts down and ating month. processes no listed oilseed for an entire (d) To determine the compliance calendar month, then you must cat ratio in Equation 2 of this section, you egorize the month as a nonoperating must select the appropriate oilseed sol month, as defined in §63.2872. Exclude vent loss factor from Table 1 of this any nonoperating months from the section. First, determine whether your compliance ratio determination. source is new or existing using Table 1 (4) If your source is subject to an ini of §63,2833. Then, under the appropriate tial startup period as defined in existing or new source column, select

353 §63.2850 40 CFRCh. I (7-1-09 Edition) the oilseed solvent loss factor that cor COMPLIANCE REQUIREMENTS responds to each type oilseed or proc ess operation for each operating § 63.2850 How do I comply with the hazardous air pollutant emission month. standards? (e) Low-HAP solvent option. For all vegetable oil production processes sub (a) General requirements. The require ject to this subpart, you must exclu ments in paragraphs (a)(l)(i) through (iv) of this section apply to all affected sively use solvent where the volume sources: fraction of each HAP comprises 1 per (1) Submit the necessary notifica cent or less by volume of the solvent tions in accordance with §63.2860, (low-HAP solvent) in each delivery, and which include: you must meet the requirements in (i) Initial notifications for existing paragraphs (e)(l) through (5) of this sources. section, Your vegetable oil production (ii) Initial notifications for new and process is not subject to the require reconstructed sources. ments in §§ 63,2850 through 63.2870 un (iii) Initial notifications for signifi less specifically referenced in para cant modifications to existing or new graphs (e)(l) through (5) of this section. sources. (1) You shall determine the HAP con (iv) Notification of compliance sta tent of your solvent in accordance with tus. the specifications in §63.2854(b)(1), (2) Develop and implement a plan for (2) You shall maintain documenta demonstrating compliance in accord tion of the HAP content determination ance with §63,2851. for each delivery of the solvent at the (3) Develop a written startup, shut facility at all times. down and malfunction (SSM) plan in (3) You must submit an initial notifi accordance with the provisions in cation for existing sources in accord §63.2852. ance with §63.2860(a). (4) Maintain all the necessary records (4) You must submit an initial notifi you have used to demonstrate compli ance with this subpart in accordance cation for new and reconstructed with §63.2862, sources in accordance with §63.2860(b). (5) Submit the reports in paragraphs (5) You must submit an annual com (a)(5)(i) through (iii) of this section: pliance certification in accordance (i) Annual compliance certifications with §63,2861(a). The certification in accordance with §63.2861(a). should only include the information re (ii) Periodic SSM reports in accord quired under §63.2861(a)(1) and (2), and ance with §63.286l(c). a certification indicating whether the (iii) Immediate SSM reports in ac source complied with all of the require cordance with §63.2861(d). ments in paragraph (e) of this section. (6) Submit all notifications and re (f) You may change compliance op ports and maintain all records required tions for your source if you submit a by the General Provisions for perform notice to the Administrator at least 60 ance testing if you add a control device days prior to changing compliance op that destroys solvent. tions. If your source changes from the (b) Existing sources under normal oper low-HAP solvent option to the compli ation. You must meet all of the require ance ratio determination option, you ments listed in paragraph (a) of this must determine the compliance ratio section and table 1 of this section for for the most recent 12 operating sources under normal operation, and months beginning with the first month the schedules for demonstrating com after changing compliance options. pliance for existing sources under nor mal operation in table 2 of this section. [66 FR 19011, Apr. 12, 2001, as amended at 69 (c) New sources. Your new source, in FR 53341, Sept. 1, 2004] cluding a source that is categorized as new due to reconstruction, must meet the requirements associated with one of two compliance options. Within 15 days of the startup date, you must 354 Environmental Protection Agency §63.2850 choose to comply with one of the op new or existing source must meet all of tions listed in paragraph (c)(1) or (2) of the requirements listed in Table I of this section: this section for sources under normal (1) Normal operation. Upon startup of operation. your new source, you must meet all of (e) Existing or new sources experiencing the requirements listed in §63.2850(a) a malfunction. A malfunction is defined and table 1 of this section for sources in §63.2. In general, it means any sud under normal operation, and the sched den, infrequent, and not reasonably ules for demonstrating compliance for preventable failure of air pollution new sources under normal operation in control equipment or process equip table 2 of this section. ment to function in a usual manner. If (2) Initial startup period. For up to 6 your existing or new source experi calendar months after the startup date ences an unscheduled shutdown as a re of your new source, you must meet all sult of a malfunction, continues to op of the requirements listed in paragraph erate during a malfunction (including (a) of this section and table 1 of this the period reasonably necessary to cor section for sources operating under an rect the malfunction), or starts up initial startup period, and the sched after a shutdown resulting from a mal ules for demonstrating compliance for function, then you must meet the re new sources operating under an initial quirements associated with one of two startup period in Table 2 of this sec compliance options. Routine or sched tion. After a maximum of 6 calendar uled process startups and shutdowns months, your new source must then resulting from, but not limited to, meet all of the requirements listed in market demands, maintenance activi table 1 of this section for sources under ties, and switching types of oilseed normal operation. processed, are not startups or shut (d) Existing or new sources that have downs resulting from a malfunction been significantly modified. Your exist and, therefore, do not qualify for this ing or new source that has been signifi provision. Within 15 days of the begin cantly modified must meet the require ning date of the malfunction, you must ments associated with one of two com choose to comply with one of the op pliance options. Within 15 days of the tions listed in paragraphs (e)(l) modified source startup date, you must through (2) of this section: choose to comply with one of the op (1) Normal operation. Your source tions listed in paragraph (d)(1) or (2) of must meet all of the requirements list this section: ed in paragraph (a) of this section and (1) Normal operation. Upon startup of one of the options listed in paragraphs your significantly modified existing or (e)(1)(i) through (iii) of this section: new source, you must meet all of the (i) EXisting source normal operation requirements listed in paragraph (a) of requirements in paragraph (b) of this this section and table 1 of this section section. for sources under normal operation, (ii) New source normal operation re and the schedules for demonstrating quirements in paragraph (c)(l) of this compliance for an existing or new section. source that has been significantly (iii) Normal operation requirements modified in table 2 of this section. for sources that have been significantly (2) Initial startup period. For up to 3 modified in paragraph (d)(l) of this sec calendar months after the startup date tion. of your significantly modified existing (2) Malfunction period. Throughout or new source, you must meet all of the the malfunction period, you must meet requirements listed in paragraph (a) of all of the requirements listed in para this section and table 1 of this section graph (a) of this section and Table 1 of for sources operating under an initial this section for sources operating dur startup period, and the schedules for ing a malfunction period. At the end of demonstrating compliance for a signifi the malfunction period, your source cantly modified existing or new source must then meet all of the requirements operating under an initial startup pe listed in table 1 of this section for riod in table 2 of this section. After a sources under normal operation. Table maximum of 3 calendar months, your 1 of this section follows: 355 §63.2850 40 CFRCh. I (7-1-09 Edition)

TABLE 1 OF §63.28SQ-REQUIREMENTS FOR COMPLIANCE WITH HAP EMISSION STANDARDS

For initial startup periods sub For periods of normal oper For malfunction periods sub ject to § 632850(c)(2) or Are you required to . ject to § 63.2850(e)(2)? ation? (d)(2)?

(a) Operate and maintain your Yes. Additionally, the HAP Yes, you are required to mini Yes, you are required to sourcein accordancewith emission limits will apply. mize emissions to the ex minimizwe emissions to the general duty provisions of tent practible throughout extent practible throughout §63.6(e)? the initial startup period. the initial startup period. Such measures should be Such measures should be described in the SSM plan. described in the SSM plan. (b) Detenmine and record the Yes, as described in Yes, as described in Yes, as described in extraction solvent loss in gal §63.2853. § 63.2862(e). § 63.2862(e). lons from your source? (c) Record the volume fraction Yes .. Yes . Yes. of HAP present at greater than 1 percent by volume and gallons of extraction sol vent in shipment received? (d) Determine and record the Yes, as described in No. No. tons of each oilseed type §63.2855. processed by your source? (e) Determine the weighted av Yes ... No. Except for solvent re No, the HAP volume fraction erage volume fraction of ceived by a new or recon in any solvent received dur HAP in extraction solvent re structed source com ing a malfunction period is ceived as described in mencingoperation under included in the weighted § 63.2854 by the end of the an initial startup period, the average HAP determination following calendar month? HAP volume fraction in any for the next operating solvent received during an month. initial startup period is in cluded in the weighted av erage HAP determination for the next operating month. (f) Detenmine and record the Yes, . No, these requirements are No, these requirements are actual solvent loss, weighted not applicable because not applicable because average volume fraction yoursource is not required your source is not required HAP, oilseed processed and to detenmine the compli to detenmine the compli compliance ratio for each 12 ance ratio with data re ance ratio with data re operating month period as corded for an initial startup corded for a malfunction described in § 63.2840 by period. period. the end of the following cal endar month». (g) Submit a Notification of Yes, as described in No. However, you may be re No. However, you may be re Compliance Status or An §§ 63.2860(d) and quiredto submitan annual quired to submit an annual nual Compliance Certifi 63.2861 (a). compliance certification for compliance certification for cationas appropriate? previous operating months, previous operating months, if the deadline for the an if the deadline for the an nual compliance certifi nual compliance certifi cationhappens to occur cation happens to occur during the initial startup pe during the malfunction pe riod. riod. (h) Submit a Deviation Notifica Yes . No, these requirements are No, these requirements are tion Report by the end of the not applicable because not applicable because calendar month following the your sourceis not required your sourceis not required month in which you deter to detenmine the compli to detenmine the compli mined that the compliance ance ratio with data re ance ratio with data re ratio exceeds 1.00 as de corded for an initial startup corded tor a malfunction scribed in §63.2861 (b)? period. period. (i) Submit a Periodic SSM Re No, a SSM activity is not cat Yes . Yes. port as described in egorized as nonmal oper §63.2861(c)? ation. (j) Submit an Immediate SSM No, a SSM activity is not cat Yes, only if your source does Yes, only if your source does Report as described in egorized as nonmal oper not follow the SSM plan. not follow the SSM plan. §63.2861(d)? ation.

356 Environmental Protection Agency §63.2851

TABLE 2 OF §63.28SQ-SCHEDULES FOR DEMONSTRATING COMPLIANCE UNDER VARIOUS SOURCE OPERATING MODES

You must determine then your record- Base your first compli- and is operating your first compliance If your source is . keeping ance ratio on intorrna- under. ratio by the end of the schedule. calendar month fol- tion lowing. recorded.

(a) Existing .... Normal operation . Begins on the compli- The first 12 operating During the first 12 oper- ance date. months after the ating months after compliance date. the compliance date. (b) New ...... (1) Normal operation. Begins on the startup The first 12 operating During the first 12 oper- date of your new months after the ating months after source. startup date of the the startup date of newsource. the new source. (2) An initial startup pe- Begins on the startup The first 12 operating During the first 12 oper- riod. date of your new months after termi- ating months after source. nation of the initial the initial startup pe- startup period, which riod, which can last can last for up to 6 for up to 6 months. months. (c) Existing or new that (1) Normal operation .... Resumes on the start- The first operating During the previous 11 has been significantly up date of the modi- month after the start- operating months rnodifled. fied source. up date of the modi- prior to the significant fied source. modification and the first operating month following the initial startup date of the source. (2) An initiai startup pe- Resumes on the start- The first operating During the 11 operating riod. up date of the modi- month after termi- months before the fied source. nation of the initial significant modifica- startup period. which tion and the first op- can last up to 3 erating month after months. the initial startup pe- nod,

[66 FR 19011, Apr. 12, 2001, as amended at 71 pliance by reference in the source's FR 20463, Apr. 20, 2006] title V permit and keep the plan on site and readily available as long as the § 63.2851 What is a plan for dem onstrating compliance? source is operational. If you make any changes to the plan for demonstrating (a) You must develop and implement compliance, then you must keep all a written plan for demonstrating com previous versions of the plan and make pliance that provides the detailed pro them readily available for inspection cedures you will follow to monitor and for at least 5 years after each revision. record data necessary for dem The plan for demonstrating compliance onstrating compliance with this sub must include the items in paragraphs part. Procedures followed for quanti (a)(l) through (7) of this section: fying solvent loss from the source and (1) The name and address of the amount of oilseed processed vary from owner or operator. source to source because of site-spe cific factors such as equipment design (2) The physical address of the vege characteristics and operating condi table oil production process. tions. Typical procedures include one (3) A detailed description of all meth or more accurate measurement meth ods of measurement your source will ods such as weigh scales, volumetric use to determine your solvent losses, displacement, and material mass bal HAP content of solvent, and the tons of ances. Because the industry does not each type of oilseed processed. have a uniform set of procedures, you (4) When each measurement will be must develop and implement your own made. site-specific plan for demonstrating (5) Examples of each calculation you compliance before the compliance date wili use to determine your compliance for your source. You must also incor status. Include examples of how you porate the plan for demonstrating com- will convert data measured with one 357 §63.2852 40 CFRCh. I (7-1-09 Edition)

parameter to other terms for use in operating month includes all solvent compliance determination. losses that occur during normal oper (6) Example logs of how data will be ating periods within the operating recorded. month. If you have determined solvent (7) A plan to ensure that the data losses for 12 or more operating months, continue to meet compliance dem then you must also determine the 12 onstration needs. operating months rolling sum of actual (b) The responsible agency of these solvent loss in gallons by summing the NESHAP may require you to revise monthly actual solvent loss for the your plan for demonstrating compli previous 12 operating months. The 12 ance. The responsible agency may re operating months rolling sum of sol quire reasonable revisions if the proce vent loss is the "actual solvent loss," dures lack detail, are inconsistent or which is used to calculate your compli do not accurately determine solvent ance ratio as described in §63.2840. loss, HAP content of the solvent, or the tons of oilseed processed. (a) To determine the actual solvent loss from your source, follow the proce § 63.2852 What is a startup, shutdown, dures in your plan for demonstrating and malfunction plan? compliance to determine the items in You must develop a written SSM paragraphs (a)(l) through (7) of this plan in accordance with §63.6(e)(3). You section: must complete the SSM plan before the (1) The dates that define each operating compliance date for your source. You status period during a calendar month. must also keep the SSM plan on-site The dates that define each operating and readily available as long as the status period include the beginning source is operational. The SSM plan date of each calendar month and the provides detailed procedures for oper date of any change in the source oper ating and maintaining your source to ating status. If the source maintains minimize emissions during a qualifying the same operating status during an SSM event for which the source choos entire calendar month, these dates are es the §63.2850( e)(2) malfunction period, the beginning and ending dates of the or the §63.2850(c)(2) or (d)(2) initial calendar month. If. prior to the effec startup period. The SSM plan must tive date of this rule, your source de specify a program of corrective action termines the solvent loss on an ac for malfunctioning process and air pol counting month, as defined in §63.2872, lution control equipment and reflect the best practices now in use by the in rather than a calendar month basis, dustry to minimize emissions. Some or and you have 12 complete accounting all of the procedures may come from months of approximately equal dura plans you developed for other purposes tion in a calendar year, you may sub such as a Standard Operating Proce stitute the accounting month time in dure manual or an Occupational Safety terval for the calendar month time in and Health Administration Process terval. If you choose to use an account Safety Management plan. To qualify as ing month rather than a calendar a SSM plan, other such plans must month, you must document this meas meet all the applicable requirements of urement frequency selection in your these NESHAP. plan for demonstrating compliance, [66 FR 19011, Apr. 12, 2001. as amended at 67 and you must remain on this schedule FR 16321. Apr. 5. 2002; 71 FR 20463, Apr. 20, unless you request and receive written 2006] approval from the agency responsible for these NESHAP. § 63.2853 How do I determine the ac (2) Source operating status. You must tual solvent loss? categorize the operating status of your By the end of each calendar month source for each recorded time interval following an operating month, you in accordance with criteria in Table 1 must determine the total solvent loss of this section, as follows: in gallons for the previous operating month. The total solvent loss for an

358 Environmental Protection Agency §63.2853

TABLE 1 OF §63.2853-CATEGORIZING YOUR SOURCE OPERATING STATUS

If during a recorded time interval. .. then your source operating status is . . .

(i) Your source processes any amount of listed oilseed and A normal operating period. source is not operating under an initial startup operating pe riod or a malfunction period subject to § 63.2850(c)(2), (d)(2), or (e)(2). (ii) Your source processes no agricultural product and your A nonoperating period. source is not operating under an initial startup period or mal function period subject to §63.2850(c)(2), (d)(2) , or (e)(2). (iii) You choose to operate your source under an initial startup An initial startup period. period subject to § 63.2850(c)(2) or (d)(2). (iv) You choose to operate your source under a malfunction A malfunction period. period subject to §63.2850(e)(2). (v) Your source processes agricultural products not defined as An exempt period. iisted oilseed.

(3) Measuring the beginning and ending received is not an accurate estimate of solvent inventory. You are required to the "actual solvent loss" for use in de measure and record the solvent inven termining compliance ratios. In such tory on the beginning and ending dates cases, you may adjust the total solvent of each normal operating period that loss for each normal operating period occurs during an operating month. An as long as you provide a reasonable jus operating month is any calendar tification for the adjustment. Situa month with at least one normal oper tions that may require adjustments of ating period. You must consistently the total solvent loss include, but are follow the procedures described in your not limited to, situations in para plan for demonstrating compliance, as graphs (a)(5)(i) and (ii) of this section: specified in §63.2851, to determine the (i) Solvent destroyed in a control device. extraction solvent inventory, and You may use a control device to reduce maintain readily available records of solvent emissions to meet the emission the actual solvent loss inventory, as standard. The use of a control device described in §63.2862(c)(l). In general, does not alter the emission limit for you must measure and record the sol the source. If you use a control device vent inventory only when the source is that reduces solvent emissions through actively processing any type of agricul destruction of the solvent instead of re tural product. When the source is not covery, then determine the gallons of active, some or all of the solvent work solvent that enter the control device ing capacity is transferred to solvent and are destroyed there during each storage tanks which can artificially in normal operating period. All solvent Date the solvent inventory. destroyed in a control device during a (4) Gallons of extraction solvent re normal operating period can be sub ceived. Record the total gallons of ex tracted from the total solvent loss. Ex traction solvent received in each ship amples of destructive emission control ment. For most processes, the gallons devices include catalytic incinerators, of solvent received represents pur boilers, or Dares. Identify and describe, chases of delivered solvent added to the in your plan for demonstrating compli solvent storage inventory. However, if ance, each type of reasonable and your process refines additional vege sound measurement method that you table oil from off-site sources, recovers use to quantify the gallons of solvent solvent from the off-site oil, and adds entering and exiting the control device it to the on-site solvent inventory, and to determine the destruction effi then you must determine the quantity ciency of the control device. You may of recovered solvent and include it in use design evaluations to document the the gallons of extraction solvent re gallons of solvent destroyed or re ceived. moved by the control device instead of (5) Solvent inventory adjustments. In performance testing under § 63.7. The some situations, solvent losses deter design evaluations must be based on mined directly from the measured sol the procedures and options described in vent inventory and quantity of solvent §63.985(b)(1)(i)(A) through (C) or § 63.11, 359 §63.2854 40 CFRCh. I (7-14)9 Edition) as appropriate. All data. assumptions, working capacity in your vegetable oil and procedures used in such evalua production process. Solvent working ca tions must be documented and avail pacity is defined in § 63.2872. In general, able for inspection. If you use perform solvent working capacity is the volume ance testing to determine solvent flow of solvent normally retained in solvent rate to the control device or destruc recovery equipment such as the extrac tion efficiency of the device, follow the tor, desolventizer-toaster, solvent stor procedures as outlined in §63.997(e)(1) age, working tanks, mineral oil ab and (2). Instead of periodic performance sorber, condensers, and oil/solvent dis testing to demonstrate continued good tillation system. If the change occurs operation of the control device, you during a normal operating period, you may develop a monitoring plan, fol lowing the procedures outlined in must determine the difference in work §63.988(c) and using operational para ing solvent volume and make a one metric measurement devices such as time documented adjustment to the fan parameters, percent measurements solvent inventory. of lower explosive limits, and combus (b) Use Equation 1 of this section to tion temperature. determine the actual solvent loss oc (ii) Changes in solvent working ca curring from your affected source for pacity. In records you keep on-site, all normal operating periods recorded document any process modifications within a calendar month. Equation 1 of resulting in changes to the solvent this section follows:

Monthly Actual n Solvent = I,(SOLVB - SOLVE + SOLV R ± SOLVA)j (Eq. I) (gal) i=l

Where: tual solvent loss in Equation 2 of SaLVa = Gallons of solvent in the inventory § 63.2840 to determine the compliance at the beginning of normal operating pe ratio. Actual solvent loss does not in riod "i" as determined in paragraph (a)(3) clude losses that occur during oper of this section. ating status periods listed in para SOLVE = Gallons of solvent in the inventory graphs (c)(l) through (4) of this section. at the end of normal operating period "i" If anyone of these four operating sta as determined in paragraph (a)(3) of this section. tus periods span an entire month, then SOLVR = Gallons of solvent received between the month is treated as nonoperating the beginning and ending inventory dates and there is no compliance ratio deter of normal operating period "i" as deter mination. mined in paragraph (a)(4) of this section. (1) Nonoperating periods as described SaLVA = Gallons of solvent added or re in paragraph (a)(2)(ii) of this section. moved from the extraction solvent inven (2) Initial startup periods as de tory during normal operating period "i" as scribed in §63.2850(c)(2) or (d)(2). determined in paragraph (a)(5) of this sec (3) Malfunction periods as described tion. in §63.2850(e)(2). n = Number of normal operating periods in a calendar month. (4) Exempt operation periods as de scribed in paragraph (a)(2)(v) of this (c) The actual solvent loss is the section. total solvent losses during normal op erating periods for the previous 12 op § 63.2854 How do I determine the erating months. You determine your weighted average volume fraction actual solvent loss by summing the of HAP in the actual solvent loss? monthly actual solvent losses for the (a) This section describes the infor previous 12 operating months. You mation and procedures you must use to must record the actual solvent loss by determine the weighted average vol the end of each calendar month fol ume fraction of HAP in extraction sol lowing an operating month. Use the ac- vent received for use in your vegetable 360 Environmental Protection Agency §63.2854

oil production process. By the end of legal and binding document provided each calendar month following an oper by a solvent manufacturer. The pur ating month, determine the weighted pose of a certificate of analysis is to average volume fraction of HAP in ex list the test methods and analytical re traction solvent received since the end sults that determine chemical prop of the previous operating month. If you erties of the solvent and the volume have determined the monthly weighted percentage of all HAP components average volume fraction of HAP in sol present in the solvent at quantities vent received for 12 or more operating greater than 1 percent by volume. You months, then also determine an overall are not required to test the materials weighted average volume fraction of that you use, but the Administrator HAP in solvent received for the pre may require a test using EPA Method vious 12 operating months. Use the vol 311 (or an approved alternative method) ume fraction of HAP determined as a 12 to confirm the reported HAP content. operating months weighted average in However, if the results of an analysis Equation 2 of §63.2840 to determine the compliance ratio. by EPA Method 311 are different from (b) To determine the volume fraction the HAP content determined by an of HAP in the extraction solvent deter other means, the EPA Method 311 re mined as a 12 operating months weight sults will govern compliance deter ed average, you must comply with minations. paragraphs (b)(l) through (3) of this (2) Determine the weighted average section: volume fraction of HAP in the extrac (1) Record the volume fraction of tion solvent each operating month. The each HAP comprising more than 1 per weighted average volume fraction of cent by volume of the solvent in each HAP for an operating month includes delivery of solvent, including solvent all solvent received since the end of the recovered from off-site oil. To deter last operating month, regardless of the mine the HAP content of the material operating status at the time of the de in each delivery of solvent, the ref livery. Determine the monthly weight erence method is EPA Method 311 of ed average volume fraction of HAP by appendix A of this part. You may use summing the products of the HAP vol EPA Method 311, an approved alter ume fraction of each delivery and the native method, or any other reasonable volume of each delivery and dividing means for determining the HAP con the sum by the total volume of all de tent. Other reasonable means of deter liveries as expressed in Equation 1 of mining HAP content include, but are this section. Record the result by the not limited to, a material safety data end of each calendar month following sheet or a manufacturer's certificate of an operating month. Equation 1 of this analysis. A certificate of analysis is a section follows:

n Monthly Weighted I,[Received, * Content.] Average HAP Content _ -"i=::.,ol _ (Eq. 1) of Extraction Solvent - Total Received (volume fraction)

Where: n = Number of extraction solvent deliveries Received; = Gallons of extraction solvent re since the end of the previous operating month. ceived in delivery "I." Content, = The volume fraction of HAP in ex (3) Determine the volume fraction of traction solvent delivery "I." HAP in your extraction solvent as a 12 Total Received = Total gallons of extraction operating months weighted average. solvent received since the end of the pre When your source has processed oilseed vious operating month. for 12 operating months, sum the prod ucts of the monthly weighted average 361 §63.2855 40 CFR Ch. I (7-1-09 Edition)

HAP volume fraction and cor end of each calendar month following responding volume of solvent received, an operating month and use it in Equa and divide the sum by the total volume tion 2 of §63.2840 to determine the com of solvent received for the 12 operating pliance ratio. Equation 2 of this section months, as expressed by Equation 2 of follows: this section. Record the result by the

12 12-Month Weighted I [Received,> Content.] Average of HAP Content _ ..!.:i-::.l.I _ CEq. 2) in Solvent Received - Total Received (volume fraction)

Where: your plan for demonstrating compli Received; = Gallons of extraction solvent re ance to determine the items in para ceived in operating month "i" as deter graphs (a)(l) through (5) of this section: mined in accordance with §63.2853(a)(4). (1) The dates that define each operating Content; = Average volume fraction of HAP status period. The dates that define in extraction solvent received in operating each operating status period include month "i" as determined in accordance with paragraph (b)(l) of this section. the beginning date of each calendar Total Received =Total gallons of extraction month and the date of any change in solvent received during the previous 12 op the source operating status. If, prior to erating months. the effective date of this rule, your source determines the oilseed inven § 63.2855 How do I determine the tory on an accounting month rather quantity of oilseed processed? than a calendar month basis, and you All oilseed measurements must be have 12 complete accounting months of determined on an as received basis. as approximately equal duration in a cal defined in §63.2872. The as received endar year, you may substitute the ac basis refers to the oilseed chemical and counting month time interval for the physical characteristics as initially re calendar month time interval. If you ceived by the source and prior to any choose to use an accounting month oilseed handling and processing. By the rather than a calendar month, you end of each calendar month following must document this measurement fre an operating month, you must deter quency selection in your plan for dem mine the tons as received of each listed onstrating compliance, and you must oilseed processed for the operating remain on this schedule unless you re month. The total oilseed processed for quest and receive written approval an operating month includes the total from the agency responsible for these of each oilseed processed during all NESHAP. The dates on each oilseed in normal operating periods that occur ventory log must be consistent with within the operating month. If you the dates recorded for the solvent in have determined the tons of oilseed ventory. processed for 12 or more operating (2) Source operating status. You must months, then you must also determine categorize the source operation for the 12 operating months rolling sum of each recorded time interval. The each type oilseed processed by sum source operating status for each time ming the tons of each type of oilseed interval recorded on the oilseed inven processed for the previous 12 operating tory for each type of oilseed must be months. The 12 operating months roll consistent with the operating status ing sum of each type of oilseed proc recorded on the solvent inventory logs essed is used to calculate the compli as described in §63.2853(a)(2). ance ratio as described in §63.2840. (3) Measuring the beginning and ending (a) To determine the tons as received inventory for each oilseed. You are re of each type of oilseed processed at quired to measure and record the oil your source. follow the procedures in seed inventory on the beginning and 362 Environmental Protection Agency §63.2855 ending dates of each normal operating (i) Oilseed that mold or otherwise be period that occurs during an operating come unsuitable for processing. month. An operating month is any cal (ii) Oilseed you sell before it enters endar month with at least one normal the processing operation. operating period. You must consist (iii) Oilseed destroyed by an event ently follow the procedures described such as a process malfunction, fire, or in your plan for demonstrating compli natural disaster. ance, as specified in §63.2851, to deter (iv) Oilseed processed through oper mine the oilseed inventory on an as re ations prior to solvent extraction such ceived basis and maintain readily as screening, dehulling, cracking, dry available records of the oilseed inven ing, and conditioning; but that are not tory as described by §63.2862(c)(3). (4) Tons of each oilseed received. routed to the solvent extractor for fur Record the type of oilseed and tons of ther processing. each shipment of oilseed received and (vl Periodic physical measurements added to your on-site storage. of inventory. For example, some (5) Oilseed inventory adjustments. In sources periodically empty oilseed some situations, determining the quan storage silos to physically measure the tity of oilseed processed directly from current oilseed inventory. This peri the measured oilseed inventory and odic measurement procedure typically quantity of oilseed received is not an results in a small inventory correction. accurate estimate of the tons of oilseed The correction factor, usually less than processed for use in determining com 1 percent, may be used to make an ad pliance ratios. For example, spoiled justment to the source's oilseed inven and molded oilseed removed from stor tory that was estimated previously age but not processed by your source with indirect measurement techniques. will result in an overestimate of the To make this adjustment, your plan for quantity of oilseed processed. In such demonstrating compliance must pro cases, you must adjust the oilseed in vide for such an adjustment. ventory and provide a justification for (b) Use Equation 1 of this section to the adjustment. Situations that may determine the quantity of each oilseed require oilseed inventory adjustments type processed at your affected source include, but are not limited to, the sit during normal operating periods re uations listed in paragraphs (a)(5)(i) corded within a calendar month. Equa through (v) of this section: tion 1 of this section follows:

Monthly Quantity n of Each Oilseed = I,(SEED B -SEEDE +SEEDR ±SEEDA ) (Eq. 1) Processed (tons) n=l

Where: n = Number of normal operating periods in the calendar month during which this type SEEDB ~ Tons of oilseed in the inventory at the beginning of normal operating period oilseed was processed. "i" as determined in accordance with para (c) The quantity of each oilseed proc graph (a)(3) of this section. essed is the total tons of each type of SEEDE = Tons of oilseed in the inventory at the end of normal operating period "i" as listed oilseed processed during normal determined in accordance with paragraph operating periods in the previous 12 op (a)(3) of this section. erating months. You determine the SEEDR = Tons of oilseed received during nor tons of each oilseed processed by sum mal operating period "i" as determined in ming the monthly quantity of each oil accordance With paragraph (a)(4) of this seed processed for the previous 12 oper section. ating months. You must record the 12 SEEDA = Tons of oilseed added or removed from the oilseed inventory during normal operating months quantity of each operating period "i" as determined in ac type of oilseed processed by the end of cordance with paragraph (a)(5) of this sec each calendar month following an oper tion. ating month. Use the 12 operating 363 §63.2860 40 CFRCh. I (7-1-09 Edition) months quantity of each type of oilseed structed sources must submit a series processed to determine the compliance of notifications before. during, and ratio as described in §63.2840. The quan after source construction per the tity of oilseed processed does not in schedule listed in §63.9. The informa clude oilseed processed during the op tion requirements for the notifications erating status periods in paragraphs are the same as those listed in the Gen (c)(1) through (4) of this section: eral Provisions with the exceptions (1) Nonoperating periods as described listed in paragraphs (b)(l) and (2) of in §63.2853 (a)(2)(ii). this section: (2) Initial startup periods as de (1) The application for approval of scribed in §63.2850(c)(2) or (d)(2). construction does not require the spe (3) Malfunction periods as described cific HAP emission data required in in §63.2850(e)(2). §63.5(d)(1)(ii)(H) and (iii), (d)(2) and (4) Exempt operation periods as de (d)(3)(ii). The application for approval scribed in §63.2853 (a)(2)(v). of construction would include, instead, (5) If anyone of these four operating a brief description of the source includ status periods span an entire calendar ing the types of listed oilseeds proc month, then the calendar month is essed. nominal operating capacity, and treated as a nonoperating month and type of desolventizer(s) used. there is no compliance ratio deter (2) The notification of actual startup mination. date must also include whether you have elected to operate under an initial NOTIFICATIONS. REPORTS, AND RECORDS startup period subject to §63.2850(c)(2) § 63.2860 What notifications must I and provide an estimate and justifica submit and when? tion for the anticipated duration of the You must submit the one-time notifi initial startup period. cations listed in paragraphs (a) (c) Significant modification notifica through (d) of this section to the re tions. Any existing or new source that sponsible agency: plans to undergo a significant modi (a) Initial notification for existing fication as defined in §63.2872 must sub sources. For an existing source. submit mit two reports as described in para an initial notification to the agency re graphs (c)(l) and (2) of this section: sponsible for these NESHAP no later (1) Initial notification. You must sub than 120 days after the effective date of mit an initial notification to the agen this subpart. In the notification, in cy responsible for these NESHAP 30 clude the items in paragraphs (a)(1) days prior to initial startup of the sig through (5) of this section: nificantly modified source. The initial (1) The name and address of the notification must demonstrate that the owner or operator. proposed changes qualify as a signifi (2) The physical address of the vege cant modification. The initial notifica table oil production process. tion must include the items in para (3) Identification of the relevant graphs (c)(l)(i) and (ii) of this section: standard, such as the vegetable oil pro (i) The expected startup date of the duction NESHAP, and compliance date. modified source. (4) A brief description of the source (ii) A description of the significant including the types of listed oilseeds modification including a list of the processed, nominal operating capacity. equipment that will be replaced or and type of desolventizer(s) used. modified. If the significant modifica (5) A statement designating the tion involves changes other than add- source as a major source of HAP or a ing or replacing extractors, demonstration that the source meets desolventizer-toasters (conventional the definition of an area source. An and specialty), and meal dryer-coolers, area source is a source that is not a then you must also include the fixed major source and is not collocated capital cost of the new components, ex within a plant site with other sources pressed as a percentage of the fixed that are individually or collectively a capital cost to build a comparable new major source. vegetable oil production process; sup (b) Initial notifications for new and re porting documentation for the cost es constructed sources. New or recon- timate: and documentation that the 364 Environmental Protection Agency §63.2861 proposed changes will significantly af (5) A statement designating the fect solvent losses. source as a major source of HAP or a (2) Notification of actual startup. demonstration that the source quali You must submit a notification of ac fies as an area source. An area source tual startup date within 15 days after is a source that is not a major source initial startup of the modified source. and is not collocated within a plant The notification must include the site with other sources that are indi items in paragraphs (c)(2)(i) through vidually or collectively a major source. (iv) of this section: (6) A compliance certification indi (i) The initial startup date of the cating whether the source complied modified source. with all of the requirements of this (ii) An indication whether you have subpart throughout the 12 operating elected to operate under an initial months used for the initial source com startup period subject to § 63.2850(d)(2). pliance determination. This certifi (iii) The anticipated duration of any cation must include a certification of initial startup period. the items in paragraphs (d)(6)(i) (iv) A justification for the antici through (iii) of this section: pated duration of any initial startup (i) The plan for demonstrating com period. pliance (as described in §63.2851) and (d) Notification of compliance status. As SSM plan (as described in §63.2852) are an existang, new, or reconstructed complete and available on-site for in source, you must submit a notification spection. of compliance status report to the re (ii) You are following the procedures sponsible agency no later than 60 days described in the plan for demonstrating after determining your initial 12 oper compliance. ating months compliance ratio. If you (iii) The compliance ratio is less than are an existing source, you generally or equal to 1.00. must submit this notification no later than 50 calendar months after the ef § 63.2861 What reports must I submit fective date of these NESHAP (36 cal and when? endar months for compliance, 12 oper After the initial notifications, you ating months to record data, and 2 cal must submit the reports in paragraphs endar months to complete the report). (a) through (d) of this section to the If you are a new or reconstructed agency responsible for these NESHAP source, the notification of compliance at the appropriate time intervals: status is generally due no later than 20 (a) Annual compliance certifications. calendar months after initial startup (6 The first annual compliance certifi calendar months for the initial startup cation is due 12 calendar months after period, 12 operating months to record you submit the notification of compli data, and 2 calendar months to com ance status. Each subsequent annual plete the report). The notification of compliance certification is due 12 cal compliance status must contain the endar months after the previous annual items in paragraphs (d)(l) through (6) compliance certification. The annual of this section: compliance certification provides the (1) The name and address of the compliance status for each operating owner or operator. month during the 12 calendar months (2) The physical address of the vege period ending 60 days prior to the date table oil production process. on which the report is due. Include the (3) Each listed oilseed type processed information in paragraphs (a)(l) during the previous 12 operating through (6) of this section in the an months. nual certification: (4) Each HAP identified under (1) The name and address of the §63.2854(a) as being present in con owner or operator. centrations greater than 1 percent by (2) The physical address of the vege volume in each delivery of solvent re table oil production process. ceived during the 12 operating months (3) Each listed oilseed type processed period used for the initial compliance during the 12 calendar months period determination. covered by the report. 365 §63.2862 40 CFRCh. I (7-1-09 Edition)

(4) Each HAP identified under periodic SSM report by the end of the §63.2854(a) as being present in con calendar month following each month centrations greater than 1 percent by in which the initial startup period or volume in each delivery of solvent re malfunction period occurred. The peri ceived during the 12 calendar months odic SSM report must include the period covered by the report. items in paragraphs (c)(I) through (3) (5) A statement designating the of this section: source as a major source of HAP or a (1) The name, title, and signature of demonstration that the source quali a source's responsible official who is fies as an area source. An area source certifying that the report accurately is a source that is not a major source states that all actions taken during the and is not collocated within a plant initial startup or malfunction period site with other sources that are indi were consistent with the SSM plan. vidually or collectively a major source. (2) A description of events occurring (6) A compliance certification to in during the time period, the date and dicate whether the source was in com duration of the events, and reason the pliance for each compliance determina time interval qualifies as an initial tion made during the 12 calendar startup period or malfunction period. months period covered by the report. (3) An estimate of the solvent loss For each such compliance determina during the initial startup or malfunc tion, you must include a certification tion period with supporting docu of the items in paragraphs (a)(6)(i) mentation. through (ii) of this section: (d) Immediate SSM reports. If you han (i) You are following the procedures dle a SSM during an initial startup pe described in the plan for demonstrating riod subject to §63.2850(c)(2) or (d)(2) or compliance. a malfunction period subject to (ii) The compliance ratio is less than §63.2850(e)(2) differently from proce or equal to 1.00. dures in the SSM plan and the relevant (b) Deviation notification report. Sub emission requirements in §63.2840 are mit a deviation report for each compli exceeded. then you must submit an im ance determination you make in which mediate SSM report. Immediate SSM the compliance ratio exceeds 1.00 as de reports consist of a telephone call or termined under §63.2840(c). Submit the facsimile transmission to the respon deviation report by the end of the sible agency within 2 working days month following the calendar month in after starting actions inconsistent with which you determined the deviation. the SSM plan, followed by a letter The deviation notification report must within 7 working days after the end of include the items in paragraphs (b)(I) the event. The letter must include the through (4) of this section: items in paragraphs (d)(I) through (3) (1) The name and address of the of this section: owner or operator. (1) The name, title, and signature of (2) The physical address of the vege a source's responsible official who is table oil production process. certifying the accuracy of the report, (3) Each listed oilseed type processed an explanation of the event, and the during the 12 operating months period reasons for not following the SSM plan. for which you determined the devi (2) A description and date of the SSM ation. event, its duration, and reason it quali (4) The compliance ratio comprising fies as a SSM. the deviation. You may reduce the fre (3) An estimate of the solvent loss for quency of submittal of the deviation the duration of the SSM event with notification report if the agency re supporting documentation. sponsible for these NESHAP does not [66 FR 19011. Apr. 12. 2001. as amended at 67 object as provided in §63.10(e)(3)(iii). FR 16321. Apr. 5, 2002] (c) Periodic startup, shutdown, and malfunction report. If you choose to op § 63.2862 What records must I keep? erate your source under an initial (a) You must satisfy the record startup period subject to §63.2850(c)(2) keeping requirements of this section by or (d)(2) or a malfunction period sub the compliance date for your source ject to §63.2850(e)(2), you must submit a specified in Table 1 of §63.2834. 366 Environmental Protection Agency §63.2862

(b) Prepare a plan for demonstrating ating month as determined in accord compliance (as described in §63.2851) ance with §63.2854(b)(2). and a SSM plan (as described in (3) For each type of listed oilseed §63.2852). In these two plans, describe processed, record the items in para the procedures you will follow in ob graphs (c)(3)(i) through (vi) of this sec taining and recording data, and deter tion, in accordance with your plan for mining compliance under normal oper demonstrating compliance: ations or a SSM subject to the (i) The dates that define each oper §63.2850(c)(2) or (d)(2) initial startup pe ating status period. These dates must riod or the §63.2850(e)(2) malfunction be the same as the dates entered for period. Complete both plans before the the extraction solvent inventory. compliance date for your source and (ii) The operating status of your keep them on-site and readily available source such as normal operation, non as long as the source is operational. operating, initial startup period, mal (c) If your source processes any listed function period, or exempt operation oilseed, record the items in paragraphs for each recorded time interval. On the (c)(l) through (5) of this section: log for each type of listed oilseed that (1) For the solvent inventory, record is not being processed during a normal the information in paragraphs (c)(l)(i) operating period, you must record through (vii) of this section in accord which type of listed oilseed is being ance with your plan for demonstrating processed in addition to the source op compliance: erating status. (I) Dates that define each operating (iii) The oilseed inventory for the status period during a calendar month. type of listed oilseed being processed (ii) The operating status of your on the beginning and ending dates of source such as normal operation, non each normal operating period. operating, initial startup period, mal (iv) The tons of each type of listed function period, or exempt operation oilseed received at the affected source for each recorded time interval. each normal operating period. (iii) Record the gallons of extraction (v) All listed oilseed inventory ad solvent in the inventory on the begin justments, additions or subtractions ning and ending dates of each normal for normal operating periods. You must operating period. document the reason for the adjust (iv) The gallons of all extraction sol ment and justify the quantity of the vent received, purchased, and recov adjustment. ered during each calendar month. (Vi) The tons of each type of listed (v) All extraction solvent inventory oilseed processed during each operating adjustments, additions or subtractions. month. You must document the reason for the (d) After your source has processed adjustment and justify the quantity of listed oilseed for 12 operating months, the adjustment. and you are not operating during an (vi) The total solvent loss for each initial startup period as described in calendar month, regardless of the §63.2850(c)(2) or (d)(2), or a malfunction source operating status. period as described in §63.2850(e)(2), (vii) The actual solvent loss in gal record the items in paragraphs (d)(l) lons for each operating month. through (5) of this section by the end of (2) For the weighted average volume the calendar month following each op fraction of HAP in the extraction sol erating month: vent, you must record the items in (1) The 12 operating months rolling paragraphs (c)(2)(i) through (iii) of this sum of the actual solvent loss in gal section: lons as described in §63.2853(c). (i) The gallons of extraction solvent (2) The weighted average volume received in each delivery. fraction of HAP in extraction solvent (ii) The volume fraction of each HAP received for the previous 12 operating exceeding 1 percent by volume in each months as described in §63.2854(b)(3). delivery of extraction solvent. (3) The 12 operating months rolling (iii) The weighted average volume sum of each type of listed oilseed proc fraction of HAP in extraction solvent essed at the affected source in tons as received since the end of the last oper- described in §63.2855(c). 367 §63.2863 40 CFR Ch. I (7-1-09 Edition)

(4) A determination of the compli startup or malfunction period with ance ratio. Using the values from supporting documentation. §§ 63.2853, 63.2854, 63.2855, and Table 1 of (3) A checklist or other mechanism §63.2840, calculate the compliance ratio to indicate whether the SSM plan was using Equation 2 of §63.2840. followed during the initial startup or (5) A statement of whether the source malfunction period. is in compliance with all of the re quirements of this subpart. This in § 63.2863 In what form and how long cludes a determination of whether you must I keep my records? have met all of the applicable require (a) Your records must be in a form ments in §63.2850. suitable and readily available for re (e) For each SSM event subject to an view in accordance with §63.10(b)(1). initial startup period as described in (b) As specified in §63.10(b)(I), you §63.2850(c)(2) or (d)(2), or a malfunction must keep each record for 5 years fol period as described in §63.2850(e)(2), lowing the date of each occurrence, record the items in paragraphs (e)(I) measurement, maintenance, corrective through (3) of this section by the end of action, report, or record. the calendar month following each (c) You must keep each record on-site month in which the initial startup pe for at least 2 years after the date of riod or malfunction period occurred: each occurrence, measurement, main (1) A description and date of the SSM tenance. corrective action, report, or event, its duration. and reason it quali record. in accordance with §3.10(b)(I). fies as an initial startup or malfunc You can keep the records off-site for tion. the remaining 3 years. (2) An estimate of the solvent loss in gallons for the duration of the initial OTHER REQUIREMENTS AND INFORMATION

§ 63.2870 What parts of the General Provisions apply to me? Table 1 of this section shows which parts of the General Provisions in §§ 63.1 through 63.15 apply to you. Table 1 of §63.2870 follows:

TABLE 1 OF §63.287Q-ApPLICABILITY OF 40 CFR PART 63, SUBPART A, TO 40 CFR, PART 63, SUBPART GGGG

General provisions Brief description of re Applies to sub Subject of citation Explanation citation quirement part

§63.1 Applicability . Initial applicability de Yes. termination; applica bility after standard established; permit requirements; exten sions: notifications. §63.2 .. Definitions . Definitions for part 63 Yes ...... Except as specifically provided in standards. this subpart. §63.3 .. Units and abbreviations Units and abbreviations Yes. for part 63 standards. §63.4 .. Prohibited activities and Prohibited activities; Yes . circumvention. compliance date; cir cumvention; sever ability. §63.5 . Construction/recon Applicability; applica Yes .. Except for subsections of § 63.5 as struction. tions; approvais. listed below. §63.5(c) .. [ReseNed] . § 63.5(d)(1 )(ii)(H) Application for approval Type and quantity of No All sources emit HAP. Subpart HAP. operating pa GGGG does not require control rameters. from specific emission points. § 63.5(d)(1 )(ii)(l) . [Heserved]

368 Environmental Protection Agency §63.2870

TABLE 1 OF §63.287Q-APPLICABILITY OF 40 CFR PART 63, SUBPART A, TO 40 CFR, PART 63, SUBPART GGGG-Continued

General provisions Subject of citation Brief description of re Applies to sub citation quirement part Explanation

§ 63.5(d)(1)(iii), Application for approval No .... The requirements of the application (d)(2), (d)(3)(ii). for approval for new. recon structed and significantly modi fied sources are described in § 63.2860(b) and (c) of subpart GGGG. General provision re quirements for identification of HAP emission points or esti mates of actual emissions are not required. Descriptions of con trol and methods. and the esti mated and actual control effi ciency of such do not apply. Re quirements for describing control equipment and the estimated and actual control efficiency of such equipment apply only to control equipment to which the subpart GGGG requirements for quantifying. § 63.6 ... Applicability of General Applicability . Yes. Except for subsections of §63.6 as Provisions. listed below. §63.6(b)(I)-(3) ...... Compliance dates, new No .... Section 63.2834 of subpart GGGG and reconstructed specifies the compliance dates sources. for new and reconstructed sources, §63.6(b)(6) . [Reserved] . § 63.6(c)(3)-(4) . [Reserved] . §63.6(d) . [Reserved] . § 63.6(e)(l) through Operation and mainte- Yes .. Minimize emissions to the extent (e)(3)(ii) and nance requirements. practical. §63.6(e)(3)(v) through (vii). §63.6(e)(3)(iii) . Operation and mainte No . Minimize emissions to the extent nance requirements. practical § 63.6(e)(3)(iv) Operation and mainte ...... No Report SSM and in accordance nance requirements. with § 63.2861(c) and (d). § 63.6(e)(3)(viii) ...... Operation and mainte Yes . Except. report each revision to nance requirements. your SSM plan in accordance with § 63.2861(c) rather than § 63.1O(d)(5) as required under §63.6(e)(3) (viii). § 63.6(e)(3)(ix) Title V permit Yes. §63.6(f)-(g) Compliance with non Comply with emission No ... Subpart GGGG does not have opacity emission standards at all times nonopacity requirements. standards except except during SSM. during SSM. § 63.6(h) OpacityNisible emis- No . Subpart GGGG has no opacity or sion (VE) standards. VE standards. §63.6(i) Compliance extension Procedures and criteria Yes . for responsible agen cy to grant compli ance extension. §63.6U) '" . Presidential compliance President may exempt Yes . exemption. source category from requirement to com ply with subpart. §63.7 . Performance testing re Schedule. conditions. Yes . Subpart GGGG requires perform quirements. notifications and pro ance testing only if the source cedures. applies additional control that de stroys solvent. Section 63.2850(a)(6) requires sources to follow the performance testing guidelines of the General Provi sions if a control is added. § 63.8 Monitoring require- No . Subpart GGGG does not require ments. monitoring other than as speci fied therein. 369 §63.2870 40 CFR Ch. I (7-1-09 Edition)

TABLE 1 OF §63.287D-ApPLICABILITY OF 40 CFR PART 63, SUBPART A, TO 40 CFR, PART 63, SUBPART GGGG-Continued

Brief description of re Applies to sub General provisions Subject of citation Explanation citation quirement part

§63.9 . Notification require Applicability and state Yes .. Except for subsections of § 63.9 as ments. delegation. listed below. §63.9(b)(2) . Notification require Initial notification re No ... Section 63.2860(a) of subpart ments. quirements for exist GGGG specifies the require ingsources. ments of the initial notification for existing sources. § 63.9(b)(3)-(5) ...... Notification require Notification requirement Yes .... Except the information require ments. for certain new/re ments differ as described in constructed sources. § 63.2860(b) of subpart GGGG. §63.9(e) . Notification of perform Notify responsible Yes. Applies only if performance testing ance test. agency 60 days is performed. ahead. §63.9(f) . Notification of VEiopac Notify responsible No Subpart GGGG has no opacity or ity observations. agency 30 days VE standards. ahead. §63.9(g) ... Additional notifications Notification of perform No Subpart GGGG has no CMS re when using a contin ance evaluation; No quirements. uous monitoring sys tification using tem (CMS). COMS data; notifica tion that exceeded criterion for relative accuracy. §63.9(h) . Notification of compli Contents .. No Section 63.2860(d) of subpart ance status. GGGG specifies requirements for the notification of compliance status. §63.10 .. Recordkeeping/report Schedule for reporting, Yes . Except for subsections of § 63.10 ing. record storage. as listed below. § 63.10(b)(2)(i) . Recordkeeping .... Record SSM event . Yes. Applicable to periods when sources must implement their SSM plan as specified in subpart GGGG. § 63.10(b)(2)(iiHiii) Recordkeeping . Malfunction of air pollu No Applies only if air pollution control tion equipment. equipment has been added to the process and is necessary for the source to meet the emission limit. § 63.10(b)(2)(vi) Recordkeeping . CMS recordkeeping . No Subpart GGGG has no CMS re quirements. § 63.10(b)(2)(viii) Recordkeeping ...... Conditions of perform Yes .. Applies only if performance tests (ix). ance test. are performed. Subpart GGGG does not have any CMS opacity or VE observation requirements. § 63.10(b)(2)(x)-(xii) Recordkeeping . CMS. performance No ...... Subpart GGGG does not require testing, and opacity CMS. and VE observations recordkeeping. §63.10(C) . Recordkeeping .. Additional CMS record- No ...... Subpart GGGG does not require keeping. CMS. §63.10(d)(2) Reporting Reporting performance Yes ...... Applies only if performance testing test results. is performed. §63.10(d)(3) Reporting Reporting opacity or No ...... Subpart GGGG has no opacity or VE observations. VE standards. §63.10(d)(4) Reporting Progress reports . Yes. Applies only if a condition of com pliance extension exists. § 63.10(d)(5) Reporting SSM reporting. No Section 63.2861(c) and (d) specify SSM reporting requirements. §63.10(e) . Reporting Additionai CMS reports No Subpart GGGG does not require CMS. §63.11 Control device require Requirements for flares Yes. Applies only if your source uses a ments. flare to control solvent emis sions. Subpart GGGG does not require flares. § 63.12 State authority and del- State authority to en Yes . egations. force standards. § 63.13 State/regional address- Addresses where re Yes . es. ports, notifications, and requests are sent. § 63.14 Incorporation by ref- Test methods incor Yes. erence. porated by reference. 370 Environmental Protection Agency §63.2872

TABLE 1 OF §63.287D-ApPLICABILITY OF 40 CFR PART 63, SUBPART A, TO 40 CFR, PART 63, SUBPART GGGG-Continued

General provisions Brief description of re- Applies to sub- Subject of citation Explanation citation quirement part

§63.15 ...... Availability of informa- Public and confidential Yes ...... lion and confiden- infonnation. tiality.

[66 FR 19011, Apr. 12, 2001, as amended at 67 FR 16321, Apr. 5, 2002: 71 FR 20463, Apr. 20, 2006]

§ 63.2871 Who implements and en (b) In 40 CFR 63.2, the NESHAP Gen forces this subpart? eral Provisions. (a) This subpart can be implemented (c) In this section as follows: by us, the U.S. EPA, or a delegated au Accounting month means a time inter thority such as your State, local, or val defined by a business firm during tribal agency. If the U.S. EPA Admin which corporate economic and finan istrator has delegated authority to cial factors are determined on a con your State, local, or tribal agency, sistent and regular basis. An account then that agency, as well as the U.S. ing month will consist of approxi EPA, has the authority to implement mately 4 to 5 calendar weeks and each and enforce this subpart, You should accounting month will be of approxi contact your U.S. EPA Regional Office mate equal duration. An accounting to find out if this subpart is delegated month may not correspond exactly to a to your State, local, or tribal agency. calendar month, but 12 accounting months will correspond exactly to a (b) In delegating implementation and calendar year. enforcement authority of this subpart to a State, local, or tribal agency Actual solvent loss means the gallons under section 40 CFR part 63, subpart of solvent lost from a source during 12 E, the authorities contained in para operating months as determined in ac graph (c) of this section are retained by cordance with §63.2853. the Administrator of the U.S. EPA and Agricultural product means any com are not transferred to the State, local, mercially grown plant or plant prod or tribal agency. uct. (c) The authorities that will not be Allowable HAP loss means the gallons delegated to State, local, or tribal of HAP that would have been lost from agencies are as follows: a source if the source was operating at the solvent loss factor for each listed (1) Approval of alternative non oilseed type, The allowable HAP loss in opacity emissions standards under gallons is determined by multiplying §63.6(g). the tons of each oilseed type processed (2) Approval of alternative opacity during the previous 12 operating standards under §63.6(h)(9). months, as determined in accordance (3) Approval of major alternatives to with §63.2855, by the corresponding oil test methods under §63.7(e)(2)(ii) and (f) seed solvent loss factor (gal/ton) listed and as defined in §63.90. in Table 1 of §63.2840, and by the (4) Approval of major alternatives to dimensionless constant 0.64, and sum monitoring under §63.8(f) and as de ming the result for all oilseed types fined in §63.90. processed. (5) Approval of major alternatives to Area source means any source that recordkeeping and reporting under does not meet the major source defini §63.10(f) and as defined in §63.90. tion. As received is the basis upon which all § 63.2872 What definitions apply to this oilseed measurements must be deter subpart? mined and refers to the oilseed chem Terms used in this subpart are de ical and physical characteristics as ini fined in the sources listed: tially received by the source and prior (a) The Clean Air Act, section 112(a). to any oilseed handling and processing.

371 §63.2872 40 CFR Ch. I (7-1-09 Edition)

Batch operation means any process separated from the other corn compo that operates in a manner where the nents using a "dry" process of mechan addition of raw material and with ical chafing and air sifting. drawal of product do not occur simul Corn germ wet milling means a source taneously. Typically, raw material is that processes corn germ that has been added to a process, operational steps separated from other corn components occur, and a product is removed from using a "wet" process of centrifuging a the process. More raw material is then slurry steeped in a dilute sulfurous added to the process and the cycle re acid solution. peats. Exempt period means a period of time Calendar month means 1 month as during which a source processes agri specified in a calendar. cultural products not defined as listed Compliance date means the date on oilseed. which monthly compliance record Extraction solvent means an organic keeping begins. For existing sources, chemical medium used to remove oil recordkeeping typically begins 3 years from an oilseed. Typically, the extrac after the effective date of the subpart. tion solvent is a commercial grade of For new and reconstructed sources, hexane isomers which have an approxi recordkeeping typically begins upon mate HAP content of 64 percent by vol initial startup, except as noted in ume. §63.2834. Hazardous air pollutant (HAP) means Compliance ratio means a ratio of the any substance or mixture of substances actual HAP loss in gallons from the listed as a hazardous air pollutant previous 12 operating months to an al under section 112(b) of the Clean Air lowable HAP loss in gallons, which is Act, as of April 12, 2001. determined by using oilseed solvent Initial startup date means the first loss factors in Table 1 of §63.2840, the calendar day that a new, reconstructed weighted average volume fraction of or significantly modified source proc HAP in solvent received for the pre esses any listed oilseed. vious 12 operating months, and the Initial startup period means a period tons of each type of listed oilseed proc of time from the initial startup date of essed in the previous 12 operating a new, reconstructed or significantly months. Months during which no listed modified source, for which you choose oilseed is processed, or months during to operate the source under an initial which the §63.2850(c)(2) or (d)(2) initial startup period subject to §63.2850(c)(2) startup period or the §63.2850(e)(2) mal or (d)(2). During an initial startup pe function period applies, are excluded riod, a source complies with the stand from this calculation. Equation 2 of ards by minimizing HAP emissions to §63.2840 is used to calculate this value. the extent practical. The initial start If the value is less than or equal to 1.00, up period following initial startup of a the source is in compliance. If the new or reconstructed source may not value is greater than 1.00, the source is exceed 6 calendar months. The initial deviating from compliance. startup period following a significant Continuous operation means any proc modification may not exceed 3 cal ess that adds raw material and with endar months. Solvent and oilseed in draws product simultaneously. Mass, ventory information recorded during temperature, concentration and other the initial startup period is excluded properties typically approach steady from use in any compliance ratio de state conditions. terminations. Conventional desolventizer means a Large cottonseed plant means a vege desolventizer toaster that operates table oil production process that proc with indirect and direct-contact steam esses 120,000 tons or more of cottonseed to remove solvent from the extracted and other listed oilseed during all nor meal. Oilseeds processed in a conven mal operating periods in a 12 operating tional desolventizer produce crude veg months period used to determine com etable oil and crude meal products, pliance. such as animal feed. Malfunction period means a period of Corn germ dry milling means a source time between the beginning and end of that processes corn germ that has been a process malfunction and the time 372 Environmental Protection Agency §63.2872 reasonably necessary for a source to operated under an initial startup pe correct the malfunction for which you riod as described in §63.2850(c)(2) or choose to operate the source under a (d)(2), or a malfunction period as de malfunction period subject to scribed in §63.2850(e)(2). An operating §63.2850(e)(2). This period may include month may include time intervals the duration of an unscheduled process characterized by several types of oper shutdown, continued operation during ating status. However, an operating a malfunction, or the subsequent proc month must have at least one normal ess startup after a shutdown resulting operating period. from a malfunction. During a malfunc Significant modification means the ad tion period, a source complies with the dition of new equipment or the modi standards by minimizing HAP emis fication of existing equipment that: sions to the extent practical. There (1) Significantly affects solvent fore, solvent and oilseed inventory in losses from your vegetable oil produc formation recorded during a malfunc tion process; tion period is excluded from use in any (2) The fixed capital cost of the new compliance ratio determinations. components represents a significant Mechanical extraction means remov percentage of the fixed capital cost of ing vegetable oil from oilseeds using building a comparable new vegetable only mechanical devices such as press oil production process; es or screws that physically force the (3) The fixed capital cost of the new oil from the oilseed. Mechanical ex equipment does not constitute recon traction techniques use no organic sol struction as defined in §63.2; and vents to remove oil from an oilseed. (4) Examples of significant modifica Nonoperating period means any period tions include replacement of or major of time in which a source processes no changes to solvent recovery equipment agricultural product. This operating such as extractors, desolventizer-toast status does not apply during any period ers/dryer-coolers, flash desolventizers, in which the source operates under an and distillation equipment associated initial startup period as described in with the mineral oil system, and equip §63.2850(c)(2) or (d)(2), or a malfunction ment affecting desolventizing effi period, as described in §63.2850(e)(2). ciency and steady-state operation of Normal operating period means any pe your vegetable oil production process riod of time in which a source proc such as flaking mills, oilseed heating esses a listed oilseed that is not cat and conditioning equipment, and egorized as an initial startup period as cracking mills. described in §63.2850(c)(2) or (d)(2), or a Small cottonseed plant means a vege malfunction period, as described in table oil production process that proc §63.2850(e)(2). At the beginning and end esses less than 120,000 tons of cotton ing dates of a normal operating period, seed and other listed oilseed during all solvent and oilseed inventory informa normal operating periods in a 12 oper tion is recorded and included in the ating months period used to determine compliance ratio determination. compliance. Oilseed or listed oilseed means the fol Solvent extraction means removing lowing agricultural products: corn vegetable oil from listed oilseed using germ, cottonseed, flax, peanut, an organic solvent in a direct-contact rapeseed (for example, canola), saf system. flower, soybean, and sunflower. Solvent working capacity means the Oilseed solvent loss factor means a volume of extraction solvent normally ratio expressed as gallons of solvent retained in solvent recovery equip loss per ton of oilseed processed. The ment. Examples include components solvent loss factors are presented in such as the solvent extractor. Table 1 of §63.2840 and are used to de desolventizer-toaster, solvent storage termine the allowable HAP loss. and working tanks, mineral oil absorp Operating month means any calendar tion system, condensers, and oil/sol or accounting month in which a source vent distillation system. processes any quantity of listed oil Specialty desolventizer means a seed, excluding any entire calendar or desolventizer that removes excess sol accounting month in which the source vent from soybean meal using vacuum

373 §63.2980 40 CFR Ch. I (7-1-09 Edition) conditions, energy from superheated pollutants (NESHAP) for emissions solvent vapors, or reduced operating from facilities that produce wet-formed conditions (e.g., temperature) as com fiberglass mat. This subpart also estab pared to the typical operation of a con lishes requirements to demonstrate ini ventional desolventizer. Soybeans tial and continuous compliance with processed in a specialty desolventizer the emission limitations. result in high-protein vegetable meal products for human and animal con § 63.2981 Does this subpart apply to sumption, such as calf milk replace me? ment products and meat extender prod You must comply with this subpart if ucts. you meet the criteria in paragraphs (a) Vegetable oil production process means and (b) of this section: the equipment comprising a continuous (a) You own or operate a drying and process for producing crude vegetable curing oven at a wet-formed fiberglass oil and meal products, including spe mat production facility. cialty soybean products. in which oil is (bl Your drying and curing oven or removed from listed oilseeds through the facility at which your drying and direct contact with an organic solvent. curing oven is located is a major source Process equipment typically includes of hazardous air pollutants (HAP). A the following components: oilseed prep major source is any stationary source aration operations (including condi or group of stationary sources located tioning, drying, dehulling, and crack within a contiguous area and under ing), solvent extractors, desolventizer common control that emits or can po toasters, meal dryers, meal coolers, tentially emit, considering controls, in meal conveyor systems, oil distillation the aggregate, 9.07 megagrams (10 tons) units, solvent evaporators and con or more per year of a single HAP or densers, solvent recovery system (also 22.68 megagrams (25 tons) or more per referred to as a mineral oil absorption year of any combination of HAP. system), vessels storing solvent-laden materials, and crude meal packaging § 63.2982 What parts of my plant does and storage vessels. A vegetable oil this subpart cover? production process does not include (a) This subpart applies to each new, vegetable oil refining operations (in reconstructed, or existing affected cluding operations such as bleaching, source. The affected source (the por hydrogenation, and deodorizing) and tion of your plant covered by this sub operations that engage in additional part) is each wet-formed fiberglass mat chemical treatment of crude soybean drying and curing oven. meals produced in specialty (b) An affected source is a new af desolventizer units (including oper fected source if you commenced con ations such as soybean isolate produc struction of the affected source after tion). May 26, 2000, and you meet the applica [66 FR 19011, Apr. 12. 2001, as amended at 71 bility criteria in § 63.2981 at start-up. FR 20464, Apr. 20. 2006] (c) An affected source is recon structed if you meet the criteria as de Subpart HHHH-National Emission fined in § 63.2. (d) An affected source is existing if it Standards for Hazardous Air is not new or reconstructed. Pollutants for Wet-Formed Fi berglass Mat Production EMISSION LIMITATIONS

§ 63.2983 What emission limits must I SOURCE: 67 FR 17835. Apr, 11. 2002. unless otherwise noted. meet? (a) You must limit the formaldehyde WHAT THIS SUBPART COVERS emissions from each drying and curing oven by either: § 63.2980 What is the purpose of this (1) Limiting emissions of formalde subpart? hyde to 0.03 kilograms or less per This subpart establishes national megagram (0.05 pounds per ton) of fi emission standards for hazardous air berglass mat produced; or 374 Appendix C

ADEQ Continuous Emission Monitoring Systems Conditions Arkansas Department of Environmental Quality

CONTINUOUS EMISSION MONITORING SYSTEMS CONDITIONS

Revised September 2013 PREAMBLE

These conditions are intended to outline the requirements for facilities required to operate Continuous Emission Monitoring Systems/Continuous Opacity Monitoring Systems (CEMS/COMS). Generally there are three types of sources required to operate CEMS/COMS:

1. CEMS/COMS required by 40 CFR Part 60 or 63, 2. CEMS required by 40 CFR Part 75, 3. CEMS/COMS required by ADEQ permit for reasons other than Part 60,63 or 75.

These CEMS/COMS conditions are not intended to supercede Part 60, 63 or 75 requirements.

• Only CEMS/COMS in the third category (those required by ADEQ permit for reasons other than Part 60, 63, or 75) shall comply with SECTION II, MONITORING REQUIREMENTS and SECTION IV, QUALITY ASSURANCE/QUALITY CONTROL.

• All CEMS/COMS shall comply with Section IlL NOTIFICATION AND RECORDKEEPING.

2 SECTION I

DEFINITIONS

Continuous Emission Monitoring System (CEMS) - The total equipment required for the determination ofa gas concentration and/or emission rate so as to include sampling, analysis and recording ofemission data.

Continuous Opacity Monitoring System (COMS) - The total equipment required for the determination ofopacity as to include sampling, analysis and recording ofemission data.

Calibration Drift (CD) - The difference in the CEMS output reading from the established reference value after a stated period ofoperation during which no unscheduled maintenance, repair, or adjustments took place.

Back-up CEMS (Secondary CEMS) - A CEMS with the ability to sample, analyze and record stack pollutant to determine gas concentration and/or emission rate. This CEMS is to serve as a back-up to the primary CEMS to minimize monitor downtime.

Excess Emissions - Any period in which the emissions exceed the permit limits.

Monitor Downtime - Any period during which the CEMS/COMS is unable to sample, analyze and record a minimum offour evenly spaced data points over an hour, except during one daily zero-span check during which two data points per hour are sufficient.

Out-of-Control Period - Begins with the time corresponding to the completion ofthe fifth, consecutive, daily CD check with a CD in excess oftwo times the allowable limit, or the time corresponding to the completion ofthe daily CD check preceding the daily CD check that results in a CD in excess offour times the allowable limit and the time corresponding to the completion ofthe sampling for the Relative Accuracy Test Audit (RATA), Relative Accuracy Audit (RAA), or Cylinder Gas Audit (CGA) which exceeds the limits outlined in Section IV. Out-of-Control Period ends with the time corresponding to the completion ofthe CD check following corrective action with the results being within the allowable CD limit or the completion ofthe sampling ofthe subsequent successful RATA, RAA, or CGA.

Primary CEMS - The main reporting CEMS with the ability to sample, analyze, and record stack pollutant to determine gas concentration and/or emission rate.

Relative Accuracy (RA) - The absolute mean difference between the gas concentration or emission rate determined by the CEMS and the value determined by the reference method plus the 2.5 percent error confidence coefficient ofa series oftests divided by the mean ofthe reference method tests ofthe applicable emission limit.

Span Value - The upper limit of a gas concentration measurement range.

3 SECTION II

MONITORING REQUIREMENTS

** Only CEMS/COMS required by ADEQ permit for reasons other than Part 60,63 or 75 shall comply with this section.

A. For new sources, the installation date for the CEMS/COMS shall be no later than thirty (30) days from the date of start-up ofthe source.

B. For existing sources, the installation date for the CEMS/COMS shall be no later than sixty (60) days from the issuance ofthe permit unless the permit requires a specific date.

C. Within sixty (60) days of installation of a CEMS/COMS, a performance specification test (PST) must be completed. PST's are defined in 40 CFR, Part 60, Appendix B, PS 1-9. The Department may accept alternate PST's for pollutants not covered by Appendix B on a case-by-case basis. Alternate PST's shall be approved, in writing, by the ADEQ CEM Coordinator prior to testing.

D. Each CEMS/COMS shall have, as a minimum, a daily zero-span check. The zero-span shall be adjusted whenever the 24-hour zero or 24-hour span drift exceeds two times the limits in the applicable performance specification in 40 CFR, Part 60, Appendix B. Before any adjustments are made to either the zero or span drifts measured at the 24-hour interval, the excess zero and span drifts measured mustbe quantified and recorded.

E. All CEMS/COMS shall be in continuous operation and shall meet minimum frequency of operation requirements of95% up-time for each quarter for each pollutant measured. Percent ofmonitor down-time is calculated by dividing the total minutes the monitor is not in operation by the total time in the calendar quarter and multiplying by one hundred. Failure to maintain operation time shall constitute a violation ofthe CEMS conditions.

F. Percent ofexcess emissions are calculated by dividing the total minutes ofexcess emissions by the total time the source operated and multiplying by one hundred. Failure to maintain compliance may constitute a violation ofthe CEMS conditions.

G. All CEMS measuring emissions shall complete a minimum ofone cycle ofoperation (sampling, analyzing, and data recording) for each successive fifteen minute period unless more cycles are required by the permit. For each CEMS, one-hour averages shall be computed from four or more data points equally spaced over each one hour period unless more data points are required by the permit.

H. All COMS shall complete a minimum ofone cycle ofsampling and analyzing for each successive 10-second period and one cycle ofdata recording for each successive 6-minute period.

I. When the pollutant from a single affected facility is released through more than one point, a CEMS/COMS shall be installed on each point unless installation of fewer systems is approved, in writing, by the ADEQ

4 CEM Coordinator. When more than one CEM/COM is used to monitor emissions from one affected facility the owner or operator shall report the results as required from each CEMS/COMS.

5 SECTION III

NOTIFICATION AND RECORD KEEPING

** All CEMS/COMS shall comply with this section.

A. When requested to do so by an owner or operator, the ADEQ CEM Coordinator will review plans for installation or modification for the purpose ofproviding technical advice to the owner or operator.

B. Each facility which operates a CEMS/COMS shall notify the ADEQ CEM Coordinator ofthe date for which the demonstration of the CEMS/COMS performance will commence (i.e. PST, RATA, RAA, CGA). Notification shall be received in writing no less than 15 business days prior to testing. Performance test results shall be submitted to the Department within thirty days after completion oftesting.

C. Each facility which operates a CEMS/COMS shall maintain records ofthe occurrence and duration ofstart up/shut down, cleaning/soot blowing, process problems, fuel problems, or other malfunction in the operation ofthe affected facility which causes excess emissions. This includes any malfunction ofthe air pollution control equipment or any period during which a continuous monitoring device/system is inoperative.

D. Each facility required to install a CEMS/COMS shall submit an excess emission and monitoring system performance report to the Department (Attention: Air Division, CEM Coordinator) at least quarterly, unless more frequent submittals are warranted to assess the compliance status ofthe facility. Quarterly reports shall be postmarked no later than the 30th day ofthe month following the end ofeach calendar quarter.

E. All excess emissions shall be reported in terms ofthe applicable standard. Each report shall be submitted on ADEQ Quarterly Excess Emission Report Forms. Alternate forms may be used with prior written approval from the Department.

F. Each facility which operates a CEMS/COMS must maintain on site a file ofCEMS/COMS data including all raw data, corrected and adjusted, repair logs, calibration checks, adjustments, and test audits. This file must be retained for a period ofat least five years, and is required to be maintained in such a condition that it can easily be audited by an inspector.

G. Quarterly reports shall be used by the Department to determine compliance with the permit.

6 SECTION IV

QUALITY ASSURANCE/QUALITY CONTROL

** Only CEMS/COMS required by ADEQ permit for reasons other than Part 60,63 or 75 shall comply with this section.

A. For each CEMS/COMS a Quality Assurance/Quality Control (QAlQC) plan shall be submitted to the Department (Attn.: Air Division, CEM Coordinator). CEMS quality assurance procedures are defined in 40 CFR, Part 60, Appendix F. This plan shall be submitted within 180 days ofthe CEMS/COMS installation. A QA/QC plan shall consist of procedure and practices which assures acceptable level of monitor data accuracy, precision, representativeness, and availability.

B. The submitted QA/QC plan for each CEMS/COMS shall not be considered as accepted until the facility receives a written notification ofacceptance from the Department.

C. Facilities responsible for one, or more, CEMS/COMS used for compliance monitoring shall meet these minimum requirements and are encouraged to develop and implement a more extensive QAlQC program, or to continue such programs where they already exist. Each QA/QC program must include written procedures which should describe in detail, complete, step-by-step procedures and operations for each ofthe following activities:

1. Calibration ofCEMS/COMS a. Daily calibrations (including the approximate time(s) that the daily zero and span drifts will be checked and the time required to perform these checks and return to stable operation) 2. Calibration drift determination and adjustment ofCEMS/COMS a. Out-of-control period determination b. Steps of corrective action 3. Preventive maintenance of CEMS/COMS a. CEMS/COMS information 1) Manufacture 2) Model number 3) Serial number b. Scheduled activities (check list) c. Spare part inventory 4. Data recording, calculations, and reporting 5. Accuracy audit procedures including sampling and analysis methods 6. Program ofcorrective action for malfunctioning CEMS/COMS

D. A Relative Accuracy Test Audit (RATA), shall be conducted at least once every four calendar quarters. A Relative Accuracy Audit (RAA), or a Cylinder Gas Audit (CGA), may be conducted in the other three

7 quarters but in no more than three quarters in succession. The RATA should be conducted in accordance with the applicable test procedure in 40 CFR Part 60 Appendix A and calculated in accordance with the applicable performance specification in 40 CFR Part 60 Appendix B. CGA's and RAA's should be conducted and the data calculated in accordance with the procedures outlined on 40 CFR Part 60 Appendix F. If alternative testing procedures or methods ofcalculation are to be used in the RATA, RAA or CGA audits prior authorization must be obtained from the ADEQ CEM Coordinator.

E. Criteria for excessive audit inaccuracy.

RATA All Pollutants > 20% Relative Accuracy except Carbon Monoxide Carbon Monoxide > 10% Relative Accuracy All Pollutants except Carbon > 10% ofthe Applicable Standard Monoxide Carbon Monoxide > 5% ofthe Applicable Standard Diluent (02& CO2) > 1.0 % 02 or CO2 Flow > 20% Relative Accuracy

eGA > 15% ofaverage audit value Pollutant or 5 ppm difference > 15% ofaverage audit value Diluent (02 & CO2) or 5 ppm difference

RAA > 15% ofthe three run Pollutant average or > 7.5 % ofthe applicable standard > 15% ofthe three run Diluent (02 & CO2) average or > 7.5 % ofthe applicable standard

8 F. Ifeither the zero or span drift results exceed two times the applicable drift specification in 40 CFR, Part 60, Appendix B for five consecutive, daily periods, the CEMS is out-of-control. Ifeither the zero or span drift results exceed four times the applicable drift specification in Appendix B during a calibration drift check, the CEMS is out-of-control. Ifthe CEMS exceeds the audit inaccuracies listed above, the CEMS is out-of-control. Ifa CEMS is out-of-control, the data from that out-of-control period is not counted towards meeting the minimum data availability as required and described in the applicable subpart. The end ofthe out-of-control period is the time corresponding to the completion ofthe successful daily zero or span drift or completion ofthe successful CGA, RAA or RATA.

G. A back-up monitor may be placed on an emission source to minimize monitor downtime. This back-up CEMS is subject to the same QAIQC procedure and practices as the primary CEMS. The back-up CEMS shall be certified by a PST. Daily zero-span checks must be performed and recorded in accordance with standard practices. When the primary CEMS goes down, the back-up CEMS may then be engaged to sample, analyze and record the emission source pollutant until repairs are made and the primary unit is placed back in service. Records must be maintained on site when the back-up CEMS is placed in service, these records shall include at a minimum the reason the primary CEMS is out ofservice, the date and time the primary CEMS was out ofservice and the date and time the primary CEMS was placed back in service.

9 CERTIFICATE OF SERVICE

I, Pam Owen, hereby certify that a copy ofthis permit has been mailed by first class mail to

Planters Cotton Oil Mill, Inc., 2901 Planters Drive, Pine Bluff, AR, 71601, on this CitY") day

Pam Owen, AAII, Air Division