RESPONSE TO COMMENTS PLANTERS COTTON OIL … · RESPONSE TO COMMENTS PLANTERS COTTON OIL MILL, ... control system for Planters Cotton Oil Mill, Incorporated to ... one ofthe five

RESPONSE TO COMMENTS

PLANTERS COTTON OIL MILL, INCORPORATEDPERMIT #1427-AOP-Rll

AFIN: 35-00025

On July 24, 2011, the Director of the Arkansas Department ofEnvironmental Quality gavenotice of a draft permitting decision for the above referenced facility. During the commentperiod, written comments on the draft permitting decision were submitted by ECCI, on behalf ofthe facility. The Department's response to these issues follows.

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

Comment #1: Shannon Lynn of ECCI electronically submitted a list of typographicalcorrections to the draft permit.

Response to Comment #1: All typographical corrections addressed in Mr. Lynn's email werecorrected in the final permit.

Comment #2: The facility routes emissions from SN-65 thru SN-7l to Rotary Drum Filter #3,SN-64. Please revise the permit to reflect this and remove Specific Conditions for SN-65 thruSN-71.

Response to Comment #2: The final permit has been revised to reflect that emissions from SN65 thru SN-7l are controlled by SN-64. Draft Specific Conditions 74 thru 77 have been deletedfrom the final permit.

Page 1 of 1

ADEQARK A N S A SDepartment of Environmental Quality

Septerr~er ?O, 2011

John JeffersonSenior Vice-PresidentPlanters Cotton Oil Mill, IncorporatedPO Box 7427Pine Bluff, AR 71611

Dear Mr. Jefferson:

The enclosed Permit No. 1427-AOP-R11 is your authority to construct, operate, and maintain theequipment and/or control apparatus as set forth in your application initially received on11/12/2009.

After considering the facts and requirements of A.C.A. §8-4-101 et seq., and implementingregulations, I have determined that Permit No. 1427-AOP-R11 for the construction, operationand maintenance of an air pollution control system for Planters Cotton Oil Mill, Incorporated tobe issued and effective on the date specified in the permit, unless a Commission review has beenproperly requested under Arkansas Department of Pollution Control & Ecology Commission'sAdministrative Procedures, Regulation 8, within thirty (30) days after service of this decision.

The applicant or permittee and any other person submitting public comments on the record mayrequest an adjudicatory hearing and Commission review of the final permitting decisions asprovided under Chapter Six of Regulation No.8, Administrative Procedures, Arkansas PollutionControl and Ecology Commission. Such a request shall be in the form and manner required byRegulation 8.603, including filing a written Request for Hearing with the APC&E CommissionSecretary at 101 E. Capitol Ave., Suite 205, Little Rock, Arkansas 72201. If you have anyquestions about filing the request, please call the Commission at 501-682-7890.

Sincerely,

luJ;~··-Mike BatesChief, Air Division

ARKANSAS DEPARTMENT OF ENVIRONMENTAL QUALITY5301 NORTHSHORE DRIVE / NORTH UTILE ROCK / ARKANSAS 72118-5317 / TELEPHONE 501-682-0744 / FAX501-682-0880

www.adeq.state.ar.us

ADEQOPERATINGAIR PERMIT

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

Permit No. : 1427-AOP-R11

IS ISSUED TO:

Planters Cotton Oil Mill, Incorporated2901 Planters Drive

Pine Bluff, AR 71601Jefferson CountyAFIN: 35-00025

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

Sent.ember '2J), /011 . AND

THE PERMITTEE IS SUBJECT TO ALL LIMITS AND CONDITIONS CONTAINEDHEREIN.

Signed:

11Ati~et~-Mike BatesChief, Air Division

5'~'1f), ~11

Date

Planters Cotton Oil Mill, IncorporatedPermit #: 1427-AOP-RllAFIN: 35-00025

Table of ContentsSECTION I: FACILITY INFORMATION 5SECTION II: INTRODUCTION 6

Summary of Permit Activity 6Process Description 6Regulations 8Emission Summary 10

SECTION III: PERMIT HISTORy 15SECTION IV: SPECIFIC CONDITIONS 20

SN-Ol 1st Cut Linter Machines 20SN-02, 03, & 04 2nd Cut Linter Machines 21SN-05 & 14 Salvage Reclaim 22SN-06-12 and 48-51 Lint Cleaners 23SN-13 Seed Cleaner 26SN-15 Recycling System 28SN-52 Recycling System 29SN-16 & 17 Bailing Presses 30SN-18 through 26 and 57 Seed Cleaners 31SN-27 and 28 Rock Traps #1 and #2 34SN-29 Stick and Burr Machine 36SN-30 Motes Beater/Pre-lint Cleaner 38SN-31 Decorticating/Separating 40SN-32, 42, 43,56, and 46 Solvent Extraction Plant 41SN-34 Dump Enclosure 45SN-35 Hammermill 46SN-36 Meal Loading Enclosure 48SN-37 Hull Loading Enclosure 49SN-38 Bulk Hull House 51SN-39 and 40 Sacked Hull Houses 53SN-44 and 45 Boilers #1 and #2 54SN-47 Bulk House Cooling Fans 56SN-55 and 61 Trash Beaters #1 and #2 59SN-58 (RFD-l) & SN-59 (RFD-2) Rotary Drum Filters #1 and #2 60SN-60 Portable Material Loading Units 62SN-62 Protein Shakers (Cyclone PS-l) 63SN-63 Trash Shaker Receiving 65SN-64 Rotary Drum Filter (RDF-3) 67SN-65 through SN-71 Hull Shaker Fans and Cascade Fans 69SN-72 Boiler #3 70SN-73 Black Cotton Seed Tank 73

SECTION V: COMPLIANCE PLAN AND SCHEDULE 75SECTION VI: PLANTWIDE CONDITIONS 76

Permit Shield 80Title VI Provisions 81

SECTION VII: INSIGNIFICANT ACTIVITIES 83

2


SECTION VIII: GENERAL PROVISIONS 84Appendix A: 40 CFR Part 60 Subpart DeAppendix B: 40 CFR Part 63 Subpart GGGGAppendix C: ADEQ Continuous Emission Monitoring Systems Conditions

3


List of Acronyms and Abbreviations

A.C.A.

AFIN

CFR

CO

HAP

lb/hr

MVAC

No.

NOx

PM

PM10

SNAP

S02

SSM

Tpy

UTM

VOC

Arkansas Code Annotated

ADEQ Facility Identification Number

Code of Federal Regulations

Carbon Monoxide

Hazardous Air Pollutant

Pound Per Hour

Motor Vehicle Air Conditioner

Number

Nitrogen Oxide

Particulate Matter

Particulate Matter Smaller Than Ten Microns

Significant New Alternatives Program (SNAP)

Sulfur Dioxide

Startup, Shutdown, and Malfunction Plan

Tons Per Year

Universal Transverse Mercator

Volatile Organic Compound

4


SECTION I: FACILITY INFORMATION

PERMITTEE: Planters Cotton Oil Mill, Incorporated

AFIN: 35-00025

PERMIT NUMBER: 1427-AOP-Rll

FACILITY ADDRESS: 2901 Planters DrivePine Bluff, AR 71601

MAILING ADDRESS: PO Box 7427Pine Bluff, AR 71611

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):

UTM East West (X):

Zone 15: 3787578.04 m

Zone 15: 592931.50 m

5

Planters Cotton Oil Mill, IncorporatedPermit #: 1427-AOP-Rl1AFIN: 35-00025

SECTION II: INTRODUCTION

Summary of Permit Activity

Planters Cotton Oil Mill (Planters) is located at 2901 Planters Drive in Pine Bluff, Arkansaswhere it currently produces vegetable oil from cottonseed separation and solvent extraction(NAICS 311223). This permit renewal included several revisions to emission limits based onupdated emission factors derived from similar source testing results at other facilities. Annualpermitted emission limits increased 14.8 tons ofS02, 5.1 tons ofVOC, 2.5 tons of CO, 1.8 tonsof Hexane while emissions limits decreased 66.3 tons of PM and 104 tons ofPMlO.

Process Description

Receiving and Storage:

The mill receives cottonseed by truck. Each truck is weighed and then sent to one of the seeddumps. At the seed dump, the trucks are elevated to a 45 degree angle. The cottonseed isreleased from the rear of the truck and dumped into receiving pits. There are receiving pits at theMain Facility (also referred to as the Active Mill), the Lower Mill on Michigan Street, and theOld Mill on East 5th Avenue across the railroad tracks.

Since pneumatic conveying could result in cottonseed damage, mechanical conveying is used totransfer the cottonseed from the receiving pits. A screw conveyor pushes the seed to the verticalelevators which transfer the seed to the elevated system of belt conveyors. The belt conveyorscarry seed either to one of the five feed storage houses or to the seed cleaning room forprocessing.

Cottonseed Cleaning:

Cottonseed is mechanically conveyed to the cleaning area where it is processed through seedcleaning units which remove leaves, twigs, pieces of bolls, or sand picked up in the fields or inhandling. Revolving screens, shaker screens, and pneumatic equipment are used for thispurpose. Lint and trash are collected by cyclones. After cleaning, the seed is conveyed to the lintroom.

Cottonseed Delinting and Lint Cleaning:

In the lint room, the delinting machines cut the short fibers off of the seeds. The lint is removedfrom the equipment 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 partsand other foreign materials 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 thencombined with the motes from the separation room and cleaned in the motes cleaner.

6


The partially delinted cottonseed from the 1st cut delinters is conveyed to the 2nd cut delinterswhere the remaining lint is removed. Cottonseed parts and other foreign materials that arecaught in the lint are cleaned by the second cut delinters. The lint from the 2nd cut delintersalong with recycle lint from the cleaners is cleaned in the 2nd cut linters. The clean 1st and 2ndcut lint is conveyed to the baling room and baled. Finished bales of lint are sent to storage forshipment. The shale, pepper, and trash stream from each lint cleaner and the motes cleaner arecombined and sent to hull storage. The lint once again goes to a beater and then to a balingpress.

Hulling and Separating:

After the cottonseed is delinted through the 2nd cut linters, the black seed is transferred to ablack seed storage tank for holding prior to processing. The black seed is then conveyed forprocessing to the safety shaker in the hulling and separating area. The safety shaker removesloose 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 thehuller room.

The huller and shaker cut the black seed open to release the meats. Meats are then directed to themeat stream. Hulls and uncut seed are sent to the hull and seed separator. Uncut seed isseparated out and recycled to the huller and shaker. Any remaining meat is separated from thehulls in the single-drum and double-drum beaters and the purifier. Meats from these threemachines 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 theyare flattened into flakes in order to improve oil extraction. Meats pass through a series of highspeed heavy cast iron rollers. The rolls reduce flakes to thin flakes. The flakes are then cookedin a cooker which is steam heated by a natural gas fired boiler. The cooker heats the flakes withadded 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 isextracted by percolating solvent through cottonseed meats. The extractor is operated under slightnegative pressure to aid in the feeding of meats and to prevent the escape of hexane vapors. Twostreams of solvent are produced. The first stream consists of solvent and oil. The secondconsists of meal saturated with solvent.

Solvent/Oil Separation:

After extraction, the miscella, a mixture of solvent and oil, is separated by distillation. Duringdistillation 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 furtherrefinement. The miscella is next treated in the miscella refinery where it is treated with a causticsolution such as sodium hydroxide. This action begins the separation of the heavy soaps from

7

Planters Cotton Oil Mill, IncorporatedPermit #: 1427-AOP-R11AFIN: 35-00025

the light oil. The heavy soaps are removed from the miscella by centrifuge. At this point, themiscella is processed through the second stage evaporator and then the oil stripper whichremoves the remaining hexane. The refinery is hermetically sealed and the solvent vapors areprocessed through the condenser vent scrubber system. Centrifuge seal water and backwash aretreated in a separate sump before treatment in the main sump. The oil, now stripped of hexane,is pumped to a cooler to remove heat and moisture, and is then pumped to finished tanks prior toshipment.

Solvent/Meal 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 theDesolventizer/Toaster unit where steam is used to vaporize and strip out occluded solvent fromthe meal. The meal is transported to the storage tanks by a cyclone meal cooler unit which coolsthe meal as it is transported.

Hexane Recovery and Control:

The hexane laden vapors from the distillation system are collected, condensed, and sent to asolvent water separator. This cooled condensate containing recovered solvent and solvent vaporsis separated into solvent and water phases by gravity. The solvent layer is returned to solventstorage for re-use. The water layer is sent through a wastewater evaporator to recover heatenergy and is then clarified in the main sump. The hexane remaining in the exhaust gas from thecondensers is controlled with a mineral oil scrubbing system. Mineral oil is first used to removehexane from the exhaust gases prior to release to the atmosphere. The solvent laden mineral oilis stripped of solvent by steam in the stripping column. The solvent vapors are recycled to thesolvent 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 inbulk. Planters incorporates the use of four (4) portable conveyors to load hulls, meal and seed totruck for shipment or processing.

Regulations

The following table contains the regulations applicable to this permit.

RegulationsArkansas Air Pollution Control Code, Regulation 18, effective June 18,2010Regulations ofthe Arkansas Plan ofImplementation for Air Pollution Control,Regulation 19, effective July 18,2009Regulations ofthe Arkansas Operating Air Permit Program, Regulation 26, effectiveJanuary 25, 2009

8


Regulations40 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 AirPollutants (NESHAP) for Solvent Extractionfor Vegetable Oil Production. Applicable toSN-32, 42,43, 56, and 46.40 CFR Part 63 Subpart DDDDD, - National Emission Standards for Hazardous AirPollutants (NESHAP) for Industrial, Commercial, and Institutional Boilers and ProcessHeaters. Applicable to SN-72.

9


Emission Summary

The following table is a summary of emissions from the facility. This table, in itself, is not anenforceable condition of the permit.

EMISSION SUMMARYSource

Description PollutantEmission Rates

Number lb/hr tpyPM lO 13.3 53.4S02 4.2 17.8

Total Allowable Criteria Pollutant VOC 132.7 502.9Emissions CO 20.6 89.9

NOx 10.3 45.1Lead 0.021 0.087PM 49.1 205.3

Hexane* 91.93 347.0

Total Allowable Non- CriteriaHCl 0.50 2.20

Pollutant EmissionsMercury* 7.6E-04 3.8E-04Arsenic* 1.3E-03 5.2E-03

Beryllium* 1.9E-04 8.2E-04Cadmium* 1.4E-03 5.8E-03

Manganese* 0.40 1.80

011st Cut Linter Machines

(Cyclone A-I)

022M Cut Linter Machines

(Cyclone A-2)2"d Cut Linter Machines Emissions routed to SN-64, Rotary Drum Filter #3.

03 (Cyclone A-3)

042"0 Cut Linter Machines

(Cyclone A-4)

05Salvage Reclaim

Emissions routed to SN-64, Rotary Drum Filter #3.(Cyclone B)

6Lint Cleaner PM 0.6 2.4

(Cyclone C-1) PM10 0.1 0.5


(Cyclone C-2) PM10 0.1 0.5


(Cyclone C-3) PM lO 0.1 0.5


(Cyclone C-4) PM10 0.1 0.5


(Cyclone C-5) PM10 0.1 0.5



10




Number lb/hr tpy



13Seed Cleaner PM 1.6 6.8

(Cyclone SC-11) PM 10 0.1 0.2

15Recycling System

Emissions routed to SN-64, Rotary Drum Filter #3(Cyclone E-2)

16Bailing Presses

Emissions routed to SN-59, Rotary Drum Filter #2(Cyclone F-1)

17Bailing Presses

Emissions routed to SN-59, Rotary Drum Filter #2(Cyclones F-2 & F-3)


(Cyclone SC-1) PMlO 0.1 0.2


(Cyclone SC-2) PM lO 0.1 0.2




(Cyclone SC-4) PM 10 0.1 0.2


(Cyclone SC-5) PM 10 0.1 0.2


(Cyclone SC-6) PM 10 0.1 0.2




(Cyclone SC-8) PM lO 0.1 0.2



27Rock Trap 1 PM 0.7 2.8

(Cyclone RTC-1) PM 10 0.7 2.8

28Rock Trap 2 PM 0.9 3.8

(Cyclone RTC-2) PMlO 0.9 3.8

29Stick & Burr Machine PM 0.9 3.6

(Cyclone MFC-1) PMlO 0.4 1.5Motes Beater/Pre-lint

PM 0.9 3.630 Cleaner

(Cyclone HC-13)PM 10 0.4 1.5

Decorticating/Separating31 Machines Emissions routed to SN-64, Rotary Drum Filter #3

(Cyclones H-1 thru H-5)

11




Number lb/hr tpy

32Solvent Plant MOS Vent VOC 41.0 156.0(90% Control Efficiency) Hexane 28.90 109.20

34 Dump Enclosure Emissions routed to SN-59, Rotary Drum Filter #2

35Hammermill PM 1.6 6.8

(Cyclone HM-18) PM10 0.7 2.7

36Meal Loading Enclosure

Emissions routed to SN-58, Rotary Drum Filter #1(Cyclone 19)

37Hull Loading Enclosure PM 0.1 0.2

(Cyclone 20) PM10 0.1 0.1

38Bulk Hull House PM 1.1 4.1(Cyclone H-21) PMlO 0.4 1.4

39Sacked Hull House

Emissions routed to SN-S8, Rotary Drum Filter #1(Cyclone H-22)

40Sacked Hull House

Emissions routed to SN-S8, Rotary Drum Filter #1(Cyclone H-23)

PM 0.3 1.0

42Dryer/Cooler Area PM10 0.1 0.4(Cyclone DC-26) VOC 7.5 28.3

Hexane S.30 19.80PM 0.3 1.0

43Dryer/Cooler Area PM10 0.1 0.4(Cyclone DC-25) VOC 7.5 28.3

Hexane S.30 19.80PM 0.2 0.7

PM 10 0.2 0.7S02 0.1 0.1

VOC 0.2 O.SCO 1.8 7.7

Boiler #1 NOx 2.1 9.244

(20.92 MMBTU/hr) Lead 1.1E-S 4.6E-5Arsenic 4.2E-6 1.9E-S

Beryllium 2.6E-7 1.IE-6Cadmium 2.3E-S 1.0E-4Hexane 0.04 0.20

Manganese 8.0E-6 3.SE-SMercury S.4E-6 2.4E-S

12



Description Emission RatesNumber Pollutant

lb/hr tpyPM 0.2 0.7

PMIO 0.2 0.7S0 2 0.1 0.1

VOC 0.2 0.5CO 1.8 7.7

Boiler #2 NOx 2.1 9.245

(20.92 MMBTU/hr)Lead 1.1E-5 4.6E-5

Arsenic 4.2E-6 1.9E-5Beryllium 2.6E-7 1.1E-6Cadmium 2.3E-5 1.0E-4Hexane 0.04 0.20

Manganese 8.0E-6 3.5E-5Mercury 5.4E-6 2.4E-5

46Solvent Plant Hexane VOC 67.2 254.0

Fugitive Losses Hexane 47.0 177.8

47 Bulk Cooling FansPM 6.9 30.0

PM 10 2.4 10.6


(Cyclone C-8) PMIO 0.1 0.5


(Cyclone C-9) PM 10 0.1 0.5


(Cyclone C-13) PM 10 0.1 0.5


(Cyclone C-13) PM 10 0.1 0.5

52Recycling System

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

56Dryer/Cooler Area PMIO 0.1 0.4(Cyclone DC-25) VOC 7.5 28.3

Hexane 5.30 19.80


(Cyclone SC-l 0) PM IO 0.1 0.2

58 Drum Filter (RDF-l)PM 1.2 5.1

PM 10 0.5 2.1

59 Drum Filter (RDF-2)PM 0.9 4.0

PM 10 0.4 1.6

13




Number lblhr tpyTrash Beater #2,

61 Lint & Motes Emissions routed to SN-64, Rotary Drum Filter #3(Cyclone B-2)

62Protein Shakers PM 0.9 3.8(Cyclone PS-1) PM 10 0.1 0.5

63Trash Shaker Receiving PM 004 1.7

(Cyclone C-9) PM 10 0.1 0.5

64Rotary Drum Filter PM 3.1 13.6

(RDF-3) PM IO 1.3 5.5

65Hull Shaker Fan #1

(Cyclone)

66Hull Shaker Fan #2

(Cyclone)

67Air Cascade Fan #1

(Cyclone)


Emissions routed to SN-64, Rotary Drum Filter #3(Cyclone)


(Cyclone)


(Cyclone)


(Cyclone)PM 1.9 804

PM 10 1.9 804S02 4.0 17.6

VOC 1.6 7.0CO 17.0 74.5

NOx 6.1 26.7

72 Boiler # 3 Lead 0.02 0.086(25.0 MMBTUIhr) Arsenic 1.20E-03 0.0051

Beryllium 1.90E-04 0.00081Cadmium 1.30E-03 0.0056Hexane 0.05 0.20

HCl 0.50 2.20Manganese 0040 1.80

Mercury 7.5E-4 0.00033

73 Black Cotton Seed Tank PM 0.1 0.2PM 10 0.1 0.1

14

Planters Cotton Oil Mill, IncorporatedPermit #: l427-AOP-RllAFIN: 35-00025

SECTION III: PERMIT HISTORY

Permit #178-A was issued to Cook Industries, Inc., in 1973 to bring the facility into fullcompliance with the provisions of the Air Code. In this permit, the facility installed a bag typecollector to control emissions generated during transfer of cottonseed to storage and installed onebag type collector on the aspiration system to control emissions generated during hull and mealloading. Five medium efficiency cyclones were installed to replace several low efficiencycyclones controlling emissions from the beater rooms. Operating procedures were established tominimize emissions generated during operation of the pneumatic unloading system.

Permit #178-AR-1 was issued on April 26, 1988, in order to change the ownership of CookIndustries ofPine Bluff to Planters Cotton Oil Mill, Inc. The facility was permitted for 3.9 tpy ofNOx from the gas boiler and 1.4 tpy ofVOC from the hexane plant. Particulate matter emissionswere 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 209tpy of PM, 7 tpy ofNOx, and 225 tpy ofVOC.

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

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

Permit #1427-AR-1 was issued July 11, 1996, to decrease the net emission limit of particulatematter from 247.5 tpy to 190.0 tpy based on testing. The SIC code for the facility was alsocorrected. In addition, the VOC limit was changed to 107.1 tpy to account for the 105.7 tpy ofhexane that is emitted from the facility.

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

Permit #1427-AOP-R1 was issued February 3, 2000. This was the initial modification to theTitle V air permit for this facility. This modification was issued in order to account foremissions increases from the installation of new equipment at the facility as well as to accountfor the reassignment of some of the equipment already present at the facility. The newequipment added in this modification consisted of a new cyclone added to the seed cleaningprocess, two new decorticating/separating machines, and four new lint cleaners. The bran andpepper cyclone was omitted from the initial permit application, but was added with thismodification. This modification resulted in an increase of 18.0 tpy ofPMlPMlO emissions.

15


Pennit #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 of a drum filter for the purposeof reducing 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 ina reduction of permitted particulate matter emissions of 10.3 tons per year (tpy).

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

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

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

1. Convert 3rd cut linter machines into 2nd cut linter machines and upgrade cyclones SN-Ol,02,03 and 04. This improved the quality ofthe finished product and it made the cyclonesmore efficient.

2. Replaced the current lint & mote beater with a new hi cell top cellulose section (SN-30) andthis increased cleaning efficiency.

3. Divide the trash reclaiming load between the lint, bran & pepper in order to reduce the loadand 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 reclaimermachine 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% of the existingload.

Trash Beater #2 (SN-61) Lint & Motes will take approximately 62% of the 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, IncorporatedPermit #: 1427-AOP-RIIAFIN: 35-00025

On January 15,2004 the Department issued a letter of acceptance for a Title V MinorModification to Permit #1427-AOP-R5 which proposed the installation of a new rotary drumfilter, designated as SN-64. This minor modification included the routing of emissions fromseveral existing cyclones to SN-64. The minor modification to Permit # 1427-AOP-R5 wasnot 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 OperatingAir Permit for this facility. This modification was issued after the Title V Operating Permitrenewal application was submitted (December 22, 2003). It was issued for the replacement of anexisting hot water boiler (SN-44) which blew up in October 2002 and an overhaul of existingboiler SN-45. A temporary boiler was taken out of service and removed from the site.

The modification included the installation of two (2) Protein Shakers with one (1) 54" cyclone,in the Separation Department, designated as SN-62. This minor modification was for theremoval of larger fiber particles and any remaining hulls from the meat stream, and will helpmaintain a high protein content, and will improve the equality of the fmished meal product. Theexcess hulls and larger fibers removed from the meat will be mixed back into the finished hullproduct.

The increase in emissions for the proposed modifications is: PM @ 7.6 tpy, PM lO @ 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 changesin this permit renewal with modifications:

A Rotary Drum Filter (RDF-3), designated as SN-64, was installed in November 2004. Overallpotential emissions of particulate matter (PM) and PM less than or equal to ten microns indiameter (PMlO) will decrease as a result of this change. The emissions from the followingexisting cyclones were re-routed to SN-64: SN-Ol through SN-05, SN-14, SN-15, SN-31, SN55, 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 updateis based on data from a study on cyclone emissions at cotton ginning facilities [Journal of CottonScience 4:178-182 (2000)]. Although the study was not performed for cottonseed processingplants, the data was considered to be representative of cyclone 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 beingpermitted: Mitchell Belt Feeder Cyclone (SN-29) and Hammermill Cyclone (SN-35).

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

17


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

Two (2) sources have been reclassified and are now included in the permit as insignificantactivities: 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 basedupon the most recent data published in AP-42 for natural gas combustion.

The previous permit limit of 300,000 tons of cottonseed processed per year was increased to350,000 tons per year. Cyclones and drum filters are being permitted to operate on a continuousbasis. The annual hexane solvent replacement limits will continue to be verified via massbalance and associated recordkeeping. The permit limit for Hexane solvent make-up has beenraised 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 amodification primarily to install a boiler which would combust solid fuels.

The only actual increases in emissions from the facility were due to the construction of Boiler #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 MMBtulhr, 500HP shop assembled package water tube boiler to be designated as SN-72 which combusted solidfuel such as cotton seed hulls or cellulose fiber/polypropylene plastic mix {Balcone's RefuseDerived Fuel (RDF)} that is composed ofwaste materials resulting from Kimberly Clark'smanufacturing operations. The RDF was provided in cube form from Balcones of Little Rock.SN-72 was subject to the MACT rules for boilers, 40 CFR 63, Subpart DDDDD. This boilerinstallation resulted in an increase in permitted emissions.

Planters was a major source of HAP emissions, namely hexane, and as such this boiler will besubject to 40 CFR 63, Subpart DDDDD; National Emission Standards for Hazardous AirPollutants (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 tomeet the following emission requirements:

0.025 lbs PMlMMBtu or 0.0003 lbs TSMlMMBtu0.02 lbs HCl/MMBtu0.000003 lbs Hg/MMBtu400 ppm CO by volumeOpacity was limited to a maximum of 10%

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

18


were in compliance with chloride and mercury but failed for TSM. Therefore, Planters installedan electrostatic precipitator (ESP) to meet the TSM limit.

The emissions from the Protein Shaker (SN-62) cyclone and the Trash Shaker Receiving (SN63) cyclone were not routed to Rotary Drum Filter #3 (SN-64) when it was installed under theprevious permit in 2004. These cyclones emitted directly to atmosphere. The increase inpermitted emissions from these sources was 8.7 tpy PMlO and 21.0 tpy PM.

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

SN-65 thru SN-71 (Hull Shaker Fans and Cascade Fans) were not previously permitted andexisted prior to the installation of (SN-64). These sources were routed into SN-64 upon itsconstruction in 2004.

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

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

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

19


SECTION IV: SPECIFIC CONDITIONS

SN-Ol1st Cut Linter Machines

Source Description

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

20


SN-02, 03, & 042nd 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 arerouted to Rotary Drum Filter #3, SN-64. Therefore, SN-02, 03 and 04 are no longer emissionpoints.

21


SN-05 & 14Salvage Reclaim

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

22


SN-06-12 and 48-51Lint Cleaners

Source Description

Sources 06 through 12 are lint cleaners that were installed in 1993. Emissions are controlled byCyclones C-1 through C-7. In 1999 four additional lint cleaners with accompanying cyclones(C-10, C-11, C-12, and C-13) were installed in order to treat lint emissions from various pointsaround the plant. Cleaners SN-49 and SN-50 were installed to handle the effluent from SN-03and SN-02 respectively. Cleaners SN-48 and SN-51 were installed to handle the effluent fromthe salvage reclaim operations.

Specific Conditions

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

SN Description Pollutant lb/hr tpy

06Lint Cleaner

PMlO 0.1 0.5(Cyclone C-1)

07Lint Cleaner

PM 10 0.1 0.5(Cyclone C-2)

08Lint Cleaner


09Lint Cleaner


10Lint Cleaner

PM 10 0.1 0.5(Cyclone C-5)

11Lint Cleaner


12Lint Cleaner


48Lint Cleaner


49Lint Cleaner


50Lint Cleaner

PM 10 0.1 0.5(Cyclone C-13)

51Lint Cleaner

PM10 0.1 0.5(Cyclone C-13)

23


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


06Lint Cleaner

PM 0.6 2.4(Cyclone C-l)

07Lint Cleaner

PM 0.6 2.4(Cyclone C-2)

08Lint Cleaner


09Lint Cleaner


10Lint Cleaner


11Lint Cleaner


12Lint Cleaner


48Lint Cleaner


49Lint Cleaner


50Lint Cleaner


51Lint Cleaner


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

SN Limit Regulatory Citation06-12 &

5% §18.50148-51

4. Weekly observations of the opacity from these sources shall be conducted by personnelfamiliar with the permittee's visible emissions. The pennittee shall maintain personneltrained in EPA Reference Method 9. If visible emissions which appear to be in excess ofthe permitted opacity are detected, the permittee shall immediately take action to identifythe cause of the visible emissions, implement corrective action, and document that visibleemissions did not appear to be in excess of the permitted opacity following the correctiveaction. The permittee shall maintain records which contain the following items in orderto demonstrate compliance with this specific condition. These records shall be updated

24


weekly, kept on site, and made available to Department personnel upon request.

a. The date and time of the observation;

b. If visible emissions which appeared to be above the permitted limit were detected;

c. The cause of the exceedance of the opacity limit;

d. The corrective action taken;

e. If the visible emissions appeared to be below the permitted limit after thecorrective action was taken; and

f. The name of the 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, and40 CFR 70.6]

25


SN-13Seed Cleaner

Source Description

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

Specific Conditions

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

SN Description Pollutant lb/hr tpy13 Seed Cleaner PMlO 0.1 0.2

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

SN Description Pollutant lb/hr tpy13 Seed Cleaner PM 1.6 6.8

7. Visible emissions may not exceed the limits specified in the following table of this permitas measured by EPA Reference Method 9.

SN Limit Regulatory Citation13 10% §18.801

8. Weekly observations of the opacity from SN-13 shall be conducted by personnel familiarwith the permittee's visible emissions. The permittee shall maintain personnel trained inEPA Reference Method 9. If visible emissions which appear to be in excess of thepermitted opacity are detected, the permittee shall immediately take action to identify thecause of the visible emissions, implement corrective action, and document that visibleemissions did not appear to be in excess of the permitted opacity following the correctiveaction. The permittee shall maintain records which contain the following items in orderto demonstrate compliance with this specific condition. These records shall be updatedweekly, kept on site, and made available to Department personnel upon request.

26








[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


SN-15Recycling System

Source Description

In the recycling system, motes from the lint cleaners are processed through Cyclones E-2 and B2. The collected material is sent back to the delinters to have the lint removed. Emissions fromthis cyclone are routed to Rotary Drum Filter #3, SN-64. Therefore, SN-15 is no longer anemission point.

28


SN-52Recycling System

Source Description

In the recycling system, motes from the lint cleaners are processed through Cyclone B-2. Thecollected material is sent back to the delinters to have the lint removed. SN-52 was installed in1999. Emissions from this cyclone are routed to Rotary Drum Filter #3, SN-64. Therefore, SN52 is no longer emission point.

29


SN-16 & 17Bailing Presses

Source Description

Two bailing presses are used to bale the lint from the cottonseed. The two bailing press cyclonesystems were replaced with two high efficiency cyclones with fans rated at 6,500 cubic feet perminute (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


SN-18 through 26 and 57Seed 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 installedin 1993 and SN-57 was installed in 1999.

Specific Conditions

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


18Seed Cleaner

PM10 0.1 0.2(Cyclone SC-1)

19Seed Cleaner

PMlO 0.1 0.2(Cyclone SC-2)

20Seed Cleaner

PM 10 0.1 0.2(Cyclone SC-3)

21Seed Cleaner

PM lO 0.1 0.2(Cyclone SC-4)

22Seed Cleaner


23Seed Cleaner

PM lO 0.1 0.2(Cyclone SC-6)

24Seed Cleaner PM lO 0.1 0.2

(Cyclone SC-7)

25Seed Cleaner


26Seed Cleaner PM lO 0.1 0.2

(Cyclone SC-9)

57Seed Cleaner

PMlO 0.1 0.2(Cyclone SC-10)


31



18Seed Cleaner

PM 1.8 7.6(Cyclone SC-l)

19Seed Cleaner

PM 1.8 7.6(Cyclone SC-2)

20Seed Cleaner


21Seed Cleaner


22Seed Cleaner


23Seed Cleaner


24Seed Cleaner


25Seed Cleaner


26Seed Cleaner


57Seed Cleaner

PM 1.8 7.6(Cyclone SC-l 0)


SN Limit Regulatory Citation18-26, &

5% §18.50157

12. Weekly observations ofthe opacity from SN-18 through 26 and 57 shall be conducted bypersonnel familiar with the permittee's visible emissions. The permittee shall maintainpersonnel trained in EPA Reference Method 9. If visible emissions which appear to be inexcess of the permitted opacity are detected, the permittee shall immediately take actionto identify the cause of the visible emissions, implement corrective action, and documentthat visible emissions did not appear to be in excess of the permitted opacity followingthe corrective action. The permittee shall maintain records which contain the followingitems in order to demonstrate compliance with this specific condition. These recordsshall be updated weekly, kept on site, and made available to Department personnel uponrequest.




32






33


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

Source Description

Rock traps #1 and #2 are used to remove some of the heavier trash from the cottonseed. Theywere both installed in 1993. Emissions are controlled by Cyclones RTC-1 and RTC-2.Particulate matter emissions are based on stack tests for both SN-27 and SN-28. SN-27 wasstack tested in December of 2003 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. Thepermittee shall demonstrate compliance with this condition by compliance with PlantWide Conditions 7, 8, and 9. [Regulation 19, §19.501 et seq. and 40 CFR Part 52,Subpart E]

SN Description Pollutant lb/hr tpy27 Rock Trap #1 PM lO 0.7 2.828 Rock Trap #2 PM lO 0.9 3.8


SN Description Pollutant lb/hr tpy27 Rock Trap #1 PM 0.7 2.828 Rock Trap #2 PM 0.9 3.8


SN Limit Regulatory Citation27 5% §18.50l28 5% §18.501

16. Weekly observations of the opacity from SN-27 and SN-28 shall be conducted bypersonnel familiar with the permittee's visible emissions. The permittee shall maintainpersonnel trained in EPA Reference Method 9. If visible emissions which appear to be inexcess of the permitted opacity are detected, the permittee shall immediately take actionto identify the cause of the visible emissions, implement corrective action, and documentthat visible emissions did not appear to be in excess of the permitted opacity followingthe corrective action. The permittee shall maintain records which contain the following

34


items in order to demonstrate compliance with this specific condition. These recordsshall be updated weekly, kept on site, and made available to Department personnel uponrequest.







[Regulation 19, §19.705, A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-31I , and40 CFR 70.6]

35


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

Source Description

The Stick and Burr Machine previously called the Mitchell Belt Feeder is used to transportmaterial collected from Cyclone MFC-l in the seed cleanirig process. The unit was installed in1993. The cyclone is rated at 2,400 cfm. SN-29 was tested on June 14,2005.

Specific Conditions



29 Stick & Burr Machine PMIO 0.4 1.5 '

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


29 Stick & Burr Machine PM 0.9 3.6

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

SN Limit Regulatory Citation

29 10% §18.501

20. Weekly observations of the opacity from SN-29 shall be conducted by personnel familiarwith the permittee's visible emissions. The permittee shall maintain personnel trained inEPA Reference Method 9. If visible emissions which appear to be in excess of thepermitted opacity are detected, the permittee shall immediately take action to identify thecause of the visible emissions, implement corrective action, and document that visibleemissions did not appear to be in excess of the permitted opacity following the correctiveaction. The permittee shall maintain records which contain the following items in orderto demonstrate compliance with this specific condition. These records shall be updated

36










37


SN-30Motes BeaterlPre-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 wasreplaced with a new Hi-Cell Top Cellulose Section in April of2003. The installation of the HiCell Top Cellulose Section increased cleaning efficiency. Emissions are controlled by CycloneHC-13, which is rated at 2,400 cfm. SN-30 was tested on June 13,2005.

Specific Conditions



30 Motes BeaterlPre-lint Cleaner PMlO 0.4 1.5


SN Description Pollutant lb/hr tpy30 Motes BeaterlPre-lint Cleaner PM 0.9 3.6



24. Weekly observations of the opacity from SN-30 shall be conducted by personnel familiarwith the permittee's visible emissions. The permittee shall maintain personnel trained inEPA Reference Method 9. If visible emissions which appear to be in excess of thepermitted opacity are detected, the permittee shall immediately take action to identify thecause of the visible emissions, implement corrective action, and document that visibleemissions did not appear to be in excess of the permitted opacity following the correctiveaction. The permittee shall maintain records which contain the following items in orderto demonstrate compliance with this specific condition. These records shall be updated

38










39


SN-31Decorticating/Separating

Source Description

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

40


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

Source Description

SN-32 is the emission source of the solvent plant mineral oil scrubber main vent (MaS).SN-42, SN-43, and SN-56 are the emissions of the dryer/cooler area cyclones. SN-56 wasadded in 1999 to assist in the dryer/cooler area. The emissions from SN-46 are fugitive nonpoint source emissions from the solvent extraction plant area. Also included at this site aretwo 10,000 gallon horizontal hexane tanks. These tanks are vented back into the solventrecovery/mineral oil system and are not vented to the atmosphere. These sources wereinstalled 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. Thepermittee shall demonstrate compliance with this condition by compliance with SpecificConditions 31, 33, and 35. [Regulation 19, §19.501 et seq. and 40 CFR Part 52, SubpartE]

SN Description Pollutant lblhr tpy

32Solvent Plant Mineral Oil

VOC 41.0 156.0Scrubber (MaS) Main Vent

42 Dryer/Cooler AreaVOC 7.5 28.3

(Cyclone DC-26)

43Dryer/Cooler Area

VOC 7.5 28.3(Cyclone DC-25)

46 Solvent Plant - Fugitive Losses VOC 67.2 254.0

56Dryer/Cooler Area

VOC 7.5 28.3(Cyclone DC-27)

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

SN Description Pollutant lblhr tpy

42Dryer/Cooler Area

PM lO 0.1 0.4(Cyclone DC-26)

43Dryer/Cooler Area

PM10 0.1 0.4(Cyclone DC-25)

41



56Dryer/Cooler Area

PMlO 0.1 0.4(Cyclone DC-27)

27. The permittee shall not exceed the emission rates set forth in the following table. Thepermittee shall demonstrate compliance with this condition by compliance with SpecificCondition 33. [Regulation 18, §18.801 and A.C.A. §8-4-203 as referenced by A.C.A. §84-304 and §8-4-311]


42Dryer/Cooler Area

PM 0.3 1.0(Cyclone DC-26)

43Dryer/Cooler Area


56Dryer/Cooler Area


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


32Solvent Plant Mineral Oil Scrubber

n-Hexane 28.9 109.2(MaS) Main Vent

42Dryer/Cooler Area

n-Hexane 5.3 19.8(Cyclone DC-26)

43Dryer/Cooler Area


46 Solvent Plant - Fugitive Losses n-Hexane 47.0 177.8

56Dryer/Cooler Area



SN Limit Regulatory Citation32 5% §18.50142 5% §18.50143 5% §18.50156 5% §18.501

42


30. Weekly observations of the opacity from SN-32, SN-42, SN-43, and SN-56 shall beconducted by personnel familiar with the permittee's visible emissions. The permitteeshall maintain personnel trained in EPA Reference Method 9. If visible emissions whichappear to be in excess of the permitted opacity are detected, the permittee shallimmediately take action to identify the cause of the visible emissions, implementcorrective action, and document that visible emissions did not appear to be in excess ofthe permitted opacity following the corrective action. The permittee shall maintainrecords which contain the following items in order to demonstrate compliance with thisspecific condition. These records shall be updated weekly, kept on site, and madeavailable to Department personnel upon request.






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, and40 CFR 70.6]

31. The facility may only use those Hexane solvents that shall not cause the VOC and HAPemission limits set forth in Specific Conditions 25 and 28 to be exceeded. The facilityshall use only those Hexane solvents that have a NormalHexane content equal to or lessthan 3.955 pounds per gallon during any consecutive 12-month operating period. Theother Hexane isomers shall be limited to 1.691 pounds per gallon. There shall be no otherHAPs used. Compliance shall be demonstrated through compliance with record keepingrequirements set forth in Specific Condition 32 and as set forth in Plant Wide Conditions10 through 22. [Regulation 19, §19.705, Regulation 18, §18.l004, and A.C.A §8-4-203as referenced by §8-4-304 and §8-4-311]

32. Records demonstrating compliance with Specific Condition 31 shall be maintained on atwelve-month rolling total basis, updated monthly, kept on site and made available to theDepartment upon request. The permittee shall submit a semi-annual report includingHexane make-up as set forth in General Provision 7. [Regulation 19, §19.705,Regulation No. 18 §18.l004, 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 of Hexane solvent that shall not cause the VOC and HAP emissionlimits set forth in Specific Conditions 25 and 28 to be exceeded, shall be limited to175,000 gallons per consecutive twelve month period. Compliance shall be demonstratedthrough 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


34. Records demonstrating compliance with Specific Condition 33 shall be maintained on atwelve-month rolling total basis, updated monthly, kept on site and made available to theDepartment upon request. The permittee shall submit a semi-annual report on Hexanemake-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 Part52, Subpart E]

35. The mineral oil plant shall not be operated without the mineral oil absorber in use.[Regulation 18, §18.1 004 and A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311]

44


SN-34Dump 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


SN-35Hammennill

Source Description

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

Specific Conditions



35 Hammennill PM 10 0.7 2.7


SN Description Pollutant lb/hr tpy35 Hammermill PM 1.6 6.8





46








47


SN-36Meal Loading Enclosure

Source Description

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

48


SN-37Hull Loading Enclosure

Source Description

Hulls are loaded into trucks in the hull loading area. This source was installed in 1993.Emissions are controlled by a cyclone (Cyclone 20).

Specific Conditions



37 Hull Loading Enclosure PMlO 0.1 0.1

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


37 Hull Loading Enclosure PM 0.1 0.2




49








[Regulation 19, §19.705, AC.A §8-4-203 as referenced by §8-4-304 and §8-4-311, and40 CFR 70.6]

50


SN-38Bulk Hull House

Source Description

Cottonseed hulls are blown from the hulling and separating area to either the Bulk Hull House(SN-38) or one of the two Sacked Hull Houses (SN-39 or SN-40). In the Bulk Hull House,Cyclone H-21 collects the hulls and drops them onto a conveyor belt which drops them into theHull House for storage until they are removed in bulk quantities (i.e., trailer truck loads).

Specific Conditions


SN Description Pollutant lb/hr tpy38 Bulk Hull House PMIO 0.4 1.4


SN Description Pollutant lb/hr tpy38 Bulk Hull House PM 1.1 4.1



47. Weekly observations of the opacity from SN-38 shall be conducted by personnel familiarwith the permittee's visible emissions. The pennittee shall maintain personnel trained inEPA Reference Method 9. If visible emissions which appear to be in excess of thepermitted opacity are detected, the permittee shall immediately take action to identify thecause of the visible emissions, implement corrective action, and document that visibleemissions did not appear to be in excess of the permitted opacity following the correctiveaction. The permittee shall maintain records which contain the following items in orderto demonstrate compliance with this specific condition. These records shall be updatedweekly, kept on site, and made available to Department personnel upon request.

51









52


SN-39 and 40Sacked Hull Houses

Source Description

The Sacked Hull House processes are similar to the Bulk Hull House except that the hulls arestored in a bin until they are fed to hull sacker machines. This process allows the hulls to be soldin smaller, sacked quantities. Cyclones H-22 and H-23 are used in this process. These sourceswere installed in 1993. Emissions from these cyclones are routed to Rotary Drum Filter (SN58).

53


SN-44 and 45Boilers #1 and #2

Source Description

SN-44 and SN-45 are natural gas fired boilers each rated at 20.922 MMBtuIhr. Boiler #1 (SN44) was replaced in October of2002. Boiler #2 (SN-45) was overhauled in 2002.

Specific Conditions

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

SN Description Pollutant lb/hr tpyPM IO 0.2 0.7SOl 0.1 0.1

44 Boiler #1VOC 0.2 0.5CO 1.8 7.7NOx 2.1 9.2Lead 1.1E-5 4.6E-5PM 10 0.2 0.7SOl 0.1 0.1

45 Boiler #2VOC 0.2 0.5CO 1.8 7.7

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

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

SN Description Pollutant lb/hr tpyPM 0.2 0.7

Arsenic 4.2E-6 1.9E-5Beryllium 2.6E-7 1.1E-6

44 Boiler #1 Cadmium 2.3E-5 1.0E-4Hexane 0.04 0.20


54


SN Description Pollutant lb/hr tpyPM 0.2 0.7

Arsenic 4.2E-6 1.9E-5Beryllium 2.6E-7 1.IE-6

45 Boiler #2 Cadmium 2.3E-5 1.0E-4Hexane 0.04 0.20



SN Limit Regulatory Citation44&45 5% §18.501

51. Natural gas shall be the only source of fuel used in SN-44 and SN-45. Pipeline naturalgas is defined as a natural gas which contains 0.5 grains or less of total sulfur per 100standard cubic feet, and pipeline natural gas must either be composed of at least 70percent methane by volume or have a gross calorific value between 950 and 1100 Btu perstandard cubic foot. [Regulation 19, §19.705, A.C.A. §8-4-203 as referenced by §8-4304 and §8-4-311, and 40 CFR 70.6]

52. SN-44 and SN-45 are affected units of 40 CFR 60, Subpart De-Standards ofPerformancefor Small Industrial-Commercial-Institutional Steam Generating Units because they wereconstructed after June 9, 1989. [Regulation 19, §19.304 and 40 CFR 60, Subpart DeStandards ofPerformance for Small Industrial-Commercial-Institutional SteamGenerating Units Appendix A]

53. The owner or operator of SN-44 and SN-45 shall record and maintain records of theamounts of each fuel combusted every month. All records of fuel combusted shall bemaintained by the owner or operator for a period of two years following the date of suchrecord. [Regulation 19, §19.304 and 40 CFR 60, §60.48c (g)(2)]

55


SN-47Bulk House Cooling Fans

Source Description

SN-47 is the combined emissions ofnineteen seed cooling fans located at Planter's locations intown. 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 arelocated at the Active Mill (AM). The fans are used to blow air through the cottonseed in order toremove 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 in1993. Source testing was performed on one of the fans in December of 2001.

Specific Conditions

54. 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 40CFR Part 52, Subpart E]

SN Description Pollutant lblhr tpyLM Seed House #5 PM10

LM Seed House #6 PM IO

47-LMLM Seed House #7 PM10

LM Seed House #8 PM10

LM Seed House #9 PM IO

LM Seed House #10 PM10

OM Seed House #11 PM10

47-0MOM Seed House #12-A PM10

OM Seed House #12-B PM IO

OM Seed House #13 PM10 2.4 10.6AM Seed House #14 PM10

AM Seed House #15-A PM10

AM Seed House #15-B PM10

AM Seed House #16-A PM IO

47-AM AM Seed House #16-B PM10





55. 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 A.C.A. §8-4-304 and §8-4-311]

56


SN Description Pollutant lb/hr tpyLM Seed House #5 PMLM Seed House #6 PM

47-LMLM Seed House #7 PMLM Seed House #8 PMLM Seed House #9 PMLM Seed House #10 PMOM Seed House #11 PM

47-0MOM Seed House #12-A PMOM Seed House #12-B PM

OM Seed House #13 PM 6.9 30.0AM Seed House #14 PM

AM Seed House #15-A PMAM Seed House #15-B PMAM Seed House #16-A PM

47-AM AM Seed House #16-B PMAM Seed House #17-A PMAM Seed House #17-B PMAM Seed House #18-A PMAM Seed House #18-B PM


SN Limit Regulatory Citation

47-LM 5% §18.50147-0M 5% §18.50147-AM 5% §18.501






57





58


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

Source Description

Trash Beater #1 is controlled by the bran and pepper cyclone (Cyclone B-1) which collectswastes from the bran and pepper shaker unit. Trash Beater #2 is controlled by the lint and motescyclone (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 sourceswere installed in 1993. Emissions from these cyclones were routed to Rotary Drum Filter #3,SN-64.

59


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 inorder to reduce particulate matter emissions from the facility. This drum filter was installed topick up emissions from the Meal Loading Enclosure Cyclone (SN-36), Hull Loading EnclosureCyclone (SN-39) and Sacked Hull House Cyclone (SN-40). The outlet for RDF-l is rated at67,000 cfm.

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

Specific Conditions


SN Description Pollutant lb/hr tpy58 Rotary Drum Filter #1 PM10 0.5 2.159 Rotary Drum Filter #2 PM10 0.4 1.6

59. The permittee shall not exceed the emission rates set forth in the following table. Thepermittee 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. §8-4304 and §8-4-311]

SN Description Pollutant lb/hr tpy58 Rotary Drum Filter #1 PM 1.2 5.159 Rotary Drum Filter #2 PM 0.9 4.0


60


SN Limit Regulatory Citation58 & 59 10% §18.501

61. Weekly observations of the opacity from SN-58 and SN-59 shall be conducted bypersonnel familiar with the permittee's visible emissions. The permittee shall maintainpersonnel trained in EPA Reference Method 9. If visible emissions which appear to be inexcess of the permitted opacity are detected, the permittee shall immediately take actionto identify the cause of the visible emissions, implement corrective action, and documentthat visible emissions did not appear to be in excess of the permitted opacity followingthe corrective action. The permittee shall maintain records which contain the followingitems in order to demonstrate compliance with this specific condition. These recordsshall be updated weekly, kept on site, and made available to Department personnel uponrequest.








61


SN-60Portable Material Loading Units

Source Description

Portable mobile units are used to load cottonseed, meal, and lorhulls into trucks. The mobileconveyors can load a maximum of75 tons per hour each. A maximum of22,500 tons ofmaterial are loaded annually. These portable material loading units (SN-60) were reclassifiedas an Insignificant Activity (A-B) with the 2005 permit renewal (1427-AOP-R7). There arethree larger units and one smaller unit in the black seed area.

62


SN-62Protein Shakers (Cyclone PS-l)

Source Description

The Protein Shakers remove excess hulls and large fiber from the meat and are mixed back intothe finished hull product. The addition of two (2) Protein Shakers helps maintain a higherprotein content and improves the quality of the finished meal product. The exhausts from eachProtein Shaker are routed through 54" Cyclone (PS-l) directly to atmosphere. This unit wasinstalled in 2004.

Specific Conditions


SN Description Pollutant lb/hr tpy62 Protein Shakers (Cyclone PS-l) PM10 0.1 0.5

63. The permittee shall not exceed the emission rates set forth in the following table. Thepermittee shall demonstrate compliance with this condition by compliance with PlantWide Conditions 7,8, and 9. [Regulation 18, §18.80l and A.C.A. §8-4-203 as referencedby A.C.A. §8-4-304 and §8-4-311]

SN Description Pollutant lb/hr tpy62 Protein Shakers (Cyclone PS-l) PM 0.9 3.8



65. Weekly observations of the opacity from SN-62 shall be conducted by personnel familiarwith the permittee's visible emissions. The permittee shall maintain personnel trained inEPA Reference Method 9. Ifvisible emissions which appear to be in excess of thepermitted opacity are detected, the permittee shall immediately take action to identify thecause of the visible emissions; implement corrective action, and document that visibleemissions did not appear to be in excess of the permitted opacity following the correctiveaction. The permittee shall maintain records which contain the following items in orderto demonstrate compliance with this specific condition. These records shall be updatedweekly, kept on site, and made available to Department personnel upon request.

63









64


SN-63Trash Shaker Receiving

Source Description

The trash shaker receiving cyclone is used to collect waste from the lint cleaners. The unit wasinstalled in 1993. Emissions are controlled and routed through Cyclone C-9 directly toatmosphere.

Specific Conditions


SN Description Pollutant lb/hr tpy63 Trash Shaker Receiving PMlO 0.1 0.5


SN Description Pollutant lb/hr toy63 Trash Shaker Receiving PM10 0.4 1.7





65


b. If visible emissions which appeared to be above the permitted limit were,detected;






66


SN-64Rotary 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), SalvageReclaim (SN-05 and SN-14), Recycling (SN-15), Recycling System (SN-52), Trash Beaters #1and #2 (SN-55 and SN-61), and Hull Shaker and Cascade Fans (SN-65 thru SN-71). The outletfor RDF-3 is rated at 170,000 cfrn but tested at 181,200 cfm on June 15-16,2005.

Specific Conditions


SN Description Pollutant lb/hr tpy64 Rotary Drum Filter (RDF-3) PM lO 1.3 5.5


SN Description Pollutant lb/hr tpy64 Rotary Drum Filter (RDF-3) PM 10 3.1 13.6




67








[Regulation 19, §19.705, AC.A §8-4-203 as referenced by §8-4-304 and §8-4-311, and40 CFR 70.6]

68


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

Source Description

Seven (7) fans used for additional air handling and aspiration are sources that existed prior to theinstallation ofRotary Drum Filter #3 (SN-64). The emissions from these sources were routed toSN-64 when it was installed in 2004.

69


SN-72Boiler #3

Source Description

SN-72 is a 25.0 MMBtulhr, 500 HP shop assembled packaged industrial water tube boiler thatwill be capable of combusting cotton seed hulls, a refuse derived fuel (RDF) which is composedof a cellulose fiber/polypropylene plastic mix, or sawdust and wood shavings. The RDF isprovided in cube form by Ba1cones of Little Rock. This Boiler was installed in 2005. Naturalgas will also be burned during periods of low solid fuel supplies.

Specific Conditions

74. The permittee shall not exceed the emission rates set forth in the following table. Thepermittee shall demonstrate compliance with this condition by compliance with SpecificConditions 77 through 80 and permitting this source at maximum capacity. [Regulation19, §19.501 et seq. and 40 CFR Part 52, Subpart E]

SN Description Pollutant lb/hr tpyPM10 1.9 8.4S02 4.0 17.6

72 Boiler #3VOC 1.6 7.0CO 17.0 74.5NOx 6.1 26.7Lead 0.02 0.086

75. The permittee shall not exceed the emission rates set forth in the following table. Thepermittee shall demonstrate compliance with this condition by compliance with SpecificConditions 77 through 79 and permitting this source at maximum capacity. [Regulation18, §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 tpyPM 1.9 8.4uci 0.5 2.20

Hexane 0.05 0.20

72 Boiler #3Mercury 7.5E-4 0.00033Arsenic 0.0012 0.0051

Beryllium 0.00019 0.00081Cadmium 0.0013 0.0056

Manganese 0.40 1.80

70




77. The permittee shall maintain a continuous opacity monitoring system (CaMS) tomeasure opacity from SN-72. The permittee shall demonstrate compliance with theopacity limit by installing, operating, and maintaining a certified CaMS. The CaMSshall comply with the ADEQ Continuous Emission Monitoring Systems (CEMS)Conditions. [Regulation 19, §19.703, A.c.A. §8-4-203 as referenced by §8-4-304 and§8-4-311, and 40 CFR Part 52, Subpart E]

78. Pipeline natural gas shall be an alternate source of fuel used in SN-72. Pipeline naturalgas is defined as a natural gas which contains 0.5 grains or less of total sulfur per 100standard cubic feet, and pipeline natural gas must either be composed of at least 70percent methane by volume or have a gross calorific value between 950 and 1100 Btu perstandard cubic foot. [Regulation 19, §19.705, A.C.A. §8-4-203 as referenced by §8-4304 and §8-4-311, and 40 CFR 70.6]

79. The permittee shall conduct stack emissions testing on the boiler (SN-72) to measure thefollowing pollutants by the indicated US EPA Reference Test Method as published in 40CFR Part 60 Appendix A.

Pollutant EPA Test MethodPM 5 and 202

PM10 201A and 202 or 5 and 202*CO 10

* By using Method 5 and 202 for PMIO, the facility will assume all collected particulate is PMIO•

The facility shall perform this testing every 5 years from the date of the last successfultest. If at any time the facility fails one ofthe 5-year tests, or the facility conductsadditional modifications to the boiler, then the facility must conduct two successiveannual tests. If both of these annual tests are successful, then the facility may return tothe five-year testing schedule. All tests shall be conducted with the boiler operating at90% or greater of capacity. Failure to test at or above this level shall limit the permitteeto operating within 10% above the tested rate. The ADEQ Air Division ComplianceInspector Supervisor shall be notified at least 15 business days prior to the testing.Results of all testing shall be submitted to the address indicated in General Provision 7.[Regulation 19, §19.702 and 40 CFR Part 52 Subpart E]

80. The permittee shall conduct stack emissions testing on the boiler (SN-72) to measure theS02 using US EPA Reference Test Method 6C while combusting RDF. This testing shallbe conducted within 60 days of combusting RDF for the first time. The facility shallperform this testing every 5 years from the date of the last successful test. If at any time

71


the facility fails one of the 5-year tests, or the facility conducts additional modificationsto the boiler, then the facility must conduct two successive annual tests. Ifboth of theseannual tests are successful, then the facility may return to the five-year testing schedule.All tests shall be conducted with the boiler operating at 90% or greater of capacity.Failure to test at or above this level shall limit the permittee to operating within 10%above the tested rate. The ADEQ Air Division Compliance Inspector Supervisor shall benotified at least 15 business days prior to the testing. Results of all testing shall besubmitted to the address indicated in General Provision 7. [Regulation 19, §19.702 and40 CFR Part 52 Subpart E]

81. Based on maximum design heat input capacity and date of construction, SN-72 is anaffected source under 40 CFR Part 60, Subpart De - Standards ofPerformance for SmallIndustrial-Commercial-Institutional Steam Generating Units. The applicablerequirements of Subpart De include, but are not limited, to the following: [Regulation19, §19.304 and 40 CFR §60.40c (a)]

a. The permittee shall submit notification of the date of construction orreconstruction and actual startup ofSN-72, as provided in 40 CFR Part §60.7.This notification shall include the heat input design capacity of SN-72 andidentification of fuels to be combusted in SN-72. [Regulation 19, §19.304 and40 CFR §60.48c (a)(l)]

b. The permittee shall record and maintain records of the total amount of each steamgenerating unit fuel delivered during each calendar month or other method ofdemonstrating compliance as allowed under 40 CFR §60.48c (g). These recordsshall be maintained by the permittee for a period of two years following the dateof such record. [Regulation 19, §19.304, 40 CFR §60.48c (g)(3) and 40 CFR§60.48c (g)(2)]

72


SN-73Black Cotton Seed Tank

Source Description

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

Specific Conditions

82. The permittee shall not exceed the emission rates set forth in the following table. Theemission limits are based an equipment capacity of 8.5 tons of seed per hour fed into thetank. [Regulation 19, §19.501 et seq. and 40 CFR Part 52, Subpart E]


73 Black Cotton Seed Tank PM IO 0.1 0.1

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


73 Black Cotton Seed Tank PM 0.1 0.2


SNs Limit Regulatory Citation73 5% §18.501


73








[Regulation 19, §19.705, A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311, and 40 CFR70.6]

74


SECTION V: COMPLIANCE PLAN AND SCHEDULE

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

75


SECTION VI: PLANTWIDE CONDITIONS

I. The permittee shall notify the Director in writing within thirty (30) days aftercommencing construction, completing construction, first placing the equipment and/orfacility 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 referencedby A.C.A. §8-4-304 and §8-4-311]

2. If the permittee fails to start construction within eighteen months or suspendsconstruction for eighteen months or more, the Director may cancel all or part of thispermit. [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 inthe Specific Conditions of this permit or by any federally regulated requirements, withinthe following time frames: (1) new equipment or newly modified equipment within sixty(60) days of achieving the maximum production rate, but no later than 180 days afterinitial startup of the permitted source or (2) operating equipment according to the timeframes set forth by the Department or within 180 days of permit issuance if no date isspecified. The permittee must notify the Department of the scheduled date of compliancetesting at least fifteen (15) business days in advance of such test. The permittee shallsubmit the compliance test results to the Department within thirty (30) calendar days aftercompleting the testing. [Regulation 19, §19.702 and/or Regulation 18 §18.1002 andA.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; andd. Utilities for sampling and testing equipment.

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

5. The permittee must operate the equipment, control apparatus and emission monitoringequipment within the design limitations. The permittee shall maintain the equipment ingood condition at all times. [Regulation 19, §19.303 and A.C.A. §8-4-203 as referencedby 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 of cottonseed at the facility shall be limited to 350,000 tons perconsecutive twelve month period. Compliance shall be demonstrated through record

76


keeping requirements set forth in Plant Wide Condition 8. [Regulation 19, §19.705,A.C.A. §8-4-203 as referenced by A.C.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 atwelve-month rolling total basis, updated monthly, kept on site and made available to theDepartment upon request. The permittee shall submit a semi-annual report includingcottonseed throughput to the Department as set forth in General Provision Error!Reference source not found.. [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 inserviceable condition as prescribed by the manufacturer during operation of the sources atthe facility. Each cyclone or filter shall be inspected no less than one time per week toensure 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 beupdated upon the completion of each weekly inspection, kept on site and made availableto the Department upon request. [Regulation 18, §18.l104 and A.C.A. §8-4-203 asreferenced by §8-4-304 and §8-4-311]

10. Testing shall be performed to measure the particulate emissions from one (1) of the lintcleaner cyclones on SN-06 through SN-12 in accordance with EPA Reference Method 5.Also testing shall be performed to measure the particulate emissions from one of the seedcleaner cyclones on SN-18 though SN-26 in accordance with EPA Reference Method 5.The test shall take place in accordance with Plant Wide Condition 3. In addition testingshall be performed to measure the particulate emissions from one of the protein shakercyclones on SN-62 or SN-63 in accordance with EPA Reference Method 5. During thetests, the facility shall be operated within 90% of its design capacity. The Departmentreserves the right to select which cyclones are to be tested. [Regulation 19, §19.702 and40 CFR Part 52, Subpart E]

11. Planters Cotton Oil Mill shall comply with the requirements of 40 CFR 63, SubpartGGGG - National Emission Standardsfor Hazardous Air Pollutants: Solvent Extractionfor Vegetable Oil Production. These requirements include, but are not limited to theconditions listed in Plant Wide Conditions 12 through 23. [Regulation 19, §19.304 and40 CFR 63]

12. For each operating month, the facility must calculate the compliance ratio whichcompares 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 sourceprocesses a listed oilseed, excluding any entire calendar month in which the sourceoperated under an initial startup period subject to §63.2850(c)(2) r (d)(2) or a malfunctionperiod subject to §63.2850(e)(2). [Regulation 19, §19.304 and 40 CFR §63.2840 (a)(1)and (a)(2)]

77

Planters Cotton Oil Mill, IncorporatedPermit #: l427-AOP-RllAFIN: 35-00025

Compliance Ratiof * Actual Solvent Los s

n

0.64 * L:((Oilseed)i * (SLF)i)i=l

Where:f= The weighted average volume fraction of HAP in solvent received during the previous12 operating months, as determined in §63.2854, dimensionless.

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

Actual Solvent Loss = Gallons of actual solvent loss during previous 12 operatingmonths, as determined in §63.2853.

Oilseed = Tons of cottonseed processed during the previous 12 operating months, asshown in §63.2855.

SLF = Oil seed loss factor = 0.5 gal/ton

13. When calculating the compliance ratio, the facility may consider the conditions andexclusions in paragraphs (b)(I) through (6) of 40 CFR §63.2840. [Regulation 19,§19.304 and 40 CFR §63.2840(b)]

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

15. The facility shall develop and implement a plan for demonstrating compliance inaccordance with 40 CFR §63.2851. This plan shall be kept on site and available toDepartment personnel upon request. [Regulation 19, §19.304 and 40 CFR§63.2850(a)(2)]

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

17. The facility shall maintain all the necessary records used to demonstrate compliance with40 CFR Part 63 Subpart GGGG in accordance with §63.2862. [Regulation 19, §19.304and 40 CFR §63.2850(4)]

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

78


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

b. Periodic SSM reports in accordance with §63.2861(c) if the facility operatesunder a malfunction period. The report shall be submitted by the end of the monthfollowing the calendar month in which the malfunction period occurred.

c. Immediate SSM reports in accordance with §63.2861(d) if the facility operatesduring a malfunction period differently from the procedures in the SSM plan. Animmediate SSM report consists of a telephone call or facsimile transmission to theDepartment within 2 working days after starting actions inconsistent with theSSM plan followed by a letter within 7 working days after the end of the event.

19. If the compliance ratio exceeds 1.00, the facility shall report by the end of the monthfollowing the calendar month in which the deviation was determined. The deviationnotification shall include items (b) (1) through (4) of 40 CFR §63.2861. [Regulation 19,§19.304 and 40 CFR §63.2861(b)]

20. 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 compliancedate for the facility and keep them on-site and readily available as long as the source isoperational. [Regulation 19, §19.304 and 40 CFR §63.2862(b)]

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

22. After the facility has processed listed oilseed for 12 operating months, and is notoperating during an initial startup period as described in §63.2850(c)(2) or (d)(2), or amalfunction period as described in §63.2850(e)(2), record the items in paragraphs (d)(l)through (5) of §63.2862 by the end of the calendar month following each operatingmonth. [Regulation 19, §19.304 and 40 CFR §63.2862(d)]

23. 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 inparagraphs (a) through (c) by the end of the calendar month following each month inwhich the initial startup period or malfunction period occurred. [Regulation 19, §19.304and 40 CFR §63.2862(e)]

a. A description and date of the SSM event, its duration, and reason it qualifies as aninitial startup or malfunction.

b. An estimate of the solvent loss in gallons for the duration of the initial startup ormalfunction period with supporting documentation.

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

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Permit Shield

24. Compliance with the conditions of this permit shall be deemed compliance with allapplicable requirements, as of the date of permit issuance, included in and specificallyidentified in the following table of this condition. The permit specifically identifies thefollowing as applicable requirements based upon the information submitted by thepermittee in an application dated November 12,2009.

Applicable Regulations

Source No. Regulation DescriptionFacility Arkansas Regulation 19 Compilation ofRegulations of the Arkansas

State Implementation Plan for Air PollutionControl

Facility Arkansas Regulation 26 Regulations of the Arkansas Operating AirPermit Program

SN-44 & 45 40 CFR 60, Subpart De. Boilers SN-44, SN-45, and SN-72 have heatNew Source Performance input capacities>10 MMBtuIhr and wereStandards for Industrial- installed after 6/9/1989. The only substantialCommercial-Institutional requirement is monthly fuel usageSteam Generating Units recordkeeping pursuant to 60.48c(g).

Solvent 40 CFR Part 63 Subpart Facility is subject. Existing facilityExtraction GGGG. National Emission compliance deadline was 4/12/2004.Plant (SN- Standards for Hazardous Air32,42,43, Pollutants: Solvent56 and 46) Extraction for Vegetable Oil

Production

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

Inapplicable Regulations

Source No. Regulation DescriptionFacility 40 CFR Part 60, Subpart Subpart Kb exempts storage tanks covered

Kb. Standards of under 40 CFR Part 63 Subpart GGGG.Performance for VolatileOrganic Liquid Storage Cottonseed oil and all other tanks at facilityVessels have a design capacity < 75 m" and/or store

liquids with maximum true vapor pressures <3.5 kilopascals

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Source No. Regulation DescriptionFacility 40 CFR Part 63 Subpart HAP (i.e., hexane) storage emissions

EEEE. National Emission regulated under Part 63 Subpart GGGG.Standards for Hazardous AirPollutants (NESHAP):Organic LiquidsDistribution

Facility 40 CFR Part 64. Emission units at the facility are not subject toCompliance Assurance CAM. Cyclones and drum filters areMonitoring considered "inherent process equipment"

under the CAM rule. The cyclones are part ofpneumatic conveying systems, and the drumfilters collect product for sale. These units arenot pollution control devices.

Title VI Provisions

25. The permittee must comply with the standards for labeling of products using ozonedepleting substances. [40 CFR Part 82, Subpart E]

a. All containers containing a class I or class II substance stored or transported, allproducts containing a class I substance, and all products directly manufacturedwith a class I substance must bear the required warning statement if it is beingintroduced to interstate commerce pursuant to §82.106.

b. The placem ent of the required warning statement must comply with therequirements pursuant to §82.108.

c. The form of the label bearing the required warning must comply with therequirements pursuant to §82.11O.

d. No person ma y modify, remove, or interfere with the required warning statementexcept as described in §82.112.

26. 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 mustcomply with the required practices pursuant to §82.156.

b. Equipment used during t he maintenance, service, repair, or disposal of appliancesmust comply with the standards for recycling and recovery equipment pursuant to§82.158.

c. Persons performing maintenance, service repair, or disposal of appliances must becertified by an approved technician certification program pursuant to §82.161.

d. Persons disposing of sma 11 appliances, MYACs, and MVAC like appliances mustcomply with record keeping requirements pursuant to §82.166. ("MVAC likeappliance" as defined at §82.152)

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e. Persons owning commercial or industrial process refrigeration equipment mustcomply with leak repair requirements pursuant to §82.156.

f. Owners/operators of appliances normally containing 50 or more pounds ofrefrigerant must keep records of refrigerant purchased and added to suchappliances pursuant to §82.166.

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

28. If the permittee performs a service on motor (fleet) vehicles when this service involvesozone depleting substance refrigerant (or regulated substitute substance) in the motorvehicle air conditioner (MVAC), the permittee is subject to all the applicablerequirements as specified in 40 CFR part 82, Subpart B, Servicing of Motor Vehicle AirConditioners.

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

29. The permittee can switch from any ozone depleting substance to any alternative listed inthe Significant New Alternatives Program (SNAP) promulgated pursuant to 40 CFR Part82, Subpart G.

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SECTION VII: INSIGNIFICANT ACTIVITIES

The following sources are insignificant activities. Any activity that has a state or federalapplicable requirement shall be considered a significant activity even if this activity meets thecriteria of §26.304 of Regulation 26 or listed in the table below. Insignificant activitydeterminations rely upon the information submitted by the permittee in an application datedNovember 12,2009.

Description CategoryHexane Tanks (not vented) A-13Miscella Tanks (not vented) A-13

Cottonseed Oil Tanks A-3Portable Material Loaders (SN-60) A-13

Air Dryer for Pellet Cooler A-13Cooker Cooling Air Exhaust A-13

Clay tanks (2) with bin vent filters A-13

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SECTION VIII: GENERAL PROVISIONS

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

2. This permit shall be valid for a period of five (5) years beginning on the date this permitbecomes 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 tooperate unless the permittee submitted a complete renewal application at least six (6)months before permit expiration. If the permittee submits a complete application, theexisting permit will remain in effect until the Department takes final action on therenewal application. The Department will not necessarily notify the permittee when thepermit renewal application is due. [Regulation 26 §26.406]

4. Where an applicable requirement of the Clean Air Act, as amended, 42 U.S.C. 7401, etseq. (Act) is more stringent than an applicable requirement of regulations promulgatedunder Title IV of the Act, the permit incorporates both provisions into the permit, and theDirector or the Administrator can enforce both provisions. [40 CFR 70.6(a)(I)(ii) andRegulation 26 §26.701(A)(2)]

5. The permittee must maintain the following records of monitoring information as requiredby 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 of such analyses; andf. The operating conditions existing at the time of sampling or measurement.

[40 CFR 70.6(a)(3)(ii)(A) and Regulation 26 §26.701(C)(2)]

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6. The permittee must retain the records of all required monitoring data and supportinformation for at least five (5) years from the date of the monitoring sample,measurement, report, or application. Support information includes all calibration andmaintenance records and all original strip chart recordings for continuous monitoringinstrumentation, and copies of all reports required by this permit. [40 CFR70.6(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. Ifpermit establishes no other reporting period, the reporting period shall end on the last dayof the anniversary month of the initial Title V permit. The report is due within thirty (30)days of the end of the reporting period. Although the reports are due every six months,each report shall contain a full year of data. The report must clearly identify all instancesof deviations from permit requirements. A responsible official as defined in RegulationNo. 26, §26.2 must certify all required reports. The permittee will send the reports to theaddress below:

Arkansas Department of Environmental QualityAir DivisionATTN: Compliance Inspector Supervisor5301 Northshore DriveNorth 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 permitrequirements,including those attributable to upset conditions as defined in the permit.

a. For all upset conditions (as defined in Regulation19, § 19.601), the permittee willmake an initial report to the Department by the next business day after thediscovery ofthe occurrence. The initial report may be made by telephone andshall include:

1. The facility name and location;11. The process unit or emission source deviating from the permit limit;

111. The permit limit, including the identification of pollutants, from whichdeviation occurs;

iv. The date and time the deviation started;v. The duration of the deviation;

VI. The average emissions during the deviation;Vll. The probable cause of such deviations;

V111. Any corrective actions or preventive measures taken or being taken toprevent such deviations in the future; and

ix. The name of the person submitting the report.

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The permittee shall make a full report in writing to the Department within five (5)business days of discovery of the occurrence. The report must include, in addition tothe information required by the initial report, a schedule of actions taken or plannedto eliminate future occurrences and/or to minimize the amount the permit's limitswere exceeded and to reduce the length of time the limits were exceeded. Thepermittee may submit a full report in writing (by facsimile, overnight courier, or othermeans) by the next business day after discovery of the occurrence, and the report willserve as both the initial report and full report.

b. For all deviations, the permittee shall report such events in semi-annual reportingand annual certifications required in this permit. This includes all upsetconditions reported in 8a above. The semi-annual report must include all theinformation 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 CFR70.6(a)(3)(iii)(B)]

9. If any provision of the permit or the application thereof to any person or circumstance isheld invalid, such invalidity will not affect other provisions or applications hereof whichcan be given effect without the invalid provision or application, and to this end,provisions of this Regulation are declared to be separable and severable. [40 CFR70.6(a)(5), Regulation 26 §26.701(E), and A.C.A. §8-4-203 as referenced by §8-4-304and §8-4-311]

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

11. It shall not be a defense for a permittee in an enforcement action that it would have beennecessary to halt or reduce the permitted activity to maintain compliance with theconditions 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 thepermit for cause. The filing of a request by the permittee for a permit modification,revocation and reissuance, termination, or of a notification of planned changes oranticipated 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 of any sort, or any exclusive privilege.[40 CFR 70.6(a)(6)(iv) and Regulation 26 §26.701(F)(4)]

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14. The permittee must furnish to the Director, within the time specified by the Director, anyinformation that the Director may request in writing to determine whether cause exists formodifying, revoking and reissuing, or terminating the permit or to determine compliancewith the permit. Upon request, the permittee must also furnish to the Director copies ofrecords required by the permit. For information the permittee claims confidentiality, theDepartment may require the permittee to furnish such records directly to the Directoralong with a claim of confidentiality. [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 inRegulation 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 forchanges provided for elsewhere in this permit. [40 CFR 70.6(a)(8) and Regulation 26§26.701(H)]

17. If the permit allows different operating scenarios, the permittee shall, contemporaneouslywith making a change from one operating scenario to another, record in a log at thepermitted facility a record of the operational scenario. [40 CFR 70.6(a)(9)(i) andRegulation 26 §26.701(I)(1)]

18. The Administrator and citizens may enforce under the Act all terms and conditions in thispermit, including any provisions designed to limit a source's potential to emit, unless theDepartment specifically designates terms and conditions of the permit asbeing federallyunenforceable under the Act or under any of its applicable requirements. [40 CFR70.6(b) and Regulation 26 §26.702(A) and (B)]

19. Any document (including reports) required by this permit must contain a certification bya responsible official as defined in Regulation 26, §26.2. [40 CFR 70.6(c)(1) andRegulation 26 §26.703(A)]

20. The permittee must allow an authorized representative of the Department, uponpresentation of credentials, to perform the following: [40 CFR 70.6(c)(2) and Regulation26 §26.703(B)]

a. Enter upon the permittee's premises where the permitted source is located oremissions related activity is conducted, or where records must be kept under theconditions of this permit;

b. Have access to and copy, at reasonable times, any records required under theconditions of this permit;

c. Inspect at reasonable times any facilities, equipment (including monitoring and airpollution control equipment), practices, or operations regulated or required underthis permit; and

87


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

21. The permittee shall submit a compliance certification with the terms and conditionscontained in the permit, including emission limitations, standards, or work practices. Thepermittee must submit the compliance certification annually within 30 days following thelast day of the anniversary month of the initial Title V permit. The permittee must alsosubmit the compliance certification to the Administrator as well as to the Department.All compliance certifications required by this permit must include the following: [40CFR 70.6(c)(5) and Regulation 26 §26.703(E)(3)]

a. The identification of each term or condition of the permit that is the basis of thecertification;

b. The compliance status;c. Whether compliance was continuous or intermittent;d. The methodes) used for determining the compliance status of the source, currently

and over the reporting period established by the monitoring requirements of thispermit; and

e. Such other facts as the Department may require elsewhere in this permit or by§114(a)(3) and §504(b) of the Act.

22. Nothing in this permit will alter or affect the following: [Regulation 26 §26.704(C)]

a. The provisions of Section 303 of the Act (emergency orders), including theauthority of the Administrator under that section;

b. The liability of the permittee for any violation of applicable requirements prior toor at the time of permit issuance;

c. The applicable requirements of the acid rain program, consistent with §408(a) ofthe Act; or

d. The ability ofEPA to obtain information from a source pursuant to §114 of theAct.

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 of the deadline, anextension to any testing, compliance or other dates in this permit. No such extensions areauthorized until the permittee receives written Department approval. The Departmentmay 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; andc. The permittee documents that all reasonable measures have been taken to meet

the current deadline and documents reasons it cannot be met.

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[Regulation 18 §18.314(A), Regulation 19 §19.416(A), Regulation 26 §26.10l3(A),A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311, and 40 CFR Part 52, SubpartE]

25. The permittee may request in writing and at least 30 days in advance, temporaryemissions and/or testing that would otherwise exceed an emission rate, throughputrequirement, or other limit in this permit. No such activities are authorized until thepermittee receives written Department approval. Any such emissions shall be included inthe facility's total emissions and reported as such. The Department may grant such arequest, 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 of air pollution;d. The request contains such information necessary for the Department to evaluate

the request, including but not limited to, quantification of such emissions and thedate/time such emission will occur;

e. Such a request will result in increased emissions less than five tons of anyindividual criteria pollutant, one ton of any single HAP and 2.5 tons of totalHAPs; and

f. The permittee maintains records of the dates and results of such temporaryemissions/testing.

[Regulation 18 §18.314(B), Regulation 19 §19.416(B), Regulation 26 §26.10l3(B),A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311, and 40 CFR Part 52, SubpartE]

26. The permittee may request in writing and at least 30 days in advance, an alternativeto the specified monitoring in this permit. No such alternatives are authorized until thepermittee receives written Department approval. The Department may grant such arequest, 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 of actual monitoring to the

current requirements; andc. Any such request, if approved, is incorporated in the next permit modification

application by the permittee.

[Regulation 18 §18.314(C), Regulation 19 §19.416(C), Regulation 26 §26.10l3(C),A.c.A. §8-4-203 as referenced by §8-4-304 and §8-4-311, and 40 CFR Part 52, SubpartE]

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Appendix A

40 CFR Part 60 Subpart De - Standards ofPerformance for Small Industrial-CommercialInstitutional Steam Generating Units.

Title 40: Protection of EnvironmentPART 60-STANDARDS OF PERFORMANCE FOR NEW STATIONARY SOURCES

Subpart Dc-Standards of Performance for Small Industrial-CommerciaI-InstitutionalSteam 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 towhich 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 inputcapacity of 29 megawatts (MW) (100 million British thermal units per hour (MMBtu/hr)) or less,but greater than or equal to 2.9 MW (10 MMBtu/hr).

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

(c) Steam generating units that meet the applicability requirements in paragraph (a) of thissection 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 definedin §60.41c.

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

(e) Heat recovery steam generators that are associated with combined cycle gas turbines andmeet 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 that are capableof combusting more than or equal to 2.9 MW (10 MMBtu/hr) heat input of fossil fuel but lessthan or equal to 29 MW (100 MMBtu/hr) heat input of fossil fuel. If the heat recovery steamgenerator is subject to this subpart, only emissions resulting from combustion of fuels in thesteam generating unit are subject to this subpart. (The gas turbine emissions are subject tosubpart GG or KKKK, as applicable, of this part).

(f) Any facility covered by subpart AAAA of this part is not subject by this subpart.

(g) Any facility covered by an EPA approved State or Federal section 111(d)/129 planimplementing subpart BBBB of this part is not subject by this subpart.

[72 FR 32759, June 13, 2007, as amended at 74 FR5090, Jan. 28, 2009]

A-l

§ 60.41c Definitions.

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

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

Coal means all solid fuels classified as anthracite, bituminous, subbituminous, or lignite by theAmerican Society of Testing and Materials in ASTM 0388 (incorporated by reference, see§60.17), coal refuse, and petroleum coke. Coal-derived synthetic fuels derived from coal forthe purposes of creating useful heat, including but not limited to solvent refined coal, gasifiedcoal not meeting the definition of natural gas, coal-oil mixtures, and coal-water mixtures, arealso 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 ashcontent greater than 50 percent (by weight) and a heating value less than 13,900 kilojoules perkilogram (kJ/kg) (6,000 Btu per pound (Btullb) on a dry basis.

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

Combined cycle system means a system in which a separate source (such as a stationary gasturbine, 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 asteam generating unit for the purpose of conducting research and development of moreefficient combustion or more effective prevention or control of air pollutant emissions fromcombustion, provided that, during these periods of research and development, the heatgenerated is not used for any purpose other than preheating combustion air for use by thatsteam generating unit ( i.e. , the heat generated is released to the atmosphere without beingused for space heating, process heating, driving pumps, preheating combustion air for otherunits, generating electricity, or any other purpose).

Conventional technology means wet flue gas desulfurization technology, dry flue gasdesulfurization technology, atmospheric fluidized bed combustion technology, and oilhydrodesulfurization technology.

Distillate oil means fuel oil that complies with the specifications for fuel oil numbers 1 or 2, asdefined by the American Society for Testing and Materials in ASTM 0396 (incorporated by

A-2

reference, see §60.17) or diesel fuel oil numbers 1 or 2, as defined by the American Society forTesting and Materials in ASTM 0975 (incorporated by reference, see §60.17).

Dry flue gas desulfurization technology means a S02controi system that is located betweenthe steam generating unit and the exhaust vent or stack, and that removes sulfur oxides fromthe combustion gases of the steam generating unit by contacting the combustion gases withan alkaline reagent and water, whether introduced separately or as a premixed slurry orsolution and forming a dry powder material. This definition includes devices where the drypowder material is subsequently converted to another form. Alkaline reagents used in dry fluegas 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 fromanother source (such as a stationary gas turbine, internal combustion engine, kiln, etc.) toallow the firing of additional fuel to heat the exhaust gases before the exhaust gases enter asteam generating unit.

Emerging technology means any S02controi system that is not defined as a conventionaltechnology under this section, and for which the owner or operator of the affected facility hasreceived 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 theAdministrator, including the requirements of 40 CFR parts 60 and 61, requirements within anyapplicable State implementation plan, and any permit requirements established under 40 CFR52.21 or under 40 CFR 51.18 and 51.24.

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

Fuel pretreatment means a process that removes a portion of the sulfur in a fuel beforecombustion of the fuel in a steam generating unit.

Heat input means heat derived from combustion of fuel in a steam generating unit and doesnot include the heat derived from preheated combustion air, recirculated flue gases, or exhaustgases from other sources (such as stationary gas turbines, internal combustion engines, andkilns).

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

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

A-3

Natural gas means:

(1) A naturally occurring mixture of hydrocarbon and nonhydrocarbon gases found in geologicformations 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 Materialsin ASTM D1835 (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 agross calorific value between 34 and 43 megajoules (MJ) per dry standard cubic meter (910and 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, includingdistillate oil and residual oil.

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

Process heater means a device that is primarily used to heat a material to initiate or promote achemical 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 thedefinition of distillate oil, and all fuel oil numbers 4, 5, and 6, as defined by the AmericanSociety for Testing and Materials in ASTM D396 (incorporated by reference, see §60.17).

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

Steam generating unit operating day means a 24-hour period between 12:00 midnight and thefollowing 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.

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

A-4

Wet scrubber system means any emission control device that mixes an aqueous stream orslurry 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]

§ 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 onwhich the performance test is completed or required to be completed under §60.8, whicheverdate comes first, the owner or operator of an affected facility that combusts only coal shallneither: cause to be discharged into the atmosphere from the affected facility any gases thatcontain S02in excess of 87 ng/J (0.20 Ib/MMBtu) heat input or 10 percent (0.10) of thepotential S02emission rate (90 percent reduction), nor cause to be discharged into theatmosphere from the affected facility any gases that contain S02in excess of 520 ng/J (1.2Ib/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 containS02in excess of 87 ng/J (0.20 Ib/MMBtu) heat input or 10 percent (0.10) of the potentialS02emission rate (90 percent reduction), nor cause to be discharged into the atmosphere fromthe affected facility any gases that contain S02in excess of the emission limit is determinedpursuant 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 whichthe performance test is completed or required to be completed under §60.8, whichever datecomes first, the owner or operator of an affected facility that:

(1) Combusts only coal refuse alone in a fluidized bed combustion steam generating unit shallneither:

(i) Cause to be discharged into the atmosphere from that affected facility any gases thatcontain S02in excess of 87 ng/J (0.20Ib/MMBtu) heat input or 20 percent (0.20) of thepotential S02emission rate (80 percent reduction); nor

(ii) Cause to be discharged into the atmosphere from that affected facility any gases thatcontain S02in excess of S02in excess of 520 ng/J (1.2 Ib/MMBtu) heat input. If coal is firedwith coal refuse, the affected facility subject to paragraph (a) of this section. If oil or any otherfuel (except coal) is fired with coal refuse, the affected facility is subject to the 87 ng/J (0.20Ib/MMBtu) heat input S02emissions limit or the 90 percent S02reduction requirement specifiedin 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 S02emissionsshall neither:

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(i) Cause to be discharged into the atmosphere from that affected facility any gases thatcontain S02in excess of 50 percent (0.50) of the potential S02emission rate (50 percentreduction); nor

(ii) Cause to be discharged into the atmosphere from that affected facility any gases thatcontain S02in excess of 260 ng/J (0.60 Ib/MMBtu) heat input. If coal is combusted with otherfuels, the affected facility is subject to the 50 percent S02reduction requirement specified inthis paragraph and the emission limit determined pursuant to paragraph (e)(2) of this section.

(c) On and after the date on which the initial performance test is completed or required to becompleted under §60.8, whichever date comes first, no owner or operator of an affected facilitythat 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 thataffected facility any gases that contain S02in excess of the emission limit determined pursuantto paragraph (e)(2) of this section. Percent reduction requirements are not applicable toaffected 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 aresubject to a federally enforceable requirement limiting operation of the affected facility to anannual capacity factor for coal of 55 percent (0.55) or less.

(3) Affected facilities located in a noncontinental area.

(4) Affected facilities that combust coal in a duct burner as part of a combined cycle systemwhere 30 percent (0.30) or less of the heat entering the steam generating unit is fromcombustion of coal in the duct burner and 70 percent (0.70) or more of the heat entering thesteam 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 becompleted under §60.8, whichever date comes first, no owner or operator of an affected facilitythat combusts oil shall cause to be discharged into the atmosphere from that affected facilityany gases that contain S02in excess of 215 ng/J (0.50 Ib/MMBtu) heat input; or, as analternative, no owner or operator of an affected facility that combusts oil shall combust oil inthe affected facility that contains greater than 0.5 weight percent sulfur. The percent reductionrequirements 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 becompleted under §60.8, whichever date comes first, no owner or operator of an affected facilitythat combusts coal, oil, or coal and oil with any other fuel shall cause to be discharged into theatmosphere from that affected facility any gases that contain S02in excess of the following:

(1) The percent of potential S02emission rate or numerical S02emission rate required underparagraph (a) or (b)(2) of this section, as applicable, for any affected facility that

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

(ii) Has a heat input capacity greater than 22 MW (75 MMBtu/hr); 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 facilitythat combusts coal, oil, or coal and oilwith any other fuel:

E. =(K..H.. +K~H\ + K,H,), (H..+H\ +H<;)

Where:

Es= S02emission 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 facilitysubject 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) ofthis section, in J (MMBtu); and

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

(f) Reduction in the potential S02emission rate through fuel pretreatment is not credited towardthe 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 potentialS02emission rate; and

(2) Emissions from the pretreated fuel (without either combustion or post-combustionS02control) are equal to or less than the emission limits specified under paragraph (b)(2) ofthis section.

(g) Except as provided in paragraph (h) of this section, compliance with the percent reductionrequirements, fuel oil sulfur limits, and emission limits of this section shall be determined on a30-day rolling average basis.

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(h) For affected facilities listed under paragraphs (h)(1), (2), or (3) of this section, compliancewith the emission limits or fuel oil sulfur limits under this section may be determined based ona 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 (10and 100 MMBtu/hr).

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

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

(i) The S02emission limits, fuel oil sulfur limits, and percent reduction requirements under thissection apply at all times, including periods of startup, shutdown, and malfunction.

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


§ 60.43c Standard for particulate matter (PM).

(a) On and after the date on which the initial performance test is completed or required to becompleted under §60.8, whichever date comes first, no owner or operator of an affected facilitythat 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 capacityof 8.7 MW (30 MMBtu/hr) or greater, shall cause to be discharged into the atmosphere fromthat 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 combustscoal 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 subjectto a federally enforceable requirement limiting operation of the affected facility to an annualcapacity 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 becompleted under §60.8, whichever date comes first, no owner or operator of an affected facilitythat 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

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heat input capacity of 8.7 MW (30 MMBtu/hr) or greater, shall cause to be discharged into theatmosphere from that affected facility any gases that contain PM in excess of the followingemissions limits:

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

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

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

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

(e)(1) On and after the date on which the initial performance test is completed or is required tobe completed under §60.8, whichever date comes first, no owner or operator of an affectedfacility 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 anyother fuels and has a heat input capacity of 8.7 MW (30 MMBtu/hr) or greater shall cause to bedischarged into the atmosphere from that affected facility any gases that contain PM in excessof 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 owneror 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 initialperformance test is completed or required to be completed under §60.8, whichever datecomes first, no owner or operator of an affected facility that commences modification afterFebruary 28, 2005 shall cause to be discharged into the atmosphere from that affected facilityany 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, amixture of these fuels, or a mixture of these fuels with any other fuels; and

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(ii) 0.2 percent of the combustion concentration (99.8 percent reduction) when combustingcoal, 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 becompleted under §60.8, whichever date comes first, no owner or operator of an affected facilitythat commences modification after February 28, 2005, and that combusts over 30 percentwood (by heat input) on an annual basis and has a heat input capacity of 8.7 MW (30MMBtu/hr) or greater shall cause to be discharged into the atmosphere from that affectedfacility any gases that contain PM in excess of 43 ng/J (0.10 Ib/MMBtu) heat input.

(4) On and after the date on which the initial performance test is completed or is required to becompleted under §60.8, whichever date comes first, an owner or operator of an affected facilitythat commences construction, reconstruction, or modification after February 28, 2005, and thatcombusts only oil that contains no more than 0.50 weight percent sulfur or a mixture of 0.50weight percent sulfur oil with other fuels not subject to a PM standard under §60.43c and notusing a post-combustion technology (except a wet scrubber) to reduce PM or S02emissions isnot subject to the PM limit in this section.


§ 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), performancetests required under §60.8 shall be conducted following the procedures specified inparagraphs (b), (c), (d), (e), and (f) of this section, as applicable. Section 60.8(f) does not applyto this section. The 30-day notice required in §60.8(d) applies only to the initial performancetest unless otherwise specified by the Administrator.

(b) The initial performance test required under §60.8 shall be conducted over 30 consecutiveoperating days of the steam generating unit. Compliance with the percent reductionrequirements and S02emission limits under §60.42c shall be determined using a 30-dayaverage. The first operating day included in the initial performance test shall be scheduledwithin 30 days after achieving the maximum production rate at which the affect facility will beoperated, but not later than 180 days after the initial startup of the facility. The steamgenerating unit load during the 30-day period does not have to be the maximum design heatinput 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 isbased on the average percent reduction and the average S02emission rates for 30consecutive steam generating unit operating days. A separate performance test is completedat the end of each steam generating unit operating day, and a new 30-day average percentreduction 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, theprocedures in Method 19 of appendix A of this part are used to determine the hourly

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S02emission rate (Eho) and the 3D-day average S02emission rate (Eao). The hourly averagesused to compute the 3D-day averages are obtained from the CEMS. Method 19 of appendix Aof this part shall be used to calculate Eaowhen using daily fuel sampling or Method 6B ofappendix A of this part.

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

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

Where:

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

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

Ew= S02concentration in fuels other than coal and oil combusted in the affected facility, asdetermined 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 timethat the lot is being combusted. The owner or operator does not have to measure Ewiftheowner or operator elects to assume Ew= D.

Xk= Fraction of the total heat input from fuel combustion derived from coal and oil, asdetermined 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§6D.42c(c) or (d) (where percent reduction is not required) does not have to measure theparameters EworXkif the owner or operator of the affected facility elects to measure emissionrates of the coal or oil using the fuel sampling and analysis procedures under Method 19 ofappendix A of this part.

(f) Affected facilities subject to the percent reduction requirements under §6D.42c(a) or (b) shalldetermine compliance with the S02emission limits under §6D.42c pursuant to paragraphs (d)or (e) of this section, and shall determine compliance with the percent reduction requirementsusing the following procedures:

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

%P =100(1 -%Rf)(l _%R!), 100 100

Where:

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%Ps= Potential S02emission rate, in percent;

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

%Rf= S02removai efficiency of fuel pretreatment as determined by Method 19 of appendix A ofthis part, in percent.

(2) If coal, oil, or coal and oil are combusted with other fuels, the same procedures required inparagraph (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~ )f E~

Where:

%Rgo = Adjusted %Rg, in percent;

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

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

(ii) To compute Eaio, an adjusted hourly S02iniet rate (EhP) is used. The EhiO is computedusing 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, asdetermined by fuel sampling and analysis procedures in Method 19 of appendix A of this part,ng/J (Ib/MMBtu). The value Ewfor each fuel lot is used for each hourly average during the timethat the lot is being combusted. The owner or operator does not have to measure Ewif theowner or operator elects to assume Ew= 0; and

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

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(g) For oil-fired affected facilities where the owner or operator seeks to demonstratecompliance with the fuel oil sulfur limits under §60.42c based on shipment fuel sampling, theinitial performance test shall consist of sampling and analyzing the oil in the initial tank of oil tobe fired in the steam generating unit to demonstrate that the oil contains 0.5 weight percentsulfur or less. Thereafter, the owner or operator of the affected facility shall sample the oil inthe 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 seeksto demonstrate compliance with the S02standards based on fuel supplier certification, theperformance 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 theS02standards under §60.42c(c)(2) shall demonstrate the maximum design heat input capacityof the steam generating unit by operating the steam generating unit at this capacity for 24hours. This demonstration shall be made during the initial performance test, and a subsequentdemonstration may be requested at any other time. If the demonstrated 24-hour average firingrate for the affected facility is less than the maximum design heat input capacity stated by themanufacturer of the affected facility, the demonstrated 24-hour average firing rate shall beused to determine the annual capacity factor for the affected facility; otherwise, the maximumdesign 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 incalculating %Psand Ehounder paragraphs (d), (e), or (f) of this section, as applicable, whetheror not the minimum emissions data requirements under §60.46c(f) are achieved. All validemissions data, including valid data collected during periods of startup, shutdown, andmalfunction, shall be used in calculating %Psor Ehopursuant to paragraphs (d), (e), or (f) of thissection, 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 particulatematter.

(a) The owner or operator of an affected facility subject to the PM and/or opacity standardsunder §60.43c shall conduct an initial performance test as required under §60.8, and shallconduct subsequent performance tests as requested by the Administrator, to determinecompliance with the standards using the following procedures and reference methods, exceptas 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 thenumber of traverse sampling points.

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

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

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

(ii) Method 17 of appendix A of this part may be used at affected facilities with or without wetscrubber 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 partmay be used in Method 17 of appendix A of this part only if Method 17 of appendix A of thispart is used in conjunction with a wet scrubber system. Method 17 of appendix A of this partshall not be used in conjunction with a wet scrubber system if the effluent is saturated or ladenwith water droplets.

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

(4) The sampling time for each run shall be at least 120 minutes and the minimum samplingvolume 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 whennecessitated 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 theprobe 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) measurementshall be obtained simultaneously with each run of Method 5, 58, or 17 of appendix A of thispart 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 ratesexpressed in ng/J (Ib/MM8tu) heat input shall be determined using:

(i) The 020r C02measurements and PM measurements obtained under this section, (ii) Thedry basis F factor, and

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

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

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

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rate for the affected facility is less than the maximum design heat input capacity stated by themanufacturer of the affected facility, the demonstrated 24-hour average firing rate shall beused to determine the annual capacity factor for the affected facility; otherwise, the maximumdesign 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 ofappendix A-6 of this part, an owner or operator may elect to install, calibrate, maintain, andoperate a CEMS for monitoring PM emissions discharged to the atmosphere and record theoutput of the system. The owner or operator of an affected facility who elects to continuouslymonitor PM emissions instead of conducting performance testing using Method 5 or 58 ofappendix 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 ofsubpart A of this part.

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

(5) The owner or operator of an affected facility shall conduct an initial performance test for PMemissions as required under §60.8 of subpart A of this part. Compliance with the PM emissionlimit shall be determined by using the CEMS specified in paragraph (d) of this section tomeasure PM and calculating a 24-hour block arithmetic average emission concentration usingEPA 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 outletdata.

(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 beexpressed in ng/J or Ib/MM8tu heat input and shall be used to calculate the boiler operating

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day daily arithmetic average emission concentrations. The 1-hour arithmetic averages shall becalculated using the data points required under §60.13(e)(2) of subpart A of this part.

(9) All valid CEMS data shall be used in calculating average emission concentrations even ifthe 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 B ofthis part.

(11) During the correlation testing runs of the CEMS required by Performance Specification 11in appendix B of this part, PM and 02(or CO2) data shall be collected concurrently (or within a30- to 60-minute period) by both the continuous emission monitors and performance testsconducted using the following test methods.

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

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

(12) Quarterly accuracy determinations and daily calibration drift tests shall be performed inaccordance with procedure 2 in appendix F of this part. Relative Response Audit's must beperformed 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 usingother monitoring systems as approved by the Administrator or EPA Reference Method 19 ofappendix A of this part to provide, as necessary, valid emissions data for a minimum of 75percent of total operating hours on a 30-day rolling average.

(14) After July 1,2011, within 90 days after the date of completing each performanceevaluation required by paragraph (c)(11) of this section, the owner or operator of the affectedfacility must either submit the test data to EPA by successfully entering the data electronicallyinto EPA's WebFIRE data base available athttp://cfpub.epa.gov/oB/web/index.cfm?action=fire.main or mail a copy to: United StatesEnvironmental Protection Agency; Energy Strategies Group; 109 TW Alexander DR; MailCode: 0243-01; RTP, NC 27711.

(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-firedaffected facilities, fuel supplier certifications are only allowed for facilities with heat inputcapacities between 2.9 and 8.7 MW (10 to 30 MMBtu/hr).


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§ 60.46c Emission monitoring for sulfur dioxide.

(a) Except as provided in paragraphs (d) and (e) of this section, the owner or operator of anaffected 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 CO2concentrations at the outlet of the S02 control device (or the outlet of the steam generating unitif no S02controi device is used), and shall record the output of the system. The owner oroperator of an affected facility subject to the percent reduction requirements under §60.42cshall measure S02concentrations and either O2or CO2concentrations at both the inlet andoutlet of the S02controi device.

(b) The 1-hour average S02 emission rates measured by a CEMS shall be expressed in ng/Jor Ib/MMBtu 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 ofoperation, and shall be calculated using the data points required under §60.13(h)(2). HourlyS02 emission rates are not calculated if the affected facility is operated less than 30 minutes ina 1-hour period and are not counted toward determination of a steam generating unit operatingday.

(c) The procedures under §60.13 shall be followed for installation, evaluation, and operation ofthe CEMS.

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

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

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

(4) For affected facilities that are not subject to the percent reduction requirements of §60.42'c,the span value of the S02CEMS at the outlet from the S02controi device (or outlet of the steamgenerating unit if no S02controi device is used) shall be 125 percent of the maximumestimated 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 thesteam generating unit if no S02controi device is used) as required under paragraph (a) of thissection, an owner or operator may elect to determine the average S02emission rate bysampling the fuel prior to combustion. As an alternative to operating a GEMS at the outlet fromthe 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 determinethe average S02emission rate by using Method 6B of appendix A of this part. Fuel sampling

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shall be conducted pursuant to either paragraph (d)(1) or (d)(2) of this section. Method 6B ofappendix 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 inan as-fired condition at the inlet to the steam generating unit and analyzed for sulfur contentand heat content according the Method 19 of appendix A of this part. Method 19 of appendix Aof this part provides procedures for converting these measurements into the format to be usedin calculating the average S02input rate.

(2) As an alternative fuel sampling procedure for affected facilities combusting oil, oil samplesmay be collected from the fuel tank for each steam generating unit immediately after the fueltank is filled and before any oil is combusted. The owner or operator of the affected facilityshall analyze the oil sample to determine the sulfur content of the oil. If a partially empty fueltank 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 asthe 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 weightpercent sulfur, the owner or operator shall ensure that the sulfur content of subsequent oilshipments is low enough to cause the 30-day rolling average sulfur content to be 0.5 weightpercent sulfur or less.

(3) Method 6B of appendix A of this part may be used in lieu of GEMS to measure S02at theinlet or outlet of the S02controi system. An initial stratification test is required to verify theadequacy of the Method 6B of appendix A of this part sampling location. The stratification testshall consist of three paired runs of a suitable S02and G02measurement train operated at thecandidate location and a second similar train operated according to the procedures in §3.2 andthe applicable procedures in section 7 of Performance Specification 2 of appendix B of thispart. Method 6B of appendix A of this part, Method 6A of appendix A of this part, or acombination of Methods 6 and 3 of appendix A of this part or Methods 6G and 3A of appendixA of this part are suitable measurement techniques. If Method 68 of appendix A of this part isused for the second train, sampling time and timer operation may be adjusted for thestratification test as long as an adequate sample volume is collected; however, both samplingtrains are to be operated similarly. For the location to be adequate for Method 6B of appendixA of this part 24-hour tests, the mean of the absolute difference between the three paired runsmust be less than 10 percent (0.10).

(e) The monitoring requirements of paragraphs (a) and (d) of this section shall not apply toaffected facilities subject to §60.42c(h) (1), (2), or (3) where the owner or operator of theaffected facility seeks to demonstrate compliance with the S02standards based on fuelsupplier 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) ofthis 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 30successive steam generating unit operating days. If this minimum data requirement is not metwith a single monitoring system, the owner or operator of the affected facility shall supplement

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the emission data with data collected with other monitoring systems as approved by theAdministrator.

§ 60.47c Emission monitoring for particulate matter.

(a) Except as provided in paragraphs (c), (d), (e), (f), and (g) of this section, the owner oroperator of an affected facility combusting coal, oil, or wood that is subject to the opacitystandards under §60.43c shall install, calibrate, maintain, and operate a continuous opacity

. monitoring system (COMS) for measuring the opacity of the emissions discharged to theatmosphere and record the output of the system. The owner or operator of an affected facilitysubject to an opacity standard in §60.43c(c) that is not required to use a COMS due toparagraphs (c), (d), (e), or (f) of this section that elects not to use a COMS shall conduct aperformance test using Method 9 of appendix A-4 of this part and the procedures in §60.11 todemonstrate compliance with the applicable limit in §60.43c by April 29, 2011, within 45 daysof stopping use of an existing COMS, or 180 days after initial startup of the facility, whicheveris later, and shall comply with either paragraphs (a)(1), (a)(2), or (a)(3) of this section. Theobservation period for Method 9 of appendix A-4 of this part performance tests may bereduced from 3 hours to 60 minutes if all 6-minute averages are less than 10 percent and allindividual 15-second observations are less than or equal to 20 percent during the initial 60minutes of observation.

(1) Except as provided in paragraph (a)(2) and (a)(3) of this section, the owner or operatorshall conduct subsequent Method 9 of appendix A-4 of this part performance tests using theprocedures 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 ofappendix 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 partperformance test must be completed within 12 calendar months from the date that the mostrecent performance test was conducted;

(ii) If visible emissions are observed but the maximum 6-minute average opacity is less than orequal to 5 percent, a subsequent Method 9 of appendix A-4 of this part performance test mustbe completed within 6 calendar months from the date that the most recent performance testwas conducted;

(iii) If the maximum 6-minute average opacity is greater than 5 percent but less than or equalto 10 percent, a subsequent Method 9 of appendix A-4 of this part performance test must becompleted within 3 calendar months from the date that the most recent performance test wasconducted; or

(iv) If the maximum 6-minute average opacity is greater than 10 percent, a subsequent Method9 of appendix A-4 of this part performance test must be completed within 45 calendar daysfrom the date that the most recent performance test was conducted.

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

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

(ii) If no visible emissions are observed for 30 operating days during which an opacity standardis applicable, observations can be reduced to once every 7 operating days during which anopacity standard is applicable. If any visible emissions are observed, daily observations shallbe resumed.

(3) If the maximum 6-minute opacity is less than 10 percent during the most recent Method 9of appendix A-4 of this part performance test, the owner or operator may, as an alternative toperforming subsequent Method 9 of appendix A-4 performance tests, elect to performsubsequent monitoring using a digital opacity compliance system according to a site-specificmonitoring plan approved by the Administrator. The observations shall be similar, but notnecessarily identical, to the requirements in paragraph (a)(2) of this section. For referencepurposes in preparing the monitoring plan, see OAQPS "Determination of Visible EmissionOpacity from Stationary Sources Using Computer-Based Photographic Analysis Systems."This document is available from the U.S. Environmental Protection Agency (U.S. EPA); Officeof Air Quality and Planning Standards; Sector Policies and Programs Division; MeasurementPolicy Group (0243--02), Research Triangle Park, NC 27711. This document is also availableon the Technology Transfer Network (TIN) under Emission Measurement Center PreliminaryMethods.

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

(c) Owners and operators of an affected facilities that burn only distillate oil that contains nomore than 0.5 weight percent sulfur and/or liquid or gaseous fuels with potential sulfur dioxideemission rates of 26 ng/J (0.060 Ib/MMBtu) heat input or less and that do not use a post-

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combustion technology to reduce S02 or PM emissions and that are subject to an opacitystandard in §60.43c(c) are not required to operate a COMS if they follow the applicableprocedures in §60.48c(f).

(d) Owners or operators complying with the PM emission limit by using a PM CEMS mustcalibrate, maintain, operate, and record the output of the system for PM emissions dischargedto 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 facilityexcept for CEMS breakdowns and repairs. Data is recorded during calibration checks, andzero 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) forreducing PM, S02, or carbon monoxide (CO) emissions, burns only gaseous fuels or fuel oilsthat contain less than or equal to 0.5 weight percent sulfur, and is operated such thatemissions of CO discharged to the atmosphere from the affected facility are maintained atlevels less than or equal to 0.15 Ib/MMBtu on a boiler operating day average basis is notrequired to operate a COMS. Owners and operators of affected facilities electing to complywith this paragraph must demonstrate compliance according to the procedures specified inparagraphs (e)(1) through (4) of this section; or

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

(i) The CO CEMS must be installed, certified, maintained, and operated according to theprovisions 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 theCO 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 90percent of the operating hours on a 30-day rolling average basis. The 1-hour averages arecalculated using the data points required in §60.13(h)(2).

(iv) Quarterly accuracy determinations and daily calibration drift tests for the CO CEMS mustbe 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 unitoperating day by multiplying the average hourly CO output concentration measured by the COCEMS times the corresponding average hourly flue gas flow rate and divided by thecorresponding average hourly heat input to the affected source. The 24-hour average COemission level is determined by calculating the arithmetic average of the hourly CO emissionlevels computed for each steam generating unit operating day.

(3) You must evaluate the preceding 24-hour average CO emission level each steamgenerating unit operating day excluding periods of affected source startup, shutdown, or

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malfunction. If the 24-hour average CO emission level is greater than 0.15 Ib/MMBtu, you mustinitiate investigation of the relevant equipment and control systems within 24 hours of the firstdiscovery of the high emission incident and, take the appropriate corrective action as soon aspracticable to adjust control settings or repair equipment to reduce the 24-hour average COemission level to 0.15 Ib/MMBtu or less.

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

(f) Owners and operators of an affected facility that is subject to an opacity standard in§60.43c(c) and that uses a bag leak detection system to monitor the performance of a fabricfilter (baghouse) according to the most recent requirements in section §60.48Da of this part isnot required to operate a COMS.

(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 0.5weight percent sulfur and operates according to a written site-specific monitoring planapproved by the permitting authority is not required to operate a COMS. This monitoring planmust include procedures and criteria for establishing and monitoring specific parameters forthe affected facility indicative of compliance with the opacity standard.


§ 60.48c Reporting and recordkeeping requirements.

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

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

(2) If applicable, a copy of any federally enforceable requirement that limits the annual capacityfactor 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 theaffected facility based on all fuels fired and based on each individual fuel fired.

(4) Notification if an emerging technology will be used for controlling S02emissions. TheAdministrator will examine the description of the control device and will determine whether thetechnology qualifies as an emerging technology. In making this determination, theAdministrator may require the owner or operator of the affected facility to submit additionalinformation 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.

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(b) The owner or operator of each affected facility subject to the S02emission limits of §60.42c,or the PM or opacity limits of §60.43c, shall submit to the Administrator the performance testdata from the initial and any subsequent performance tests and, if applicable, the performanceevaluation of the CEMS and/or COMS using the applicable performance specifications inappendix B of this part.

(c) In addition to the applicable requirements in §60.7, the owner or operator of an affectedfacility subject to the opacity limits in §60.43c(c) shall submit excess emission reports for anyexcess emissions from the affected facility that occur during the reporting period and maintainrecords 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, theowner 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 visibleemission 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, theowner or operator shall keep the records including the information specified in paragraphs(c)(2)(i) through (iv) of this section.

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

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

(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 tothe affected facility operation by the owner or operator to demonstrate compliance with theapplicable monitoring requirements.

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

(d) The owner or operator of each affected facility subject to the S02emission limits, fuel oilsulfur limits, or percent reduction requirements under §60.42c shall submit reports to theAdministrator.

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(e) The owner or operator of each affected facility subject to the S02emission limits, fuel oilsulfur limits, or percent reduction requirements under §6D.42c shall keep records and submitreports as required under paragraph (d) of this section, including the following information, asapplicable.

(1) Calendar dates covered in the reporting period.

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

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

(4) Identification of any steam generating unit operating days for which S020r diluent (020rCO2) data have not been obtained by an approved method for at least 75 percent of theoperating hours; justification for not obtaining sufficient data; and a description of correctiveactions taken.

(5) Identification of any times when emissions data have been excluded from the calculation ofaverage emission rates; justification for excluding data; and a description of corrective actionstaken if data have been excluded for periods other than those during which coal or oil were notcombusted in the steam generating unit.

(6) Identification of the F factor used in calculations, method of determination, and type of fuelcombusted.

(7) Identification of whether averages have been obtained based on CEMS rather than manualsampling methods.

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

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

(1 D) If a CEMS is used, results of daily CEMS drift tests and quarterly accuracy assessmentsas required under appendix F, Procedure 1 of this part.

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

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(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 thedefinition 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 sulfurcontent of the oil, specifically including whether the oil was sampled as delivered to theaffected facility, or whether the sample was drawn from oil in storage at the oil supplier's or oilrefiner'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:

(i) The name of the coal supplier;

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

(iii) The results of the analysis of the coal from which the shipment came (or of the shipmentitself) 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 inng/J heat input; and

A-25

(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 oroperator of each affected facility shall record and maintain records of the amount of each fuelcombusted during each operating day.

(2) As an alternative to meeting the requirements of paragraph (g)(1) of this section, the owneror operator of an affected facility that combusts only natural gas, wood, fuels using fuelcertification in §60.48c(f) to demonstrate compliance with the S02 standard, fuels not subject toan emissions standard (excluding opacity), or a mixture of these fuels may elect to record andmaintain 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 owneror operator of an affected facility or multiple affected facilities located on a contiguous propertyunit where the only fuels combusted in any steam generating unit (including steam generatingunits not subject to this subpart) at that property are natural gas, wood, distillate oil meeting themost current requirements in §60.42C to use fuel certification to demonstrate compliance withthe S02 standard, and/or fuels, excluding coal and residual oil, not subject to an emissionsstandard (excluding opacity) may elect to record and maintain records of the total amount ofeach 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 enforceablerequirement 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. Theannual capacity factor is determined on a 12-month rolling average basis with a new annualcapacity 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 theaffected facility for a period of two years following the date of such record.

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

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

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AppendixB

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

Title 40: Protection of EnvironmentPART 63-NATIONAL EMISSION STANDARDS FOR HAZARDOUS AIR POLLUTANTS FORSOURCE CATEGORIES (CONTINUED)

Subpart GGGG-National Emission Standards for Hazardous Air Pollutants: SolventExtraction for Vegetable Oil Production

Source: 66 FR 19011, Apr. 12,2001, unless otherwise noted.

What This Subpart Covers

§ 63.2830 What is the purpose of this subpart?

This subpart establishes national emission standards for hazardous air pollutants (NESHAP)for emissions during vegetable oil production. This subpart limits hazardous air pollutant (HAP)emissions from specified vegetable oil production processes. This subpart also establishesrequirements to demonstrate initial and continuous compliance with the emission standards.

§ 63.2831 Where can I find definitions of key words used in this subpart?

You can find definitions of key words used in this subpart in §63.2872.

§ 63.2832 Am I subject to this subpart?

(a) You are an affected source subject to this subpart if you meet all of the criteria listed inparagraphs (a)(1) and (2) of this section:

(1) You own or operate a vegetable oil production process that is a major source of HAPemissions or is collocated within a plant site with other sources that are individually orcollectively a major source of HAP emissions.

(i) A vegetable oil production process is defined in §63.2872. In general, it is the collection ofcontinuous process equipment and activities that produce crude vegetable oil and mealproducts by removing oil from oilseeds listed in Table 1 to §63.2840 through direct contact withan organic solvent, such as a hexane isomer blend.

(ii) A major source of HAP emissions is a plant site that emits or has the potential to emit anysingle HAP at a rate of 10 tons (9.07 megagrams) or more per year or any combination of HAPat a rate of 25 tons (22.68 megagrams) or more per year.

(2) Your vegetable oil production process processes any combination of eight types of oilseedslisted in paragraphs (a)(2)(i) through (viii) of this section:

(i) Corn germ;

(ii) Cottonseed;

B-1

(iii) Flax;

(iv) Peanut;

(v) Rapeseed (for example, canola);

(vi) Safflower;

(vii) Soybean; and

(viii) Sunflower.

(b) You are not subject to this subpart if your vegetable oil production process meets any of thecriteria listed in parag raphs (b)(1) throug h (4) of this section:

(1) It uses only mechanical extraction techniques that use no organic solvent to remove oilfrom a listed oilseed.

(2) It uses only batch solvent extraction and batch desolventizing equipment.

(3) It processes only agricultural products that are not listed oilseeds as defined in §63.2872.

(4) It functions only as a research and development facility and is not a major source.

(c) As listed in §63.1 (c)(5) of the General Provisions, if your HAP emissions increase such thatyou become a major source, then you are subject to all of the requirements of this subpart.

§ 63.2833 Is my source categorized as existing or new?

(a) This subpart applies to each existing and new affected source. You must categorize yourvegetable oil production process as either an existing or a new source in accordance with thecriteria in Table 1 of this section, as follows:

Table 1 to §63.2833-eategorizing Your Source as Existing or New

Then youraffected

Ifyour affected source... And if.•. source...

(I) was constructed or began reconstruction has not occurred is an existingconstruction before May 26, 2000 source.

(2) began reconstruction, as defined in (i) reconstruction was part of a scheduled plan remains an§63.2, on or after May 26,2000 to comply with the existing source existing source.

requirements of this subpart; and(ii) reconstruction was completed no later than3 years after the effective date of this subpart

B-2

Then youraffected

Ifyour affected source... And if... source...

(3) began a significant modification, as he modification does not constitute remains andefined in §63.2872, at any time on an reconstruction existing source.existing source

(4) began a significant modification, as the modification does not constitute remains a newdefined in §63.2872, at any time on a reconstruction source.new source

(5) began reconstruction on or after May reconstruction was completed later than 3 is a new source26,2000 ~ears after the effective date of this subpart

(6) began construction on or after May IS a new26,2000 source.

(b) Reconstruction of a source. Any affected source is reconstructed if components arereplaced so that the criteria in the definition of reconstruction in §63.2 are satisfied. In general,a vegetable oil production process is reconstructed if the fixed capital cost of the newcomponents exceeds 50 percent of the fixed capital cost for constructing a new vegetable oilproduction process, and it is technically and economically feasible for the reconstructed sourceto meet the relevant new source requirements of this subpart. The effect of reconstruction onthe categorization of your existing and new affected source is described in paragraphs (b)(1)and (2) of this section:

(1) After reconstruction of an existing source, the affected source is recategorized as a newsource and becomes subject to the new source requirements of this subpart.

(2) After reconstruction of a new source, the affected source remains categorized as a newsource and remains subject to the new source requirements of this subpart.

(c) Significant modification of a source. A significant modification to an affected source is aterm specific to this subpart and is defined in §63.2872.

(1) In general, a significant modification to your source consists of adding new equipment orthe modification of existing equipment within the affected source that significantly affectssolvent losses from the affected source. Examples include adding or replacing extractors,desolventizer-toasters (conventional and specialty), and meal dryer-coolers. All othersignificant modifications must meet the criteria listed in paragraphs (c)(1)(i) and (ii) of thissection:

(i) The fixed capital cost of the modification represents a significant percentage of the fixedcapital cost of building a comparable new vegetable oil production process.

(ii) It does not constitute reconstruction as defined in §63.2.

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(2) A significant modification has no effect on the categorization of your source as existing andnew. An existing source remains categorized as an existing source and subject to the existingsource requirements of this subpart. A new source remains categorized as a new source andsubject to the new source requirements of this subpart.

(d) Changes in the type of oilseed processed by your affected source does not affect thecategorization of your source as new or existing. Recategorizing an affected source fromexisting to new occurs only when you add or modify process equipment within the sourcewhich meets the definition of reconstruction.

§ 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 thissection, as follows:

Table 1 of §63.2834-Compliance Dates for Existing and New Sources

Ifyour affected source is Then your compliance datecategorized as... And if... is...

(a) an existing source 3 years after the effectivedate of this subpart.

(b) a new source lYou startup your affected source before the the effective date of thiseffective date of this subpart subpart.

(c) a new source you startup your affected source on or after your startup date.Ithe effective date of this subpart

Standards

§ 63.2840 What emission requirements must I meet?

For each facility meeting the applicability criteria in §63.2832, you must comply with either therequirements specified in paragraphs (a) through (d), or the requirements in paragraph (e) ofthis section.

(a)(1) The emission requirements limit the number of gallons of HAP lost per ton of listedoilseeds processed. For each operating month, you must calculate a compliance ratio whichcompares your actual HAP loss to your allowable HAP loss for the previous 12 operatingmonths as shown in Equation 1 of this section. An operating month, as defined in §63.2872, isany calendar month in which a source processes a listed oilseed, excluding any entirecalendar month in which the source operated under an initial startup period subject to§63.2850(c)(2) or (d)(2) or a malfunction period subject to §63.2850(e)(2). Equation 1 of thissection follows:

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Compliance Ratio Actual Hap LossAllowable Hap Loss

(Eq. 1)

(2) Equation 1 of this section can also be expressed as a function of total solvent loss asshown in Equation 2 of this section. Equation 2 of this section follows:

Cempli ance Rati 0

Where:

f * Actual Solvent Lossn

0.64 * 2:((Oilseed], * (SLF)i)1=1

(Eq.2)

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

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

Actual Solvent Loss = Gallons of actual solvent loss during previous 12 operating months, asdetermined in §63.2853.

Oilseed = Tons of each oilseed type "i" processed during the previous 12 operating months, asshown in §63.2855.

SLF = The corresponding solvent loss factor (gal/ton) for oilseed "i" listed in Table 1 of thissection, as follows:

Table 1 of §63.2840-Qilseed Solvent Loss Factors for Determining Allowable HAP Loss

Oilseed solventloss factor(gal/ton)

Type of oilseed Existing Newprocess A source that... sources sources

(i) Com Germ, Wet processes com germ that has been separated from other com 0.4 0.3Milling components using a "wet" process of centrifuging a slurry

steeped in a dilute sulfurous acid solution

(ii) Com Germ, Dry processes com germ that has been separated from the other 0.7 0.7Milling com components using a "dry" process of mechanical chafing

and air sifting

(iii) Cottonseed, processes 120,000 tons or more of a combination of 0.5 0.4Large cottonseed and other listed oilseeds during all normal

operating periods in a 12 operating month period

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Oilseed solventloss factor(gal/ton)

Type of oilseed Existing Newprocess A source that... sources sources

(iv) Cottonseed, processes less than 120,000 tons of a combination of 0.7 0.4Small cottonseed and other listed oilseeds during all normal

operating periods in a 12 operating month period

(v) Flax processes flax 0.6 0.6

(vi) Peanuts IProcessespeanuts 1.2 0.7

(vii) Rapeseed processes rapeseed 0.7 0.3

(viii) Safflower processes safflower 0.7 0.7

(ix) Soybean, uses a conventional style desolventizer to produce crude 0.2 0.2Conventional soybean oil products and soybean animal feed products

(x) Soybean, uses a special style desolventizer to produce soybean meal 1.7 1.5Specialty products for human and animal consumption

(xi) Soybean, processes soybeans in both specialty and conventional 0.25 0.25Combination Plant desolventizers and the quantity of soybeans processed inwith Low Specialty specialty desolventizers during normal operating periods isProduction less than 3.3 percent of total soybeans processed during all

normal operating periods in a 12 operating month period. Thecorresponding solvent loss factor is an overall value andapplies to the total quantity of soybeans processed.

(xii) Sunflower processes sunflower 0.4 0.3

(b) When your source has processed listed oilseed for 12 operating months, calculate thecompliance ratio by the end of each calendar month following an operating month usingEquation 2 of this section. When calculating your compliance ratio, consider the conditions andexclusions in paragraphs (b)(1) through (6) of this section:

(1) If your source processes any quantity of listed oilseeds in a calendar month and the sourceis not operating under an initial startup period or malfunction period subject to §63.2850, thenyou must categorize the month as an operating month, as defined in §63.2872.

(2) The 12-month compliance ratio may include operating months occurring prior to a sourceshutdown and operating months that follow after the source resumes operation.

(3) If your source shuts down and processes no listed oilseed for an entire calendar month,then you must categorize the month as a nonoperating month, as defined in §63.2872.Exclude any nonoperating months from the compliance ratio determination.

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(4) If your source is subject to an initial startup period as defined in §63.2872, exclude from thecompliance ratio determination any solvent and oilseed information recorded for the initialstartup period.

(5) If your source is subject to a malfunction period as defined in §63.2872, exclude from thecompliance ratio determination any solvent and oilseed information recorded for themalfunction period.

(6) For sources processing cottonseed or specialty soybean, the solvent loss factor you use todetermine the compliance ratio may change each operating month depending on the tons ofoilseed processed during all normal operating periods in a 12 operating month period.

(c) If the compliance ratio is less than or equal to 1.00, your source was in compliance with theHAP emission requirements for the previous operating month.

(d) To determine the compliance ratio in Equation 2 of this section, you must select theappropriate oilseed solvent loss factor from Table 1 of this section. First, determine whetheryour source is new or existing using Table 1 of §63.2833. Then, under the appropriate existingor new source column, select the oilseed solvent loss factor that corresponds to each typeoilseed or process operation for each operating month.

(e) Low-HAP solvent option. For all vegetable oil production processes subject to this subpart,you must exclusively use solvent where the volume fraction of each HAP comprises 1 percentor less by volume of the solvent (low-HAP solvent) in each delivery, and you must meet therequirements in paragraphs (e)(1) through (5) of this section. Your vegetable oil productionprocess is not subject to the requirements in §§63.2850 through 63.2870 unless specificallyreferenced in paragraphs (e)(1) through (5) of this section.

(1) You shall determine the HAP content of your solvent in accordance with the specificationsin §63.2854(b)(1).

(2) You shall maintain documentation of the HAP content determination for each delivery of thesolvent at the facility at all times.

(3) You must submit an initial notification for existing sources in accordance with §63.2860(a).

(4) You must submit an initial notification for new and reconstructed sources in accordancewith §63.2860(b).

(5) You must submit an annual compliance certification in accordance with §63.2861(a). Thecertification should only include the information required under §63.2861 (a)(1) and (2), and acertification indicating whether the source complied with all of the requirements in paragraph(e) of this section.

(f) You may change compliance options for your source if you submit a notice to theAdministrator at least 60 days prior to changing compliance options. If your source changes

B-7

from the low-HAP solvent option to the compliance ratio determination option, you mustdetermine the compliance ratio for the most recent 12 operating months beginning with the firstmonth after changing compliance options.

[66 FR 19011, Apr. 12, 2001, as amended at 69 FR 53341, Sept. 1, 2004]

Compliance Requirements

§ 63.2850 How do I comply with the hazardous air pollutant emission standards?

(a) General requirements. The requirements in paragraphs (a)(1)(i) through (iv) of this sectionapply to all affected sources:

(1) Submit the necessary notifications in accordance with §63.2860, which include:

(i) Initial notifications for existing sources.

(ii) Initial notifications for new and reconstructed sources.

(iii) Initial notifications for significant modifications to existing or new sources.

(iv) Notification of compliance status.

(2) Develop and implement a plan for demonstrating compliance in accordance with §63.2851.

(3) Develop a written startup, shutdown and malfunction (SSM) plan in accordance with theprovisions in §63.2852.

(4) Maintain all the necessary records you have used to demonstrate compliance with thissubpart in accordance with §63.2862.

(5) Submit the reports in paragraphs (a)(5)(i) through (iii) of this section:

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

(ii) Periodic SSM reports in accordance with §63.2861 (c).

(iii) Immediate SSM reports in accordance with §63.2861 (d).

(6) Submit all notifications and reports and maintain all records required by the GeneralProvisions for performance testing if you add a control device that destroys solvent.

(b) Existing sources under normal operation. You must meet all of the requirements listed inparagraph (a) of this section and table 1 of this section for sources under normal operation,and the schedules for demonstrating compliance for existing sources under normal operationin table 2 of this section.

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(c) New sources. Your new source, including a source that is categorized as new due toreconstruction, must meet the requirements associated with one of two compliance options.Within 15 days of the startup date, you must choose to comply with one of the options listed inparagraph (c)(1) or (2) of this section:

(1) Normal operation. Upon startup of your new source, you must meet all of the requirementslisted in §63.2850(a) and table 1 of this section for sources under normal operation, and theschedules for demonstrating compliance for new sources under normal operation in table 2 ofthis section.

(2) Initial startup period. For up to 6 calendar months after the startup date of your new source,you must meet all of the requirements listed in paragraph (a) of this section and table 1 of thissection for sources operating under an initial startup period, and the schedules fordemonstrating compliance for new sources operating under an initial startup period in Table 2of this section. After a maximum of 6 calendar months, your new source must then meet all ofthe requirements listed in table 1 of this section for sources under normal operation.

(d) Existing or new sources that have been significantly modified. Your existing or new sourcethat has been significantly modified must meet the requirements associated with one of twocompliance options. Within 15 days of the modified source startup date, you must choose tocomply with one of the options listed in paragraph (d)(1) or (2) of this section:

(1) Normal operation. Upon startup of your significantly modified existing or new source, youmust meet all of the requirements listed in paragraph (a) of this section and table 1 of thissection for sources under normal operation, and the schedules for demonstrating compliancefor an existinq or new source that has been significantly modified in table 2 of this section.

(2) Initial startup period. For up to 3 calendar months after the startup date of your significantlymodified existing or new source, you must meet all of the requirements listed in paragraph (a)of this section and table 1 of this section for sources operating under an initial startup period,and the schedules for demonstrating compliance for a significantly modified existing or newsource operating under an initial startup period in table 2 of this section. After a maximum of 3calendar months, your new or existing source must meet all of the requirements listed in Table1 of this section for sources under normal operation.

(e) Existing or new sources experiencing a malfunction. A malfunction is defined in §63.2. Ingeneral, it means any sudden, infrequent, and not reasonably preventable failure of airpollution control equipment or process equipment to function in a usual manner. If your existingor new source experiences an unscheduled shutdown as a result of a malfunction, continuesto operate during a malfunction (including the period reasonably necessary to correct themalfunction), or starts up after a shutdown resulting from a malfunction, then you must meetthe requirements associated with one of two compliance options. Routine or scheduledprocess startups and shutdowns resulting from, but not limited to, market demands,maintenance activities, and switching types of oilseed processed, are not startups orshutdowns resulting from a malfunction and, therefore, do not qualify for this provision. Within

8-9

15 days of the beginning date of the malfunction, you must choose to comply with one of theoptions listed in paragraphs (e)(1) through (2) of this section:

(1) Normal operation. Your source must meet all of the requirements listed in paragraph (a) ofthis section and one of the options listed in paragraphs (e)(1)(i) through (iii) of this section:

(i) Existing source normal operation requirements in paragraph (b) of this section.

(ii) New source normal operation requirements in paragraph (c)(1) of this section.

(iii) Normal operation requirements for sources that have been significantly modified inparagraph (d)(1) of this section.

(2) Malfunction period. Throughout the malfunction period, you must meet all of therequirements listed in paragraph (a) of this section and Table 1 of this section for sourcesoperating during a malfunction period. At the end of the malfunction period, your source mustthen meet all of the requirements listed in table 1 of this section for sources under normaloperation. Table 1 of this section follows:

Table 1 of §63.2850-ReQuirements for Compliance with HAP Emission Standards

For periods of For initial startup periodsnormal subject to §63.2850(c)(2) or For malfunction periods

Are you required to ... operation? (d)(2)? subject to §63.2850(e)(2)?

(a) Operate and maintain Yes. Yes, you are required to Yes, you are required to~our source in accordance Additionally, minimize emissions to the minimizwe emissions to thewith general duty the HAP extent practible throughout the extent practible throughout'provisions of §63.6(e)? emission limits initial startup period. Such the initial startup period.

will apply. measures should be described Such measures should bein the SSM plan. described in the SSM plan.

(b) Determine and record Yes, as Yes, as described in Yes, as described initheextraction solvent loss described in §63.2862(e) §63.2862(e).in gallons from your §63.2853source?

(c) Record the volume Yes Yes Yes.fraction of HAP present atgreater than 1 percent bylvolume and gallons ofextraction solvent inshipment received?

(d) Determine and record Yes, as ~o IN"0.ithe tons of each oilseed described in~ype processed by your §63.2855source?

8-10



(e) Determine the Yes 1N0. Except for solvent received1N0, the HAP volumeweighted average volume by a new or reconstructed fraction in any solventfraction of HAP in source commencing operation received during aextraction solvent received under an initial startup period, malfunction period isas described in §63.2854 ~he HAP volume fraction in included in the weightedby the end of the following any solvent received during an average HAP determinationcalendar month? initial startup period is included for the next operating

in the weighted average HAP month.determination for the nextoperating month

(f) Determine and record Yes, 1N0, these requirements are not 1N0, these requirements arehe actual solvent loss, applicable because your source not applicable because your

weighted average volume is not required to determine the source is not required tofraction HAP, oilseed compliance ratio with data determine the complianceIprocessed and compliance recorded for an initial startup ratio with data recorded forratio for each 12 operating lPeriod a malfunction period.month period as describedin §63.2840 by the end ofthe following calendarmonth?

(g) Submit a Notification Yes, as 1N0. However, you may be 1N0. However, you may beof Compliance Status or described in required to submit an annual equired to submit an annualAnnual Compliance §§63.2860(d) compliance certification for compliance certification forCertification as and 63.2861(a) previous operating months, if previous operating months,appropriate? ~he deadline for the annual if the deadline for the

compliance certification annual compliancehappens to occur during the certification happens toinitial startup period occur during the

malfunction period.

(h) Submit a Deviation Yes 1N0, these requirements are not No, these requirements areNotification Report by the applicable because your source not applicable because yourend of the calendar month is not required to determine the source is not required tofollowing the month in compliance ratio with data determine the compliance[whichyou determined that recorded for an initial startup ratio with data recorded forithe compliance ratio period a malfunction period.exceeds 1.00 as describedin §63.2861(b)?

(i) Submit a Periodic SSM 1N0, a SSM Yes Yes.Report as described in activity is not§63.2861(c)? categorized as

B-11



normaloperation

G) Submit an Immediate lNo, a SSM Yes, only if your source does Yes, only if your sourceSSM Report as described activity is not not follow the SSM plan does not follow the SSMin §63.2861 (d)? categorized as plan.

normaloperation

Table 2 of §63.2850-Schedules for Demonstrating Compliance Under Various Source() t· nn d'pera mg o es

You must determineyour first compliance

and is then your ratio by the end of the Base your first complianceIf your source is operating recordkeeping calendar month ratio on information

.. . under.. . schedule.. . following. . . recorded. . .

(a) Existing [Normal Begins on the The first 12 operating During the first 12 operatingoperation compliance date months after the months after the compliance

compliance date date.

(b) New (1) Normal Begins on the The first 12 operating During the first 12 operatingoperation startup date of your months after the startup months after the startup date

new source date of the new source of the new source.

(2) An Begins on the The first 12 operating During the first 12 operatinginitial startup date of your months after months after the initialstartup Inew source termination of the startup period, which can last~eriod initial startup period, for up to 6 months.

which can last for up to6 months

(c) Existing or (1) Normal Resumes on the The first operating !During the previous 11new that has operation startup date of the month after the startup operating months prior to thebeen modified source date of the modified significant modification andsignificantly source ~he first operating monthmodified following the initial startup

date of the source.

(2) An Resumes on the The first operating During the 11 operatinginitial startup date of the month after termination months before the significantstartup lmodified source of the initial startup modification and the firstperiod ~eriod, which can last operating month after the

up to 3 months initial startup period.

B-12

[66 FR 19011, Apr. 12, 2001, as amended at 71 FR 20463, Apr. 20, 2006]

§ 63.2851 What is a plan for demonstrating compliance?

(a) You must develop and implement a written plan for demonstrating compliance that providesthe detailed procedures you will follow to monitor and record data necessary for demonstratingcompliance with this subpart. Procedures followed for quantifying solvent loss from the sourceand amount of oilseed processed vary from source to source because of site-specific factorssuch as equipment design characteristics and operating conditions. Typical procedures includeone or more accurate measurement methods such as weigh scales, volumetric displacement,and material mass balances. Because the industry does not have a uniform set of procedures,you must develop and implement your own site-specific plan for demonstrating compliancebefore the compliance date for your source. You must also incorporate the plan fordemonstrating compliance by reference in the source's title V permit and keep the plan on-siteand readily available as long as the source is operational. If you make any changes to the planfor demonstrating compliance, then you must keep all previous versions of the plan and makethem readily available for inspection for at least 5 years after each revision. The plan fordemonstrating compliance must include the items in paragraphs (a)(1) through (7) of thissection:

(1) The name and address of the owner or operator.

(2) The physical address of the vegetable oil production process.

(3) A detailed description of all methods of measurement your source will use to determineyour solvent losses, HAP content of solvent, and the tons of each type of oilseed processed.

(4) When each measurement will be made.

(5) Examples of each calculation you will use to determine your compliance status. Includeexamples of how you will convert data measured with one parameter to other terms for use incompliance determination.

(6) Example logs of how data will be recorded.

(7) A plan to ensure that the data continue to meet compliance demonstration needs.

(b) The responsible agency of these NESHAP may require you to revise your plan fordemonstrating compliance. The responsible agency may require reasonable revisions if theprocedures lack detail, are inconsistent or do not accurately determine solvent loss, HAPcontent of the solvent, or the tons of oilseed processed.

§ 63.2852 What is a startup, shutdown, and malfunction plan?

You must develop a written SSM plan in accordance with §63.6(e)(3). You must complete theSSM plan before the compliance date for your source. You must also keep the SSM plan on-

B-13

site and readily available as long as the source is operational. The SSM plan provides detailedprocedures for operating and maintaining your source to minimize emissions during aqualifying SSM event for which the source chooses the §63.2850(e)(2) malfunction period, orthe §63.2850(c)(2) or (d)(2) initial startup period. The SSM plan must specify a program ofcorrective action for malfunctioning process and air pollution control equipment and reflect thebest practices now in use by the industry to minimize emissions. Some or all of the proceduresmay come from plans you developed for other purposes such as a Standard OperatingProcedure manual or an Occupational Safety and Health Administration Process SafetyManagement plan. To qualify as a SSM plan, other such plans must meet all the applicablerequirements of these NESHAP.

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

§ 63.2853 How do I determine the actual solvent loss?

By the end of each calendar month following an operating month, you must determine the totalsolvent loss in gallons for the previous operating month. The total solvent loss for an operatingmonth includes all solvent losses that occur during normal operating periods within theoperating month. If you have determined solvent losses for 12 or more operating months, thenyou must also determine the 12 operating months rolling sum of actual solvent loss in gallonsby summing the monthly actual solvent loss for the previous 12 operating months. The 12operating months rolling sum of solvent loss is the "actual solvent loss," which is used tocalculate your compliance ratio as described in §63.2840.

(a) To determine the actual solvent loss from your source, follow the procedures in your planfor demonstrating compliance to determine the items in paragraphs (a)(1) through (7) of thissection:

(1) The dates that define each operating status period during a calendar month. The dates thatdefine each operating status period include the beginning date of each calendar month and thedate of any change in the source operating status. If the source maintains the same operatingstatus during an entire calendar month, these dates are the beginning and ending dates of thecalendar month. If, prior to the effective date of this rule, your source determines the solventloss on an accounting month, as defined in §63.2872, rather than a calendar month basis, andyou have 12 complete accounting months of approximately equal duration in a calendar year,you may substitute the accounting month time interval for the calendar month time interval. Ifyou choose to use an accounting month rather than a calendar month, you must document thismeasurement frequency selection in your plan for demonstrating compliance, and you mustremain on this schedule unless you request and receive written approval from the agencyresponsible for these NESHAP.

(2) Source operating status. You must categorize the operating status of your source for eachrecorded time interval in accordance with criteria in Table 1 of this section, as follows:

8-14

Table 1 of §63.2853-Categorizing Your Source Operating Status

then your sourceIf during a recorded time interval •.. operating status is ...

(i) Your source processes any amount of listed oilseed and source is not A normal operatingoperating under an initial startup operating period or a malfunction period lPeriod.subject to §63.2850(c)(2), (d)(2), or (e)(2)

(ii) Your source processes no agricultural product and your source is not A nonoperating period.operating under an initial startup period or malfunction period subject to§63.2850(c)(2), (d)(2), or (e)(2)

(iii) You choose to operate your source under an initial startup period subject to An initial startup§63.2850(c)(2) or (d)(2) Iperiod.

(iv) You choose to operate your source under a malfunction period subject to A malfunction period.§63.2850(e)(2)

(v) Your source processes agricultural products not defined as listed oilseed An exempt period.

(3) Measuring the beginning and ending solvent inventory. You are required to measure andrecord the solvent inventory on the beginning and ending dates of each normal operatingperiod that occurs during an operating month. An operating month is any calendar month withat least one normal operating period. You must consistently follow the procedures described inyour plan for demonstrating compliance, as specified in §63.2851 , to determine the extractionsolvent inventory, and maintain readily available records of the actual solvent loss inventory,as described in §63.2862(c)(1). In general, you must measure and record the solvent inventoryonly when the source is actively processing any type of agricultural product. When the sourceis not active, some or all of the solvent working capacity is transferred to solvent storage tankswhich can artificially inflate the solvent inventory.

(4) Gallons of extraction solvent received. Record the total gallons of extraction solventreceived in each shipment. For most processes, the gallons of solvent received representspurchases of delivered solvent added to the solvent storage inventory. However, if yourprocess refines additional vegetable oil from off-site sources, recovers solvent from the off-siteoil, and adds it to the on-site solvent inventory, then you must determine the quantity ofrecovered solvent and include it in the gallons of extraction solvent received.

(5) Solvent inventory adjustments. In some situations, solvent losses determined directly fromthe measured solvent inventory and quantity of solvent received is not an accurate estimate ofthe "actual solvent loss" for use in determining compliance ratios. In such cases, you mayadjust the total solvent loss for each normal operating period as long as you provide areasonable justification for the adjustment. Situations that may require adjustments of the totalsolvent loss include, but are not limited to, situations in paragraphs (a)(5)(i) and (ii) of thissection:

B-15

(i) Solvent destroyed in a control device. You may use a control device to reduce solventemissions to meet the emission standard. The use of a control device does not alter theemission limit for the source. If you use a control device that reduces solvent emissionsthrough destruction of the solvent instead of recovery, then determine the gallons of solventthat enter the control device and are destroyed there during each normal operating period. Allsolvent destroyed in a control device during a normal operating period can be subtracted fromthe total solvent loss. Examples of destructive emission control devices include catalyticincinerators, boilers, or flares. Identify and describe, in your plan for demonstratingcompliance, each type of reasonable and sound measurement method that you use to quantifythe gallons of solvent entering and exiting the control device and to determine the destructionefficiency of the control device. You may use design evaluations to document the gallons ofsolvent destroyed or removed by the control device instead of performance testing under§63.7. The design evaluations must be based on the procedures and options described in§63.985(b)(1)(i)(A) through (C) or §63.11, as appropriate. All data, assumptions, andprocedures used in such evaluations must be documented and available for inspection. If youuse performance testing to determine solvent flow rate to the control device or destructionefficiency of the device, follow the procedures as outlined in §63.997(e)(1) and (2). Instead ofperiodic performance testing to demonstrate continued good operation of the control device,you may develop a monitoring plan, following the procedures outlined in §63.988(c) and usingoperational parametric measurement devices such as fan parameters, percent measurementsof lower explosive limits, and combustion temperature.

(ii) Changes in solvent working capacity. In records you keep on-site, document any processmodifications resulting in changes to the solvent working capacity in your vegetable oilproduction process. Solvent working capacity is defined in §63.2872. In general, solventworking capacity is the volume of solvent normally retained in solvent recovery equipmentsuch as the extractor, desolventizer-toaster, solvent storage, working tanks, mineral oilabsorber, condensers, and oil/solvent distillation system. If the change occurs during a normaloperating period, you must determine the difference in working solvent volume and make aone-time documented adjustment to the solvent inventory.

(b) Use Equation 1 of this section to determine the actual solvent loss occurring from youraffected source for all normal operating periods recorded within a calendar month. Equation 1of this section follows:

(gal)

Monthly Actual

Solvent '"~)SOLV.B - SOLVE + SOL~± SOLVA)ii.l

Where:

(Eq. 1)

SOlVa= Gallons of solvent in the inventory at the beginning of normal operating period "i" asdetermined in paragraph (a)(3) of this section.

SOLVE= Gallons of solvent in the inventory at the end of normal operating period "i" asdetermined in paragraph (a)(3) of this section.

8-16

SOLVR= Gallons of solvent received between the beginning and ending inventory dates ofnormal operating period "i" as determined in paragraph (a)(4) of this section.

SOLVA= Gallons of solvent added or removed from the extraction solvent inventory duringnormal operating period "i" as determined in paragraph (a)(5) of this section.

n = Number of normal operating periods in a calendar month.

(c) The actual solvent loss is the total solvent losses during normal operating periods for theprevious 12 operating months. You determine your actual solvent loss by summing themonthly actual solvent losses for the previous 120perating months. You must record theactual solvent loss by the end of each calendar month following an operating month. Use theactual solvent loss in Equation 2 of §63.2840 to determine the compliance ratio. Actual solventloss does not include losses that occur during operating status periods listed in paragraphs(c)(1) through (4) of this section. If anyone of these four operating status periods span anentire month, then the month is treated as nonoperating and there is no compliance ratiodetermination.

(1) Nonoperating periods as described in paragraph (a)(2)(ii) of this section.

(2) Initial startup periods as described in §63.2850(c)(2) or (d)(2).

(3) Malfunction periods as described in §63.2850(e)(2).

(4) Exempt operation periods as described in paragraph (a)(2)(v) of this section.

§ 63.2854 How do I determine the weighted average volume fraction of HAP in theactual solvent loss?

(a) This section describes the information and procedures you must use to determine theweighted average volume fraction of HAP in extraction solvent received for use in yourvegetable oil production process. By the end of each calendar month following an operatingmonth, determine the weighted average volume fraction of HAP in extraction solvent receivedsince the end of the previous operating month. If you have determined the monthly weightedaverage volume fraction of HAP in solvent received for 12 or more operating months, then alsodetermine an overall weighted average volume fraction of HAP in solvent received for theprevious 12 operating months. Use the volume fraction of HAP determined as a 12 operatingmonths weighted average in Equation 2 of §63.2840 to determine the compliance ratio.

(b) To determine the volume fraction of HAP in the extraction solvent determined as a 12operating months weighted average, you must comply with paragraphs (b)(1) through (3) ofthis section:

(1) Record the volume fraction of each HAP comprising more than 1 percent by volume of thesolvent in each delivery of solvent, including solvent recovered from off-site oil. To determinethe HAP content of the material in each delivery of solvent, the reference method is EPA

B-17

Method 311 of appendix A of this part. You may use EPA Method 311, an approved alternativemethod, or any other reasonable means for determining the HAP content. Other reasonablemeans of determining HAP content include, but are not limited to, a material safety data sheetor a manufacturer's certificate of analysis. A certificate of analysis is a legal and bindingdocument provided by a solvent manufacturer. The purpose of a certificate of analysis is to listthe test methods and analytical results that determine chemical properties of the solvent andthe volume percentage of all HAP components present in the solvent at quantities greater than1 percent by volume. You are not required to test the materials that you use, but theAdministrator may require a test using EPA Method 311 (or an approved alternative method) toconfirm the reported HAP content. However, if the results of an analysis by EPA Method 311are different from the HAP content determined by another means, the EPA Method 311 resultswill govern compliance determinations.

(2) Determine the weighted average volume fraction of HAP in the extraction solvent eachoperating month. The weighted average volume fraction of HAP for an operating monthincludes all solvent received since the end of the last operating month, regardless of theoperating status at the time of the delivery. Determine the monthly weighted average volumefraction of HAP by summing the products of the HAP volume fraction of each delivery and thevolume of each delivery and dividing the sum by the total volume of all deliveries as expressedin Equation 1 of this section. Record the result by the end of each calendar month following anoperating month. Equation 1 of this section follows:

Monthly Weighted If

A H.AP C 2:(Receive~ * Contf3n4)wragf3 ontent "" ..::.;i-;.:;..l _

of Extracti on Solvent Total Received

(volume fraction)

Where:

(Eq. 1)

Recelved> Gallons of extraction solvent received in delivery "i."

Content> The volume fraction of HAP in extraction solvent delivery "i."

Total Received = Total gallons of extraction solvent received since the end of the previousoperating month.

n = Number of extraction solvent deliveries since the end of the previous operating month.

(3) Determine the volume fraction of HAP in your extraction solvent as a 12 operating monthsweighted average. When your source has processed oilseed for 12 operating months, sum theproducts of the monthly weighted average HAP volume fraction and corresponding volume ofsolvent received, and divide the sum by the total volume of solvent received for the 12operating months, as expressed by Equation 2 of this section. Record the result by the end ofeach calendar month following an operating month and use it in Equation 2 of §63.2840 todetermine the compliance ratio. Equation 2 of this section follows:

B-18

12...JY.t:onth Weighted U

A f U.I\net ""(Receive~* Conten4)verage O.Q...MJ;' on ent .(....1... l-

in Solvent Received Total Received

(volumefraction)

Where:

(Eq.2)

Recelved> Gallons of extraction solvent received in operating month "i" as determined inaccordance with §63.2853(a)(4).

Contents- Average volume fraction of HAP in extraction solvent received in operating month "i"as determined in accordance with paragraph (b)(1) of this section.

Total Received =Total gallons of extraction solvent received during the previous 12 operatingmonths.

§ 63.2855 How do I determine the quantity of oilseed processed?

All oilseed measurements must be determined on an as received basis, as defined in§63.2872. The as received basis refers to the oilseed chemical and physical characteristics asinitially received by the source and prior to any oilseed handling and processing. By the end ofeach calendar month following an operating month, you must determine the tons as receivedof each listed oilseed processed for the operating month. The total oilseed processed for anoperating month includes the total of each oilseed processed during all normal operatingperiods that occur within the operating month. If you have determined the tons of oilseedprocessed for 12 or more operating months, then you must also determine the 12 operatingmonths rolling sum of each type oilseed processed by summing the tons of each type ofoilseed processed for the previous 12 operating months. The 12 operating months rolling sumof each type of oilseed processed is used to calculate the compliance ratio as described in§63.2840.

(a) To determine the tons as received of each type of oilseed processed at your source, followthe procedures in your plan for demonstrating compliance to determine the items inparagraphs (a)(1) through (5) of this section:

(1) The dates that define each operating status period. The dates that define each operatingstatus period include the beginning date of each calendar month and the date of any change inthe source operating status. If, prior to the effective date of this rule, your source determinesthe oilseed inventory on an accounting month rather than a calendar month basis, and youhave 12 complete accounting months of approximately equal duration in a calendar year, youmay substitute the accounting month time interval for the calendar month time interval. If youchoose to use an accounting month rather than a calendar month, you must document thismeasurement frequency selection in your plan for demonstrating compliance, and you mustremain on this schedule unless you request and receive written approval from the agency

B-19

responsible for these NESHAP. The dates on each oilseed inventory log must be consistentwith the dates recorded for the solvent inventory.

(2) Source operating status. You must categorize the source operation for each recorded timeinterval. The source operating status for each time interval recorded on the oilseed inventoryfor each type of oilseed must be consistent with the operating status recorded on the solventinventory logs as described in §63.2853(a)(2).

(3) Measuring the beginning and ending inventory for each oilseed. You are required tomeasure and record the oilseed inventory on the beginning and ending dates of each normaloperating period that occurs during an operating month. An operating month is any calendarmonth with at least one normal operating period. You must consistently follow the proceduresdescribed in your plan for demonstrating compliance, as specified in §63.2851, to determinethe oilseed inventory on an as received basis and maintain readily available records of theoilseed inventory as described by §63.2862(c)(3).

(4) Tons ofeach oilseed received. Record the type of oilseed and tons of each shipment ofoilseed received and added to your on-site storage.

(5) Oilseed inventory adjustments. In some situations, determining the quantity of oilseedprocessed directly from the measured oilseed inventory and quantity of oilseed received is notan accurate estimate of the tons of oilseed processed for use in determining compliance ratios.For example, spoiled and molded oilseed removed from storage but not processed by yoursource will result in an overestimate of the quantity of oilseed processed. In such cases, youmust adjust the oilseed inventory and provide a justification for the adjustment. Situations thatmay require oilseed inventory adjustments include, but are not limited to, the situations listed inparagraphs (a)(5)(i) through (v) of this section:

(i) Oilseed that mold or otherwise become unsuitable for processing.

(ii) Oilseed you sell before it enters the processing operation.

(iii) Oilseed destroyed by an event such as a process malfunction, fire, or natural disaster.

(iv) Oilseed processed through operations prior to solvent extraction such as screening,dehulling, cracking, drying, and conditioning; but that are not routed to the solvent extractor forfurther processing.

(v) Periodic physical measurements of inventory. For example, some sources periodicallyempty oilseed storage silos to physically measure the current oilseed inventory. This periodicmeasurement procedure typically results in a small inventory correction. The correction factor,usually less than 1 percent, may be used to make an adjustment to the source's oilseedinventory that was estimated previously with indirect measurement techniques. To make thisadjustment, your plan for demonstrating compliance must provide for such an adjustment.

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(b) Use Equation 1 of this section to determine the quantity of each oilseed type processed atyour affected source during normal operating periods recorded within a calendar month.Equation 1 of this section follows:

Monthly Quantity

of Each Oilseed ...!(SEEDB - SEEDg +SEEDR ±SEEDA)

Processed (tons) ",-1

Where:

(Eq, 1)

SEEDs= Tons of oilseed in the inventory at the beginning of normal operating period "i" asdetermined in accordance with paragraph (a)(3) of this section.

SEEDE= Tons of oilseed in the inventory at the end of normal operating period "l" asdetermined in accordance with paragraph (a)(3) of this section.

SEEDR= Tons of oilseed received during normal operating period "i" as determined inaccordance with paragraph (a)(4) of this section.

SEEDA= Tons of oilseed added or removed from the oilseed inventory during normal operatingperiod "i" as determined in accordance with paragraph (a)(5) of this section.

n = Number of normal operating periods in the calendar month during which this type oilseedwas processed.

(c) The quantity of each oilseed processed is the total tons of each type of listed oilseedprocessed during normal operating periods in the previous 12 operating months. Youdetermine the tons of each oilseed processed by summing the monthly quantity of eachoilseed processed for the previous 12 operating months. You must record the 12 operatingmonths quantity of each type of oilseed processed by the end of each calendar monthfollowing an operating month. Use the 12 operating months quantity of each type of oilseedprocessed to determine the compliance ratio as described in §63.2840. The quantity of oilseedprocessed does not include oilseed processed during the operating status periods inparagraphs (c)(1) through (4) of this section:

(1) Nonoperating periods as described in §63.2853 (a)(2)(ii).

(2) Initial startup periods as described in §63.2850(c)(2) or (d)(2).

(3) Malfunction periods as described in §63.2850(e)(2).

(4) Exempt operation periods as described in §63.2853 (a)(2)(v).

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(5) If anyone of these four operating status periods span an entire calendar month, then thecalendar month is treated as a nonoperating month and there is no compliance ratiodetermination.

Notifications, Reports, and Records

§ 63.2860 What notifications must I submit and when?

You must submit the one-time notifications listed in paragraphs (a) through (d) of this sectionto the responsible agency:

(a) Initial notification for existing sources. For an existing source, submit an initial notification tothe agency responsible for these NESHAP no later than 120 days after the effective date ofthis subpart. In the notification, include the items in paragraphs (a)(1) through (5) of thissection:



(3) Identification of the relevant standard, such as the vegetable oil production NESHAP, andcompliance date.

(4) A brief description of the source including the types of listed oilseeds processed, nominaloperating capacity, and type of desolventizer(s) used.

(5) A statement designating the source as a major source of HAP or a demonstration that thesource meets the definition of an area source. An area source is a source that is not a majorsource and is not collocated within a plant site with other sources that are individually orcollectively a major source.

(b) Initial notifications for new and reconstructed sources. New or reconstructed sources mustsubmit a series of notiflcations.before, during, and after source construction per the schedulelisted in §63.9. The information requirements for the notifications are the same as those listedin the General Provisions with the exceptions listed in paragraphs (b)(1) and (2) of this section:

(1) The application for approval of construction does not require the specific HAP emissiondata required in §63.5(d)(1 )(ii)(H) and (iii), (d)(2) and (d)(3)(ii). The application for approval ofconstruction would include, instead, a brief description of the source including the types oflisted oilseeds processed, nominal operating capacity, and type of desolventizer(s) used.

(2) The notification of actual startup date must also include whether you have elected tooperate under an initial startup period subject to §63.2850(c)(2) and provide an estimate andjustification for the anticipated duration of the initial startup period.

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(c) Significant modification notifications. Any existing or new source that plans to undergo asignificant modification as defined in §63.2872 must submit two reports as described inparagraphs (c)(1) and (2) of this section:

(1) Initial notification. You must submit an initial notification to the agency responsible for theseNESHAP 30 days prior to initial startup of the significantly modified source. The initialnotification must demonstrate that the proposed changes qualify as a significant modification.The initial notification must include the items in paragraphs (c)(1)(i) and (ii) of this section:

(i) The expected startup date of the modified source.

(ii) A description of the significant modification including a list of the equipment that will bereplaced or modified. If the significant modification involves changes other than adding orreplacing extractors, desolventizer-toasters (conventional and specialty), and meal dryercoolers, then you must also include the fixed capital cost of the new components, expressedas a percentage of the fixed capital cost to build a comparable new vegetable oil productionprocess; supporting documentation for the cost estimate; and documentation that the proposedchanges will significantly affect solvent losses.

(2) Notification of actual startup. You must submit a notification of actual startup date within 15days after initial startup of the modified source. The notification must include the items inparagraphs (c)(2)(i) through (iv) of this section:

(i) The initial startup date of the modified source.

(ii) An indication whether you have elected to operate under an initial startup period subject to§63.2850(d)(2).

(iii) The anticipated duration of any initial startup period.

(iv) A justification for the anticipated duration of any initial startup period.

(d) Notification of compliance status. As an existing, new, or reconstructed source, you mustsubmit a notification of compliance status report to the responsible agency no later than 60days after determining your initial 12 operating months compliance ratio. If you are an existingsource, you generally must submit this notification no later than 50 calendar months after theeffective date of these NESHAP (36 calendar months for compliance, 12 operating months torecord data, and 2 calendar months to complete the report). If you are a new or reconstructedsource, the notification of compliance status is generally due no later than 20 calendar monthsafter initial startup (6 calendar months for the initial startup period, 12 operating months torecord data, and 2 calendar months to complete the report). The notification of compliancestatus must contain the items in paragraphs (d)(1) through (6) of this section:



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(3) Each listed oilseed type processed during the previous 12 operating months.

(4) Each HAP identified under §63.2854(a) as being present in concentrations greater than 1percent by volume in each delivery of solvent received during the 12 operating months periodused for the initial compliance determination.

(5) A statement designating the source as a major source of HAP or a demonstration that thesource qualifies as an area source. An area source is a source that is not a major source andis not collocated within a plant site with other sources that are individually or collectively amajor source.

(6) A compliance certification indicating whether the source complied with all of therequirements of this subpart throughout the 12 operating months used for the initial sourcecompliance determination. This certification must include a certification of the items inparagraphs (d)(6)(i) through (iii) of this section:

(i) The plan for demonstrating compliance (as described in §63.2851) and SSM plan (asdescribed in §63.2852) are complete and available on-site for inspection.

(ii) You are following the procedures described in the plan for demonstrating compliance.

(iii) The compliance ratio is less than or equal to 1.00.

§ 63.2861 What reports must I submit and when?

After the initial notifications, you must submit.the reports in paragraphs (a) through (d) of thissection to the agency responsible for these NESHAP at the appropriate time intervals:

(a) Annual compliance certifications. The first annual compliance certification is due 12calendar months after you submit the notification of compliance status. Each subsequentannual compliance certification is due 12 calendar months after the previous annualcompliance certification. The annual compliance certification provides the compliance statusfor each operating month during the 12 calendar months period ending 60 days prior to thedate on which the report is due. Include the information in paragraphs (a)(1) through (6) of thissection in the annual certification:



(3) Each listed oilseed type processed during the 12 calendar months period covered by thereport.

(4) Each HAP identified under §63.2854(a) as being present in concentrations greater than 1percent by volume in each delivery of solvent received during the 12 calendar months periodcovered by the report.

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(5) A statement designating the source as a major source of HAP or a demonstration that thesource qualifies as an area source. An area source is a source that is not a major source andis not collocated within a plant site with other sources that are individually or collectively amajor source.

(6) A compliance certification to indicate whether the source was in compliance for eachcompliance determination made during the 12 calendar months period covered by the report.For each such compliance determination, you must include a certification of the items inparagraphs (a)(6)(i) through (ii) of this section:

(i) You are following the procedures described in the plan for demonstrating compliance.

(ii) The compliance ratio is less than or equal to 1.00.

(b) Deviation notification report. Submit a deviation report for each compliance determinationyou make in which the compliance ratio exceeds 1.00 as determined under §63.2840(c).Submit the deviation report by the end of the month following the calendar month in which youdetermined the deviation. The deviation notification report must include the items inparagraphs (b)(1) through (4) of this section:



(3) Each listed oilseed type processed during the 12 operating months period for which youdetermined the deviation.

(4) The compliance ratio comprising the deviation. You may reduce the frequency of submittalof the deviation notification report if the agency responsible for these NESHAP does not objectas provided in §63.10(e)(3)(iii).

(c) Periodic startup, shutdown, and malfunction report. If you choose to operate your sourceunder an initial startup period subject to §63.2850(c)(2) or (d)(2) or a malfunction periodsubject to §63.2850(e)(2), you must submit a periodic SSM report by the end of the calendarmonth following each month in which the initial startup period or malfunction period occurred.The periodic SSM report must include the items in paragraphs (c)(1) through (3) of this section:

(1) The name, title, and signature of a source's responsible official who is certifying that thereport accurately states that all actions taken during the initial startup or malfunction periodwere consistent with the SSM plan.

(2) A description of events occurring during the time period, the date and duration of theevents, and reason the time interval qualifies as an initial startup period or malfunction period.

(3) An estimate of the solvent loss during the initial startup or malfunction period withsupporting documentation.

B-25

(d) Immediate SSM reports. If you handle a SSM during an initial startup period subject to§63.2850(c)(2) or (d)(2) or a malfunction period subject to §63.2850(e)(2) differently fromprocedures in the SSM plan and the relevant emission requirements in §63.2840 areexceeded, then you must submit an immediate SSM report. Immediate SSM reports consist ofa telephone call or facsimile transmission to the responsible agency within 2 working days afterstarting actions inconsistent with the SSM plan, followed by a letter within 7 working days afterthe end of the event. The letter must include the items in paragraphs (d)(1) through (3) of thissection:

(1) The name, title, and signature of a source's responsible official who is certifying theaccuracy of the report, an explanation of the event, and the reasons for not following the SSMplan.

(2) A description and date of the SSM event, its duration, and reason it qualifies as a SSM.

(3) An estimate of the solvent loss for the duration of the SSM event with supportingdocumentation.

[66 FR 19011, Apr. 12,2001, as amended at 67 FR 16321, Apr. 5, 2002]

§ 63.2862 What records must I keep?

(a) You must satisfy the recordkeeping requirements of this section by the compliance date foryour source specified in Table 1 of §63.2834.

(b) Prepare a plan for demonstrating compliance (as described in §63.2851) and a SSM plan(as described in §63.2852). In these two plans, describe the procedures you will follow inobtaining and recording data, and determining compliance under normal operations or a SSMsubject to the §63.2850(c)(2) or (d)(2) initial startup period or the §63.2850(e)(2) malfunctionperiod. Complete both plans before the compliance date for your source and keep them on-siteand readily available as long as the source is operational.

(c) If your source processes any listed oilseed, record the items in paragraphs (c)(1) through(5) of this section:

(1) For the solvent inventory, record the information in paragraphs (c)(1)(i) through (vii) of thissection in accordance with your plan for demonstrating compliance:

(i) Dates that define each operating status period during a calendar month.

(ii) The operating status of your source such as normal operation, nonoperating, initial startupperiod, malfunction period, or exempt operation for each recorded time interval.

(iii) Record the gallons of extraction solvent in the inventory on the beginning and ending datesof each normal operating period.

B-26

(iv) The gallons of all extraction solvent received, purchased, and recovered during eachcalendar month.

(v) All extraction solvent inventory adjustments, additions or subtractions. You must documentthe reason for the adjustment and justify the quantity of the adjustment.

(vi) The total solvent loss for each calendar month, regardless of the source operating status.

(vii) The actual solvent loss in gallons for each operating month.

(2) For the weighted average volume fraction of HAP in the extraction solvent, you must recordthe items in paragraphs (c)(2)(i) through (iii) of this section:

(i) The gallons of extraction solvent received in each delivery.

(ii) The volume fraction of each HAP exceeding 1 percent by volume in each delivery ofextraction solvent.

(iii) The weighted average volume fraction of HAP in extraction solvent received since the endof the last operating month as determined in accordance with §63.2854(b)(2).

(3) For each type of listed oilseed processed, record the items in paragraphs (c)(3)(i) through(vi) of this section, in accordance with your plan for demonstrating compliance:

(i) The dates that define each operating status period. These dates must be the same as thedates entered for the extraction solvent inventory.

(ii) The operating status of your source such as normal operation, nonoperating, initial startupperiod, malfunction period, or exempt operation for each recorded time interval. On the log foreach type of listed oilseed that is not being processed during a normal operating period, youmust record which type of listed oilseed is being processed in addition to the source operatingstatus.

(iii) The oilseed inventory for the type of listed oilseed being processed on the beginning andending dates of each normal operating period.

(iv) The tons of each type of listed oilseed received at the affected source each normaloperating period.

(v) All listed oilseed inventory adjustments, additions or subtractions for normal operatingperiods. You must document the reason for the adjustment and justify the quantity of theadjustment.

(vi) The tons of each type of listed oilseed processed during each operating month.

B-27

(d) After your source has processed listed oilseed for 12 operating months, and you are notoperating during an initial startup period as described in §63.2850(c)(2) or (d)(2), or amalfunction period as described in §63.2850(e)(2), record the items in paragraphs (d)(1)through (5) of this section by the end of the calendar month following each operating month:

(1) The 12 operating months rolling sum of the actual solvent loss in gallons as described in§63.2853(c).

(2) The weighted average volume fraction of HAP in extraction solvent received for theprevious 12 operating months as described in §63.2854(b)(3).

(3) The 12 operating months rolling sum of each type of listed oilseed processed at theaffected source in tons as described in §63.2855(c).

(4) A determination of the compliance ratio. Using the values from §§63.2853, 63.2854,63.2855, and Table 1 of §63.2840, calculate the compliance ratio using Equation 2 of§63.2840.

(5) A statement of whether the source is in compliance with all of the requirements of thissubpart. This includes a determination of whether you have met all of the applicablerequirements in §63.2850.

(e) 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(e)(1) through (3) of this section by the end of the calendar month following each month inwhich the initial startup period or malfunction period occurred:

(1) A description and date of the SSM event, its duration, and reason it qualifies as an initialstartup or malfunction.

(2) An estimate of the solvent loss in gallons for the duration of the initial startup or malfunctionperiod with supporting documentation.

(3) A checklist or other mechanism to indicate whether the SSM plan was followed during theinitial startup or malfunction period.

§ 63.2863 In what form and how long must I keep my records?

(a) Your records must be in a form suitable and readily available for review in accordance with§63.10(b)(1).

(b) As specified in §63.10(b)(1), you must keep each record for 5 years following the date ofeach occurrence, measurement, maintenance, corrective action, report, or record.

B-28

(c) You must keep each record on-site for at least 2 years after the date of each occurrence,measurement, maintenance, corrective action, report, or record, in accordance with§3.10(b)(1). You can keep the records oft-site for the remaining 3 years.

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 63.15apply to you. Table 1 of §63.2870 follows:

Table 1 of §63.2870-Applicability of 40 CFR Part 63, Subpart A, to 40 CFR, Part 63,S b rtGGGGu tpa

AppliesGeneral provisions Brief description of to

citation Subject of citation requirement subpart Explanation

§63.l Applicability Initial applicability Yesdetermination;applicability afterstandard established;Ipennit requirements;extensions;notifications

§63.2 lDefinitions Definitions for part Yes Except as specifically63 standards IProvided in this

subpart.

§63.3 Units and abbreviations Units and Yesabbreviations for part63 standards

§63.4 Prohibited activities and Prohibited activities; Yescircumvention compliance date;

circumvention;severability

§63.5 Construction/reconstruction Applicability; Yes Except for subsectionsapplications; of §63.5 as listedapprovals below.

§63.5(c) [Reserved]

§63.5(d)(1)(ii)(H) Application for approval Type and quantity of lNo All sources emit HAP.HAP, operating Subpart GGGG doeslParameters riot require control

from specific emission[points.

8-29



§63.5(d)(1)(ii)(I) [Reserved]

§63.5(d)(l )(iii), Application for 1N0 The requirements of(d)(2), (d)(3)(ii) approval the application for

approval for new,reconstructed andsignificantly modifiedsources are describedin §63.2860(b) and (c)of subpart GGGG.General provisionrequirements foridentification of HAPemission points orestimates of actualemissions are notequired. Descriptions

of control andmethods, and theestimated and actualcontrol efficiency ofsuch do not apply.Requirements fordescribing controlequipment and theestimated and actualcontrol efficiency ofsuch equipment applyonly to controlequipment to which thesubpart GGGGrequirements forquantifying.

§63.6 lApplicability of General Applicability Yes Except for subsectionsIProvisions of §63.6 as listed

below.

§63.6(b)(1)-(3) Compliance dates, new and 1N0 Section 63.2834 ofreconstructed sources subpart GGGG

specifies thecompliance dates fornew and reconstructedsources.

8-30



§63.6(b)(6) [Reserved]

§63.6(c)(3)-{4) [Reserved]

§63.6(d) [Reserved]

§63.6(e)(1) through Operation and maintenance Yes Minimize emissions to(e)(3)(ii) and requirements ~he extent practical.§63.6(e)(3)(v)hrough (vii)

§63.6(e)(3)(iii) Operation and maintenance [No Minimize emissions torequirements he extent practical

§63.6(e)(3)(iv) Operation and maintenance No Report SSM and inrequirements accordance with

§63.2861(c) and (d).

§63.6(e)(3)(viii) Operation and maintenance Yes Except, report eachrequirements revision to your SSM

plan in accordancewith §63.2861(c)rather than§63.l0(d)(5) asrequired under§63.6(e)(3) (viii).

§63.6(e)(3)(ix) Title V permit Yes

§63.6(t)-(g) Compliance with nonopacity Comply with lNo Subpart GGGG doesemission standards except emission standards at not have nonopacityduring SSM all times except requirements.

during SSM

§63.6(h) OpacityNisible emission !No Subpart GGGG has no(VE) standards opacity or VE

standards.

§63.6(i) Compliance extension Procedures and Yescriteria forresponsible agency togrant complianceextension

§63.60) Presidential compliance President may Yesexemption exempt source

category from

B-31



requirement tocomply with subpart

§63.7 Performance testing Schedule, conditions, Yes Subpart GGGGrequirements notifications and requires performance

procedures esting only if thesource appliesadditional control thatdestroys solvent.Section 63.2850(a)(6)Irequires sources tofollow the performancetesting guidelines ofIthe General Provisionsif a control is added.

§63.8 Monitoring requirements ~o Subpart GGGG doesnot require monitoringother than as specifiedtherein.

§63.9 1N0tificationrequirements Applicability and Yes Except for subsectionsstate delegation of §63.9 as listed

below.

§63.9(b)(2) 1N0tificationrequirements Initial notification !No Section 63.2860(a) ofrequirements for subpart GGGGexisting sources specifies the

equirements of theinitial notification forexisting sources.

§63.9(b)(3)-(5) ~otification requirements Notification Yes Except the informationequirement for requirements differ as

certain described innew/reconstructed §63.2860(b) of subpartsources GGGG.

§63.9(e) !Notification of performance Notify responsible Yes [Applies only ifhest agency 60 days lPerformance testing is

ahead !performed.

§63.9(f) !Notification of VE/opacity Notify responsible 1N0 Subpart GGGG has noobservations agency 30 days opacity or VE

ahead standards.

B-32

[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 enforces this subpart?

(a) This subpart can be implemented by us, the U.S. EPA, or a delegated authority such asyour State, local, or tribal agency. If the U.S. EPA Administrator has delegated authority toyour State, local, or tribal agency, then that agency, as well as the U.S. EPA, has the authorityto implement and enforce this subpart. You should contact your U.S. EPA Regional Office tofind out if this subpart is delegated to your State, local, or tribal agency.

(b) In delegating implementation and enforcement authority of this subpart to a State, local, ortribal agency under section 40 CFR part 63, subpart E, the authorities contained in paragraph(c) of this section are retained by the Administrator of the U.S. EPA and are not transferred tothe State, local, or tribal agency.

(c) The authorities that will not be delegated to State, local, or tribal agencies are as follows:

(1) Approval of alternative nonopacity emissions standards under §63.6(g).

(2) Approval of alternative opacity standards under §63.6(h)(9).

(3) Approval of major alternatives to test methods under §63.7(e)(2)(ii) and (f) and as definedin §63.90.

(4) Approval of major alternatives to monitoring under §63.8(f) and as defined in §63.90.

(5) Approval of major alternatives to recordkeeping and reporting under §63.1O(f) and asdefined in §63.90.

§ 63.2872 What definitions apply to this subpart?

Terms used in this subpart are defined in the sources listed:

(a) The Clean Air Act, section 112(a).

(b) In 40 CFR 63.2, the NESHAP General Provisions.

(c) In this section as follows:

Accounting month means a time interval defined by a business firm during which corporateeconomic and financial factors are determined on a consistent and regular basis. Anaccounting month will consist of approximately 4 to 5 calendar weeks and each accountingmonth will be of approximate equal duration. An accounting month may not correspond exactlyto a calendar month, but 12 accounting months will correspond exactly to a calendar year.

B-35

Actual solvent loss means the gallons of solvent lost from a source during 12 operating monthsas determined in accordance with §63.2853.

Agricultural product means any commercially grown plant or plant product.

Allowable HAP loss means the gallons of HAP that would have been lost from a source if thesource was operating at the solvent loss factor for each listed oilseed type. The allowable HAPloss in gallons is determined by multiplying the tons of each oilseed type processed during theprevious 12 operating months, as determined in accordance with §63.2855, by thecorresponding oilseed solvent loss factor (gal/ton) listed in Table 1 of §63.2840, and by thedimensionless constant 0.64, and summing the result for all oilseed types processed.

Area source means any source that does not meet the major source definition.

As received is the basis upon which all oilseed measurements must be determined and refersto the oilseed chemical and physical characteristics as initially received by the source and priorto any oilseed handling and processing.

Batch operation means any process that operates in a manner where the addition of rawmaterial and withdrawal of product do not occur simultaneously. Typically, raw material isadded to a process, operational steps occur, and a product is removed from the process. Moreraw material is then added to the process and the cycle repeats.

Calendar month means 1 month as specified in a calendar.

Compliance date means the date on which monthly compliance recordkeeping begins. Forexisting sources, recordkeeping typically begins 3 years after the effective date of the subpart.For new and reconstructed sources, recordkeeping typically begins upon initial startup, exceptas noted in §63.2834.

Compliance ratio means a ratio of the actual HAP loss in gallons from the previous 12operating months to an allowable HAP loss in gallons, which is determined by using oilseedsolvent loss factors in Table 1 of §63.2840, the weighted average volume fraction of HAP insolvent received for the previous 12 operating months, and the tons of each type of listedoilseed processed in the previous 12 operating months. Months during which no listed oilseedis processed, or months during which the §63.2850(c)(2) or (d)(2) initial startup period or the§63.2850(e)(2) malfunction period applies, are excluded from this calculation. Equation 2 of§63.2840 is used to calculate this value. If the value is less than or equal to 1.00, the source isin compliance. If the value is greater than 1.00, the source is deviating from compliance.

Continuous operation means any process that adds raw material and withdraws productsimultaneously. Mass, temperature, concentration and other properties typically approachsteady-state conditions.

Conventional desolventizer means a desolventizer toaster that operates with indirect anddirect-contact steam to remove solvent from the extracted meal. Oilseeds processed in a

8-36

conventional desolventizer produce crude vegetable oil and crude meal products, such asanimal feed.

Com germ dry milling means a source that processes corn germ that has been separated fromthe other corn components using a "dry" process of mechanical chafing and air sifting.

Com germ wet milling means a source that processes corn germ that has been separated fromother corn components using a "wet" process of centrifuging a slurry steeped in a dilutesulfurous acid solution.

Exempt period means a period of time during which a source processes agricultural productsnot defined as listed oilseed.

Extraction solvent means an organic chemical medium used to remove oil from an oilseed.Typically, the extraction solvent is a commercial grade of hexane isomers which have anapproximate HAP content of 64 percent by volume.

Hazardous air pollutant (HAP) means any substance or mixture of substances listed as ahazardous air pollutant under section 112(b) of the Clean Air Act, as of April 12, 2001.

Initial startup date means the first calendar day that a new, reconstructed or significantlymodified source processes any listed oilseed.

Initial startup period means a period of time from the initial startup date of a new, reconstructedor significantly modified source, for which you choose to operate the source under an initialstartup period subject to §63.2850(c)(2) or (d)(2). During an initial startup period, a sourcecomplies with the standards by minimizing HAP emissions to the extent practical. The initialstartup period following initial startup of a new or reconstructed source may not exceed 6calendar months. The initial startup period following a significant modification may not exceed3 calendar months. Solvent and oilseed inventory information recorded during the initial startupperiod is excluded from use in any compliance ratio determinations.

Large cottonseed plant means a vegetable oil production process that processes 120,000 tonsor more of cottonseed and other listed oilseed during all normal operating periods in a 12operating months period used to determine compliance.

Malfunction period means a period of time between the beginning and end of a processmalfunction and the time reasonably necessary for a source to correct the malfunction forwhich you choose to operate the source under a malfunction period subject to §63.2850(e)(2).This period may include the duration of an unscheduled process shutdown, continuedoperation during a malfunction, or the subsequent process startup after a shutdown resultingfrom a malfunction. During a malfunction period, a source complies with the standards byminimizing HAP emissions to the extent practical. Therefore, solvent and oilseed inventoryinformation recorded during a malfunction period is excluded from use in any compliance ratiodeterminations.

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Mechanical extraction means removing vegetable oil from oilseeds using only mechanicaldevices such as presses or screws that physically force the oil from the oilseed. Mechanicalextraction techniques use no organic solvents to remove oil from an oilseed.

Nonoperating period means any period of time in which a source processes no agriculturalproduct. This operating status does not apply during any period in which the source operatesunder 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).

Normal operating period means any period of time in which a source processes a listed oilseedthat is not categorized as an initial startup period as described in §63.2850(c)(2) or (d)(2), or amalfunction period, as described in §63.2850(e)(2). At the beginning and ending dates of anormal operating period, solvent and oilseed inventory information is recorded and included inthe compliance ratio determination.

Oilseed or listed oilseed means the following agricultural products: corn germ, cottonseed, flax,peanut, rapeseed (for example, canola), safflower, soybean, and sunflower.

Oilseed solvent loss factor means a ratio expressed as gallons of solvent loss per ton ofoilseed processed. The solvent loss factors are presented in Table 1 of §63.2840 and are usedto determine the allowable HAP loss.

Operating month means any calendar or accounting month in which a source processes anyquantity of listed oilseed, excluding any entire calendar or accounting month in which thesource operated under an initial startup period as described in §63.2850(c)(2) or (d)(2), or amalfunction period as described in §63.2850(e)(2). An operating month may include timeintervals characterized by several types of operating status. However, an operating monthmust have at least one normal operating period.

Significant modification means the addition of new equipment or the modification of existingequipment that:

(1) Significantly affects solvent losses from your vegetable oil production process;

(2) The fixed capital cost of the new components represents a significant percentage of thefixed capital cost of building a comparable new vegetable oil production process;

(3) The fixed capital cost of the new equipment does not constitute reconstruction as defined in§63.2; and

(4) Examples of significant modifications include replacement of or major changes to solventrecovery equipment such as extractors, desolventizer-toasters/dryer-coolers, flashdesolventizers, and distillation equipment associated with the mineral oil system, andequipment affecting desolventizing efficiency and steady-state operation of your vegetable oilproduction process such as flaking mills, oilseed heating and conditioning equipment, andcracking mills.

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Small cottonseed plant means a vegetable oil production process that processes less than120,000 tons of cottonseed and other listed oilseed during all normal operating periods in a 12operating months period used to determine compliance.

Solvent extraction means removing vegetable oil from listed oilseed using an organic solvent ina direct-contact system.

Solvent working capacity means the volume of extraction solvent normally retained in solventrecovery equipment. Examples include components such as the solvent extractor,desolventizer-toaster, solvent storage and working tanks, mineral oil absorption system,condensers, and oil/solvent distillation system.

Specialty desolventizer means a desolventizer that removes excess solvent from soybeanmeal using vacuum conditions, energy from superheated solvent vapors, or reduced operatingconditions (e.g., temperature) as compared to the typical operation of a conventionaldesolventizer. Soybeans processed in a specialty desolventizer result in high-protein vegetablemeal products for human and animal consumption, such as calf milk replacement products andmeat extender products.

Vegetable oil production process means the equipment comprising a continuous process forproducing crude vegetable oil and meal products, including specialty soybean products, inwhich oil is removed from listed oilseeds through direct contact with an organic solvent.Process equipment typically includes the following components: oilseed preparation operations(including conditioning, drying, dehulling, and cracking), solvent extractors, desolventizertoasters, meal dryers, meal coolers, meal conveyor systems, oil distillation units, solventevaporators and condensers, solvent recovery system (also referred to as a mineral oilabsorption system), vessels storing solvent-laden materials, and crude meal packaging andstorage vessels. A vegetable oil production process does not include vegetable oil refiningoperations (including operations such as bleaching, hydrogenation, and deodorizing) andoperations that engage in additional chemical treatment of crude soybean meals produced inspecialty desolventizer units (including operations such as soybean isolate production).

[66 FR 19011, Apr. 12, 2001, as amended at 71 FR 20464, Apr. 20, 2006]

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Appendix C

ADEQ Continuous Emission Monitoring SystemsConditions

Arkansas Department of Environmental Quality

CONTINUOUS EMISSION MONITORING SYSTEMSCONDITIONS

Revised August 2004

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PREAMBLE

These conditions are intended to outline the requirements for facilities required to operate Continuous EmissionMonitoring Systems/Continuous Opacity Monitoring Systems (CEMS)/(COMS). Generally there are threetypes 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 that 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 Part60, 63 or 75) shall comply with SECTION II, MONITORING REQUIREMENTS and SECTION IV,QUALITY ASSURANCE/QUALITY CONTROL.

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

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SECTION I

DEFINITIONS

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

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

Calibration Drift (CD) - The difference in the CEMS output reading from the established reference value aftera stated period of operation 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 todetermine gas concentration and/or emission rate. This CEMS is to serve as a back-up to the primary CEMS tominimize 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 aminimum of four evenly spaced data points over an hour, except during one daily zero-span check during whichtwo data points per hour are sufficient.

Out-of-Control Period - Begins with the time corresponding to the completion of the fifth, consecutive, dailyCD check with a CD in excess of two 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 of four times the allowable limitand the time corresponding to the completion of the sampling for the RATA, RAA, or CGA which exceeds thelimits outlined in Section IV. Out-of-Control Period ends with the time corresponding to the completion of theCD check following corrective action with the results being within the allowable CD limit or the completion ofthe sampling of the subsequent successful RATA, RAA, or CGA.

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

Relative Accuracy (RA) - The absolute mean difference between the gas concentration or emission ratedetermined by the CEMS and the value determined by the reference method plus the 2.5 percent errorconfidence coefficient of a series of tests divided by the mean of the reference method tests of the applicableemission limit.

Span Value - The upper limit of a gas concentration measurement range.

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SECTION II

MONITORING REQUIREMENTS

A. For new sources, the installation date for the CEMS/COMS shall be no later than thirty (30) days fromthe date of start-up of the source.

B. For existing sources, the installation date for the CEMS/COMS shall be no later than sixty (60) daysfrom the issuance of the 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 becompleted. PST's are defined in 40 CFR, Part 60, Appendix B, PS 1-9. The Department may acceptalternate PSTs for pollutants not covered by Appendix B on a case-by-case basis. Alternate PST's shallbe 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 adjustedwhenever the 24-hour zero or 24-hour span drift exceeds two times the limits in the applicableperformance specification in 40 CFR, Part 60, Appendix B. Before any adjustments are made to eitherthe zero or span drifts measured at the 24-hour interval the excess zero and span drifts measured must bequantified and recorded.

E. All CEMS/COMS shall be in continuous operation and shall meet minimum frequency of operationrequirements of 95% up-time for each quarter for each pollutant measured. Percent of monitor downtime is calculated by dividing the total minutes the monitor is not in operation by the total time in thecalendar quarter and multiplying by one hundred. Failure to maintain operation time shall constitute aviolation of the CEMS conditions.

F. Percent of excess emissions are calculated by dividing the total minutes of excess emissions by the totaltime the source operated and multiplying by one hundred. Failure to maintain compliance mayconstitute a violation of the CEMS conditions.

F. All CEMS measuring emissions shall complete a minimum of one cycle of operation (sampling,analyzing, and data recording) for each successive fifteen minute period unless more cycles are requiredby the permit. For each CEMS, one-hour averages shall be computed from four or more data pointsequally spaced over each one hour period unless more data points are required by the permit.

H. All COMS shall complete a minimum of one cycle of sampling and analyzing for each successive 10second period and one cycle of data recording for each successive 6-minute period.

1. When the pollutant from a single affected facility is released through more than one point, aCEMS/COMS shall be installed on each point unless installation of fewer systems is approved, inwriting, by the ADEQ CEM Coordinator. When more than one CEM/COM is used to monitoremissions from one affected facility the owner or operator shall report the results as required from eachCEMS/COMS.

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SECTION III

NOTIFICATION AND RECORD KEEPING

A. When requested to do so by an owner or operator, the ADEQ CEM Coordinator will review plans forinstallation or modification for the purpose of providing technical advice to the owner or operator.

B. Each facility which operates a CEMS/COMS shall notify the ADEQ CEM Coordinator of the date forwhich 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 days prior to testing. Performance testresults shall be submitted to the Department within thirty days after completion of testing.

C. Each facility which operates a CEMS/COMS shall maintain records of the occurrence and duration ofstart up/shut down, cleaning/soot blowing, process problems, fuel problems, or other malfunction in theoperation of the affected facility which causes excess emissions. This includes any malfunction of theair pollution control equipment or any period during which a continuous monitoring device/system isinoperative.

D. Except for Part 75 CEMs, each facility required to install a CEMS/COMS shall submit an excessemission and monitoring system performance report to the Department (Attention: Air Division, CEMCoordinator) at least quarterly, unless more frequent submittals are warranted to assess the compliancestatus of the facility. Quarterly reports shall be postmarked no later than the 30th day of the monthfollowing the end of each calendar quarter. Part 75 CEMs shall submit this information semi-annuallyand as part of Title V six (6) month reporting requirement if the facility is a Title V facility.

E. All excess emissions shall be reported in terms of the applicable standard. Each report shall besubmitted on ADEQ Quarterly Excess Emission Report Forms. Alternate forms may be used with priorwritten approval from the Department.

F. Each facility which operates a CEMS/COMS must maintain on site a file of CEMS/COMS dataincluding all raw data, corrected and adjusted, repair logs, calibration checks, adjustments, and testaudits. This file must be retained for a period of at least five years, and is required to be maintained insuch a condition that it can easily be audited by an inspector.

G. Except for Part 75 CEMs, quarterly reports shall be used by the Department to determine compliancewith the permit. For Part 75 CEMs, the semi-annual report shall be used.

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SECTION IV

QUALITY ASSURANCE/QUALITY CONTROL

A. For each CEMS/COMS a Quality Assurance/Quality Control (QAlQC) plan shall be submitted to theDepartment (Attn.: Air Division, CEM Coordinator). CEMS quality assurance procedures are definedin 40 CFR, Part 60, Appendix F. This plan shall be submitted within 180 days of the CEMS/COMSinstallation. A QAlQC plan shall consist of procedure and practices which assures acceptable level ofmonitor data accuracy, precision, representativeness, and availability.

B. The submitted QAlQC plan for each CEMS/COMS shall not be considered as accepted until the facilityreceives a written notification of acceptance from the Department.

C. Facilities responsible for one, or more, CEMS/COMS used for compliance monitoring shall meet theseminimum requirements and are encouraged to develop and implement a more extensive QAlQCprogram, or to continue such programs where they already exist. Each QAlQC program must includewritten procedures which should describe in detail, complete, step-by-step procedures and operations foreach of the following activities:

1. Calibration of CEMS/COMSa. 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 tostable operation)

2. Calibration drift determination and adjustment of CEMS/COMSa. Out-of-control period determinationb. Steps of corrective action

3. Preventive maintenance of CEMS/COMSa. CEMS/COMS information

I) Manufacture2) Model number3) Serial number

b. Scheduled activities (check list)c. Spare part inventory

4. Data recording, calculations, and reporting5. Accuracy audit procedures including sampling and analysis methods6. Program of corrective action for malfunctioning CEMS/COMS

D. A Relative Accuracy Test Audit (RATA), shall be conducted at least once every four calendarquarters. A Relative Accuracy Audit (RAA), or a Cylinder Gas Audit (CGA), may be conductedin the other three quarters but in no more than three quarters in succession. The RATA shouldbe conducted in accordance with the applicable test procedure in 40 CFR Part 60 Appendix Aand calculated in accordance with the applicable performance specification in 40 CFR Part 60Appendix B. CGA's and RAA's should be conducted and the data calculated in accordance withthe procedures outlined on 40 CFR Part 60 Appendix F.

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If alternative testing procedures or methods of calculation are to be used in the RATA, RAA orCGA audits prior authorization must be obtained from the ADEQ CEM Coordinator.

E. Criteria for excessive audit inaccuracy.

RATAAll Pollutants

> 20% Relative Accuracyexcept Carbon

MonoxideCarbon Monoxide > 10% Relative Accuracy

All Pollutantsexcept Carbon > 10% of the Applicable Standard

MonoxideCarbon Monoxide > 5% of the Applicable Standard

Diluent (02 & CO2) > 1.0%02orC02Flow > 20% Relative Accuracy

eGA

Pollutant> 15% of average auditvalue or 5 ppm difference

Diluent (02 & CO2)> 15% of average auditvalue or 5 ppm difference

RAA> 15% of the three run

Pollutant average or > 7.5 % of theapplicable standard> 15% of the three run

Diluent (02 & CO2) average or > 7.5 % of theapplicable standard

F. If either the zero or span drift results exceed two times the applicable drift specification in 40 CFR, Part60, Appendix B for five consecutive, daily periods, the CEMS is out-of-control. If either the zero orspan drift results exceed four times the applicable drift specification in Appendix B during a calibration

(-7

drift check, the CEMS is out-of-control. If the CEMS exceeds the audit inaccuracies listed above, theCEMS is out-of-control. If a CEMS is out-of-control, the data from that out-of-control period is notcounted towards meeting the minimum data availability as required and described in the applicablesubpart. The end of the out-of-control period is the time corresponding to the completion of thesuccessful daily zero or span drift or completion of the successful CGA, RAA or RATA.

G. A back-up monitor may be placed on an emission source to minimize monitor downtime. This back-upCEMS is subject to the same QAlQC procedure and practices as the primary CEMS.· The back-upCEMS shall be certified by a PST. Daily zero-span checks must be performed and recorded inaccordance with standard practices. When the primary CEMS goes down, the back-up CEMS may thenbe engaged to sample, analyze and record the emission source pollutant until repairs are made and theprimary unit is placed back in service. Records must be maintained on site when the back-up CEMS isplaced 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 of service and the date and time the primaryCEMS was placed back in service.

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CERTIFICATE OF SERVICE

I, Pam Owen, hereby certify that a copy of this permit has been mailed by first class mail to

\/-hPlanters Cotton Oil Mill, Incorporated, PO Box 7427, Pine Bluff, AR, 71611, on this 80 day

of ,~p±erobQr ,2011.

P~O· (Y\AAII A~D·. . -----am wen, ,If rvision

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