permit applications table

Permit Applications Table

Permit Type Application Date Permit Action Total Facility Operating Permit October 12, 2011 001 Additional Material February 29, 2012 001

TABLE OF CONTENTS

Notice to the Permittee Permit Shield Facility Description

Table A: Limits and Other Requirements Table B: Submittals Appendix I: Insignificant Activities Appendix II: Odor Management Plan Appendix III: Modeled Parameters

NOTICE TO THE PERMITTEE: Your stationary source may be subject to the requirements of the Minnesota Pollution Control Agency’s (MPCA) solid waste, hazardous waste, and water quality programs. If you wish to obtain information on these programs, including information on obtaining any required permits, please contact the MPCA general information number at: Metro Area 651-296-6300 Outside Metro Area 1-800-657-3864 TTY 651-282-5332 The rules governing these programs are contained in Minn. R. chs. 7000-7105. Written questions may be sent to: Minnesota Pollution Control Agency, 520 Lafayette Road North, St. Paul, Minnesota 55155-4194. Questions about this air emission permit or about air quality requirements can also be directed to the telephone numbers and address listed above. PERMIT SHIELD: Subject to the limitations in Minn. R. 7007.1800, compliance with the conditions of this permit shall be deemed compliance with the specific provision of the applicable requirement identified in the permit as the basis of each condition. Subject to the limitations of Minn. R. 7007.1800 and 7017.0100, subp. 2, notwithstanding the conditions of this permit specifying compliance practices for applicable requirements, any person (including the Permittee) may also use other credible evidence to establish compliance or noncompliance with applicable requirements.

FACILITY DESCRIPTION: Hometown BioEnergy produces electricity by combusting biogas which is created onsite through anaerobic digestion. The facility has four 2-MW reciprocating engines (EU 001-EU 004) paired with generators. Each of the engines is controlled with a CO catalyst (CE 001-CE 004) which reduces carbon monoxide (CO) and hazardous air pollutants (HAPs). The anaerobic digester uses agricultural and food processing residuals for feedstock to create biogas. Hydrogen sulfide (H2S) and moisture are removed from the biogas through the use of a biofilter before being used in the engines. The exhaust heat from the engines is used to dry the solids that remain after anaerobic digestion (EU 006). The dried solids are taken off-site for use as solid fuel. The facility has a 10 MMBtu/hr propane-fired boiler (EU 005). A flare (EU 007) is maintained with a propane-fired pilot for the purpose of combusting excess biogas in the event that more biogas is created than can be used or stored onsite.

TABLE A: LIMITS AND OTHER REQUIREMENTSHometown BioEnergy

07900050 - 001

Facility Name:

Permit Number:

05/07/12A-1

Table A contains limits and other requirements with which your facility must comply. The limits are located in the first column ofthe table (What To do). The limits can be emission limits or operational limits. This column also contains the actions that you musttake and the records you must keep to show that you are complying with the limits. The second column of Table A (Why to do it)lists the regulatory basis for these limits. Appendices included as conditions of your permit are listed in Table A under total facilityrequirements.

Subject Item: Total Facility

What to do Why to do itSOURCE-SPECIFIC REQUIREMENTS hdr

Permit Appendices: This permit contains two appendices as listed in the permitTable of Contents. The Permittee shall comply with all requirements contained inthe appendices.

Minn. R. 7007.0800, subp. 2

Application for a major permit amendment: If any GP 001 CO emission factorverification test measures at 0.88 g/hp-hr or greater, the Permittee shall submit anapplication for a major amendment. The application shall propose a reduction of the31,000 hr/yr GP 001 operating limit to a level that will limit GP 001 CO emissions tono greater than 85.0 tons per year.

The application shall be submitted no later than 30 days after the Permittee'sreceipt of the MPCA letter approving the performance test results (i.e. a Notice ofVerification).

This requirement is repeated under Subject Item GP 001.

Title I Condition: To avoid major source classificationunder 40 CFR Section 70.2 and Minn. R. 7007.0200

Application for a major permit amendment: If any GP 001 formaldehyde emissionfactor verification test measures at 0.60 lb/hr or greater, the Permittee shall submitan application for a major amendment. The application shall propose a reduction ofthe 31,000 hr/yr GP 001 operating limit to a level that will limit GP 001formaldehyde to less than 9.0 tons/year.




OPERATIONAL REQUIREMENTS hdr

Circumvention: Do not install or use a device or means that conceals or dilutesemissions, which would otherwise violate a federal or state air pollution control rule,without reducing the total amount of pollutant emitted.

Minn. R. 7011.0020

Air Pollution Control Equipment: Operate all pollution control equipment wheneverthe corresponding process equipment and emission units are operated.

Minn. R. 7007.0800, subp. 2; Minn. R. 7007.0800,subp. 16(J)

Operation and Maintenance Plan: Retain at the stationary source an operation andmaintenance plan for all air pollution control equipment. At a minimum, the O & Mplan shall identify all air pollution control equipment and control practices and shallinclude a preventative maintenance program for the equipment and practices, adescription of (the minimum but not necessarily the only) corrective actions to betaken to restore the equipment and practices to proper operation to meet applicablepermit conditions, a description of the employee training program for properoperation and maintenance of the control equipment and practices, and the recordskept to demonstrate plan implementation.

Minn. R. 7007.0800, subps. 14 and 16(J)

Operation Changes: In any shutdown, breakdown, or deviation the Permittee shallimmediately take all practical steps to modify operations to reduce the emission ofany regulated air pollutant. The Commissioner may require feasible and practicalmodifications in the operation to reduce emissions of air pollutants. No emissionsunits that have an unreasonable shutdown or breakdown frequency of process orcontrol equipment shall be permitted to operate.

Minn. R. 7019.1000, subp. 4

Fugitive Emissions: Do not cause or permit the handling, use, transporting, orstorage of any material in a manner which may allow avoidable amounts ofparticulate matter to become airborne. Comply with all other requirements listed inMinn. R. 7011.0150.

Minn. R. 7011.0150

Noise: The Permittee shall comply with the noise standards set forth in Minn. R.7030.0010 to 7030.0080 at all times during the operation of any emission units.This is a state only requirement and is not enforceable by the EPA Administrator orcitizens under the Clean Air Act.

Minn. R. 7030.0010 - 7030.0080

Inspections: The Permittee shall comply with the inspection procedures andrequirements as found in Minn. R. 7007.0800, subp. 9(A).

Minn. R. 7007.0800, subp. 9(A)


07900050 - 001

Facility Name:

Permit Number:

05/07/12A-2

The Permittee shall comply with the General Conditions listed in Minn. R.7007.0800, subp. 16.

Minn. R. 7007.0800, subp. 16

PERFORMANCE TESTING hdr

Performance Testing: Conduct all performance tests in accordance with Minn. R.ch. 7017 unless otherwise noted in Tables A, B, and/or C.

Minn. R. ch. 7017

Performance Test Notifications and Submittals:

Performance Tests are due as outlined in Table A of the permit.See Table B for additional testing requirements.

Performance Test Notification (written): due 30 days before each Performance TestPerformance Test Plan: due 30 days before each Performance TestPerformance Test Pre-test Meeting: due 7 days before each Performance TestPerformance Test Report: due 45 days after each Performance TestPerformance Test Report - Microfiche Copy: due 105 days after each PerformanceTest

The Notification, Test Plan, and Test Report may be submitted in an alternativeformat as allowed by Minn. R. 7017.2018.

Minn. R. 7017.2018; Minn. R. 7017.2030, subps. 1-4,Minn. R. 7017.2035, subps. 1-2

Limits set as a result of a performance test (conducted before or after permitissuance) apply until superseded as stated in the MPCA's Notice of Complianceletter granting preliminary approval. Preliminary approval is based on formal reviewof a subsequent performance test on the same unit as specified by Minn. R.7017.2025, subp. 3. The limit is final upon issuance of a permit amendmentincorporating the change.

Minn. R. 7017.2025, subp. 3

MONITORING REQUIREMENTS hdr

Monitoring Equipment Calibration: The Permittee shall calibrate all requiredmonitoring equipment at least once every 12 months (any requirements applying tocontinuous emission monitors are listed separately in this permit).

Minn. R. 7007.0800, subp. 4(D)

Operation of Monitoring Equipment: Unless otherwise noted in Tables A, B, and/orC, monitoring a process or control equipment connected to that process is notnecessary during periods when the process is shutdown, or during checks of themonitoring systems, such as calibration checks and zero and span adjustments. Ifmonitoring records are required, they should reflect any such periods of processshutdown or checks of the monitoring system.

Minn. R. 7007.0800, subp. 4(D)

RECORDKEEPING hdr

Recordkeeping: Retain all records at the stationary source, unless otherwisespecified within this permit, for a period of five (5) years from the date of monitoring,sample, measurement, or report. Records which must be retained at this locationinclude all calibration and maintenance records, all original recordings forcontinuous monitoring instrumentation, and copies of all reports required by thepermit. Records must conform to the requirements listed in Minn. R. 7007.0800,subp. 5(A).

Minn. R. 7007.0800, subp. 5(C)

Recordkeeping: Maintain records describing any insignificant modifications (asrequired by Minn. R. 7007.1250, subp. 3) or changes contravening permit terms (asrequired by Minn. R. 7007.1350, subp. 2), including records of the emissionsresulting from those changes.

Minn. R. 7007.0800, subp. 5(B)

If the Permittee determines that no permit amendment or notification is requiredprior to making a change, the Permittee must retain records of all calculationsrequired under Minn. R. 7007.1200. For nonexpiring permits, these records shall bekept for a period of five years from the date that the change was made. The recordsshall be kept at the stationary source for the current calendar year of operation andmay be kept at the stationary source or office of the stationary source for all otheryears. The records may be maintained in either electronic or paper format.

Minn. R. 7007.1200, subp. 4

REPORTING/SUBMITTALS hdr

Shutdown Notifications: Notify the Commissioner at least 24 hours in advance of aplanned shutdown of any control equipment or process equipment if the shutdownwould cause any increase in the emissions of any regulated air pollutant. If theowner or operator does not have advance knowledge of the shutdown, notificationshall be made to the Commissioner as soon as possible after the shutdown.However, notification is not required in the circumstances outlined in Items A, Band C of Minn. R. 7019.1000, subp. 3.

At the time of notification, the owner or operator shall inform the Commissioner ofthe cause of the shutdown and the estimated duration. The owner or operator shallnotify the Commissioner when the shutdown is over.

Minn. R. 7019.1000, subp. 3


07900050 - 001

Facility Name:

Permit Number:

05/07/12A-3

Breakdown Notifications: Notify the Commissioner within 24 hours of a breakdownof more than one hour duration of any control equipment or process equipment ifthe breakdown causes any increase in the emissions of any regulated air pollutant.The 24-hour time period starts when the breakdown was discovered or reasonablyshould have been discovered by the owner or operator. However, notification is notrequired in the circumstances outlined in Items A, B and C of Minn. R. 7019.1000,subp. 2.

At the time of notification or as soon as possible thereafter, the owner or operatorshall inform the Commissioner of the cause of the breakdown and the estimatedduration. The owner or operator shall notify the Commissioner when the breakdownis over.

Minn. R. 7019.1000, subp. 2

Notification of Deviations Endangering Human Health or the Environment: As soonas possible after discovery, notify the Commissioner or the state duty officer, eitherorally or by facsimile, of any deviation from permit conditions which could endangerhuman health or the environment.

Minn. R. 7019.1000, subp. 1

Notification of Deviations Endangering Human Health or the Environment Report:Within 2 working days of discovery, notify the Commissioner in writing of anydeviation from permit conditions which could endanger human health or theenvironment. Include the following information in this written description:1. the cause of the deviation;2. the exact dates of the period of the deviation, if the deviation has been corrected;3. whether or not the deviation has been corrected;4. the anticipated time by which the deviation is expected to be corrected, if not yetcorrected; and5. steps taken or planned to reduce, eliminate, and prevent reoccurrence of thedeviation.

Minn. R. 7019.1000, subp. 1

Application for Permit Amendment: If a permit amendment is needed, submit anapplication in accordance with the requirements of Minn. R. 7007.1150 throughMinn. R. 7007.1500. Submittal dates vary, depending on the type of amendmentneeded.

Minn. R. 7007.1150 - 7007.1500

Extension Requests: The Permittee may apply for an Administrative Amendment toextend a deadline in a permit by no more than 120 days, provided the proposeddeadline extension meets the requirements of Minn. R. 7007.1400, subp. 1(H).Performance testing deadlines from the General Provisions of 40 CFR pt. 60 andpt. 63 are examples of deadlines for which the MPCA does not have authority togrant extensions and therefore do not meet the requirements of Minn. R.7007.1400, subp. 1(H).

Minn. R. 7007.1400, subp. 1(H)

Emission Inventory Report: due on or before April 1 of each calendar year followingpermit issuance, to be submitted on a form approved by the Commissioner.

Minn. R. 7019.3000 - 7019.3100

Emission Fees: due 60 days after receipt of an MPCA bill. Minn. R. 7002.0005 - 7002.0095


07900050 - 001

Facility Name:

Permit Number:

05/07/12A-4

Subject Item: GP 001 Generator Engines

Associated Items: EU 001 Generator Engine

EU 002 Generator Engine



What to do Why to do itEMISSION LIMITS hdr

Opacity: less than or equal to 20 percent once operating temperatures have beenattained.

Minn. R. 7011.2300, subp. 1

Sulfur Dioxide: less than or equal to 0.50 lbs/million Btu heat input . The potentialto emit from the unit is 0.21 lb/MMBtu due to equipment design and allowable fuels.

Minn. R. 7011.2300, subp. 2

Hydrogen Sulfide: less than or equal to 300 parts per million in conditioned biogas. Minn. R. 7005.0100, subp. 35a; 40 CFR 241.3; Minn.R. 7011.2300, subp. 2; Minn. Stat. Section 116.07,subds. 4a & 9; Minn. R. 7007.0100, subp. 7(A), 7(L), &7(M); Minn. R. 7007.0800, subps. 1, 2 & 4; Minn. R.7009.0010-7009.0080

Operating Hours: less than or equal to 31,000 hours/year total for the fourgenerator engines (EU 001, EU 002, EU 003, EU 004), calculated monthly by thelast day of each month. This limit may be revised through a major amendmentbased on results from CO emission factor testing required by this permit.

During the initial 12 months of operation, the applicable operating hours limit as ofmonth 'n' shall be the following:

month 1 = 2,976 hrsmonth 2 = 5,856 hrsmonth 3 = 8,832 hrsmonth 4 = 11,712 hrsmonth 5 = 14,688 hrsmonth 6 = 17,568 hrsmonth 7 = 20,544 hrsmonth 8 = 23,424 hrsmonth 9 = 26,400 hrsmonth 10 = 29,280 hrsmonth 11 = 30,140 hrsmonth 12 = 31,000 hrs


OPERATING CONDITIONS hdr







Fuel Usage: limited to biogas produced onsite through anaerobic digestion ofapproved feedstock material defined below.

Title I Condition: To avoid major source classificationunder 40 CFR Section 70.2 and Minn. R. 7007.0200;Minn. R. 7005.0100, subp. 35a

Materials authorized in this permit as feedstock:Agricultural material including: vegetable processing residuals, silage, manure,grasses, hays, snack foods, cereals, and cellulosic biomass.

40 CFR Section 241


07900050 - 001

Facility Name:

Permit Number:

05/07/12A-5

The Permittee shall operate and maintain the catalysts (CE 001-004) any time thatany process equipment controlled by the engine catalyst is in operation. ThePermittee shall document periods of non-operation of the control equipment.See GP 002 for control equipment requirements.

Title I Condition: To avoid classification as majorsource under 40 CFR Section 70.2 and Minn. R.7007.0200, Minn. R. 7007.0800, subps. 2 and 14

The engines in this group (EU 001, EU 002, EU 003, EU 004) separately must beequipped with non-resettable hour meters.

Title I Condition: To avoid major source classificationunder 40 CFR Section 70.2 and Minn. R. 7007.0200;40 CFR Section 60.4243(a)(2)(iii)

FUEL TESTING REQUIREMENTS hdr

Initial Fuel Analysis: due 30 days after Initial Startup. Analysis of conditionedbiogas for hydrogen sulfide (H2S) following ASTM Method D-5504 and EPAMethod 18.

Fuel sample must be obtained from the fuel feed pipe to the engines. For the initialfuel analysis only: laboratory sample analysis shall performed to confirm onsitesample analysis.

Minn. R. 7007.0800, subp. 4

Fuel Analysis: due 30 days after Initial Fuel Analysis for H2S following ASTMMethod D-5504 and EPA Method 18. Fuel sample must be obtained from the fuelfeed pipe to the engines.

After a total of 12 sampling events, fuel sampling and analysis may be changed toquarterly sampling if the monthly data results are below 150 ppm.

Minn. R. 7007.0800, subp. 4

Additional Fuel Analysis for H2S when the digester feedstock makeup changes by30% or more on a dry weight basis following ASTM Method D-5504 and EPAMethod 18.

Minn. R. 7007.0800, subp. 4

PERFORMANCE TESTING hdr

Initial Performance Test: due 90 days after Initial Startup for formaldehyde. Minn. R. 7017.2020, subp. 1

Performance Test: due 180 days after Initial Performance Test to test formaldehydeemissions, not to exceed 6 months between test dates. After a total of three tests,if the average of the results are below 0.40 lb/hr, the Permittee shall notify theMPCA in writing that testing for formaldehyde will be discontinued. If the average ofthe results are above 0.40 lb/hr, the Permittee shall submit a test frequency plan tothe MPCA.

If any results are over 0.60 lb/hr the Permittee shall submit an application for amajor amendment. The application shall propose a reduction of the 31,000 hr/yr GP001 operating limit to a level that will limit GP 001 formaldehyde emissions to nogreater than 9.0 tons per year.

Minn. R. 7017.2020, subp. 1

Initial Performance Test: due 90 days after Initial Startup for arsenic Minn. R. 7017.2020, subp. 1

Performance Test: due 180 days after Initial Performance Test for arsenicemissions, not to exceed 6 months between test dates. After a total of three tests, ifthe results are negligible, the Permittee shall notify the MPCA in writing that testingfor arsenic will be discontinued.

Minn. R. 7017.2020, subp. 1

Initial Performance Test: due 90 days after Initial Startup for hydrochloric acid Minn. R. 7017.2020, subp. 1

Performance Test: due 180 days after Initial Performance Test for HCl emissions,not to exceed 6 months between test dates. After a total of three tests, if theresults are negligible, the Permittee shall notify the MPCA in writing that testing forHCl will be discontinued.

Minn. R. 7017.2020, subp. 1

RECORDKEEPING REQUIREMENTS hdr

Monthly Calculations:By the last day of the month, the Permittee shall calculate and record the following:1) Total hours of operation for the month for all emission units in GP 001.2) The 12 month rolling sum of operating hours for the previous 12 month period bysumming the monthly operating hours for the previous 12 months.

Title I Condition: To avoid major source classificationunder 40 CFR Section 70.2 and Minn. R. 7007.0200;Minn. R. 7007.0800, subp. 4 and 5

NSPS JJJJ REQUIREMENTS hdr

Nitrogen Oxides: less than or equal to 1.0 grams/horsepower-hour or 82 ppmvd at15% oxygen.

40 CFR Section 60.4233(e)

Carbon Monoxide: less than or equal to 2.0 grams/horsepower-hour or 270 ppmvdat 15% oxygen.

40 CFR Section 60.4233(e)

Volatile Organic Compounds: less than or equal to 0.70 grams/horsepower-hour 40 CFR Section 60.4233(e)

Air-to-fuel ratio controllers shall be used with the operation of three-waycatalysts/non-selective catalytic reduction. The AFR controller must be maintainedand operated appropriately in order to ensure proper operation of the engine andcontrol device to minimize emissions at all times.

40 CFR Section 60.4243(g)


07900050 - 001

Facility Name:

Permit Number:

05/07/12A-6

A non-certified stationary SI internal combustion engine shall demonstratecompliance by:- keeping a maintenance plan and records of conducted maintenance- maintaining and operate the engine in a manner consistent with good air pollutioncontrol practice for minimizing emissions, to the extent practicable- conducting an initial performance test within 1 year of engine startup andconducting subsequent performance testing every 8,760 hours or 3 years,whichever comes first, thereafter.

40 CFR Section 60.4243(a)(2), 40 CFR Section60.4243(a)(2)(iii)

Initial Performance Test: due 365 days after Startup of each engine for NOx. Thisrequirement applies separately to each engine.

Compliance with NSPS Subpart JJJJ is demonstrated if results are less than 1.0g/hp-hr.


Initial Performance Test: due 365 days after Startup of each engine for CO. Thisrequirement applies separately to each engine.

Compliance with NSPS Subpart JJJJ is demonstrated if results are less than 2.0g/hp-hr. If results are at or greater than 0.88 g/hp-hr see operating condition aboveregarding submitting a major permit amendment.


Initial Performance Test: due 365 days after Initial Startup of each engine forVOCs. This requirement applies separately to each engine.



Performance Test: due before end of each 36 months following Initial PerformanceTest or 8,760 hours of operation, whichever comes first for NOx. This requirementapplies separately to each engine.



Performance Test: due before end of each 36 months following Initial PerformanceTest or 8,760 hours of operation, whichever comes first for CO. This requirementapplies separately to each engine.



Performance Test: due before end of each 36 months following Initial PerformanceTest or 8,760 hours of operation, whichever comes first for VOCs. This requirementapplies separately to each engine.



The Permittee shall keep records of the following:(1) All notifications submitted to comply with Subpart JJJJ and all documentationsupporting any notification;(2) Maintenance conducted on the engine;(3) If the engine is certified, documentation from the manufacturer that the engine iscertified to meet the emission standards and information as required in 40 CFRParts 90 and 1048; and(4) If the engine is non-certified or is certified but operating in a non-certifiedmanner and subject to 40 CFR Section 60.4243(a), documentation that the enginemeets the emission standards.

40 CFR Section 60.4245(a)

The Permittee shall follow the procedures in 40 CFR Section 60.4244(a) through (f)when conducting performance tests.

40 CFR Section 60.4244

The Permittee must submit an initial notification as required in 40 CFR Section60.7(a)(1). The notification must include the following information:1) Name and address of the Permittee;2) The address of the affected source;3) Engine information including make, model, engine family, serial number, modelyear, maximum engine power, and engine displacement;4) Emission control equipment; and5) Fuel used.

40 CFR Section 60.4245(c)

The Permittee must submit a copy of each performance test as conducted in 40CFR Section 60.4244 within 60 days after the test has been completed.

40 CFR Section 60.4245(d)

NESHAP ZZZZ REQUIREMENTS hdr


07900050 - 001

Facility Name:

Permit Number:

05/07/12A-7

EU 001, EU 002, EU 003, EU 004 are new affected sources as defined under 40CFR pt. 63, subp. ZZZZ, and the facility is an area source as defined at 40 CFRSection 63.2. The Permittee shall meet the requirements of 40 CFR pt. 63, subp.ZZZZ by meeting the requirements of 40 CFR pt. 60, subp. JJJJ. No furtherrequirements of 40 CFR pt. 63, subp. ZZZZ apply to EU 001, EU 002, EU 003, EU004.

40 CFR Section 63.6590(c); Minn. R. 7011.8150


07900050 - 001

Facility Name:

Permit Number:

05/07/12A-8

Subject Item: GP 002 CO Catalysts

Associated Items: CE 001 Catalytic Oxidizer

CE 002 Catalytic Oxidizer



What to do Why to do itEMISSION AND OPERATIONAL LIMITS hdr

The Permittee shall operate and maintain the engine catalyst any time that anyprocess equipment controlled by the engine catalyst is in operation. The Permitteeshall document periods of non-operation of the control equipment.


The Permittee shall operate and maintain the control equipment such that itachieves an overall control efficiency for Volatile Organic Compounds: greater thanor equal to 60 percent control efficiency


The Permittee shall operate and maintain the control equipment such that itachieves an overall control efficiency for Carbon Monoxide: greater than or equal to60 percent control efficiency


The Permittee shall operate and maintain the control equipment such that itachieves an overall control efficiency for HAPs - Total: greater than or equal to 60percent control efficiency


The Permittee shall operate and maintain the control equipment such that itachieves an overall control efficiency for Formaldehyde: greater than or equal to 60percent control efficiency


Temperature: greater than or equal to 550 degrees F and less than or equal to1250 degrees F using 3-hour Rolling Average unless a new limit is set pursuant toMinn. R. 7017.2025, subp. 3 based on the values recorded during the most recentMPCA-approved performance test where compliance was demonstrated. The newlimit shall be implemented upon receipt of the Notice of Compliance letter grantingpreliminary approval. The limit is final upon issuance of a permit amendmentincorporating the change. If the temperature is below the minimum inlettemperature limit, the CO, VOC and HAPs used during that time shall beconsidered uncontrolled until the inlet temperature is above the minimumtemperature limit. This shall be reported as a deviation.


MONITORING AND RECORDKEEPING hdr

Sample Analysis: due before end of each 24 months following Startup. ThePermittee shall send a representative sample of the catalyst to a laboratory to testthe catalyst's activity. If test results show a activity of less than 60%, the Permitteeshall follow the corrective actions contained in the Operation and MaintenancePlan.


Daily Monitoring: The Permittee shall physically verify the operation of thetemperature recording device at least once each operating day to verify that it isworking and recording properly. The Permittee shall maintain a written record of thedaily verifications.

Minn. R. 7007.0800, subps. 4 and 5

Monitoring Equipment: The Permittee shall install and maintain thermocouples formeasuring the temperatures as required by this permit. The monitoring equipmentmust be installed, in use, and properly maintained whenever the monitored controlequipment is required to be operated.

Minn. R. 7007.0800, subp. 4

The Permittee shall maintain and operate a thermocouple monitoring device thatcontinuously indicates and records both the inlet and outlet temperatures of thecatalytic oxidizer. The monitoring device shall have a margin of error less than thegreater of +/- 0.75 percent of the temperature being measured or +/- 2.5 degreesCelsius. The recording device shall also calculate the three-hour rolling averageinlet temperature.

Minn. R. 7007.0800, subps. 4 and 5

The Permittee shall maintain a continuous hard copy readout or computer disk fileof the inlet and outlet temperatures and the calculated three-hour rolling averageinlet temperature.

Title I Condition: To avoid classification as a majorsource under 40 CFR Section 70.2 and Minn. R.7007.0200; Minn. R. 7007.0800, subps. 4 and 5

Monthly Monitoring: At least once each month during normal operation, thePermittee shall record the temperature rise across the catalyst (outlet temp. - inlettemp.) while the process is running. If it is determined that the catalyst reactivityhas been impaired, by comparison of the observed temperature rise to the pasttemperature rise records, the Permittee shall follow the corrective actions in theOperation and Maintenance Plan. The Permittee shall maintain written records ofthe monitoring and any corrective actions taken.

Minn. R. 7007.0800, subps. 4, 5, and 14


07900050 - 001

Facility Name:

Permit Number:

05/07/12A-9

Quarterly Inspections: At least once per calendar quarter, or more frequently ifrequired by the manufacturer specifications, the Permittee shall inspect the controlequipment internal and external system components, including but not limited to therefractory, heat exchanger, and electrical systems. The Permittee shall maintain awritten record of the inspection and any corrective actions taken resulting from theinspection.

Minn. R. 7007.0800, subps. 4, 5, and 14

Annual Calibration: The Permittee shall calibrate the temperature monitor at leastannually and shall maintain a written record of the calibration and any actionresulting from the calibration.

Minn. R. 7007.0800, subps. 4, 5, and 14

For periods when the catalytic oxidizer is operated above the minimum inlettemperature, the Permittee shall use either one of the following when completingcalculations as required elsewhere in this permit:a. The overall control efficiency limit specified in this permit for this equipment(60%); orb. The overall control efficiency determined during the most recent MPCA approvedperformance test. If the tested efficiency is less than the efficiency limit in thispermit, the Permittee must use the tested value in all calculations until theefficiency is demonstrated to be above the permit limit through a new test


Corrective Actions: If the temperature is below the minimum specified by this permitor if the catalytic oxidizer or any of its components are found during the inspectionsto need repair, the Permittee shall take corrective action as soon as possible.Corrective actions shall return the temperature to at least the permitted minimumand/or include completion of necessary repairs identified during the inspection, asapplicable. Corrective actions include, but are not limited to, those outlined in the O& M Plan for the catalytic oxidizer. The Permittee shall keep a record of the typeand date of any corrective action taken.

Minn. R. 7007.0800, subps. 4, 5, and 14

The Permittee shall operate and maintain the CO Catalyst in accordance with theOperation and Maintenance (O & M) Plan. The Permittee shall keep copies of theO & M Plan available onsite for use by staff and MPCA staff.

Minn. R. 7007.0800, subp. 14


07900050 - 001

Facility Name:

Permit Number:

05/07/12A-10

Subject Item: EU 005 Boiler

Associated Items: SV 002 Hot Water Boiler

What to do Why to do itFuels allowed: propane, by equipment design. Minn. R. 7005.0100, subp. 35a

Total Particulate Matter: less than or equal to 0.40 lbs/million Btu heat input . Thepotential to emit from the unit is 0.008 lb/MMBtu due to equipment design andallowable fuels.

Minn. R. 7011.0515, subp. 1

Opacity: less than or equal to 20 percent except for one six-minute period per hourof not more than 60 percent opacity.

Minn. R. 7011.0515, subp. 2

Recordkeeping: By the last day of each calendar month, the Permittee shall recordthe amount of propane combusted in the boiler during the previous calendar month.These records shall consist of purchase records, receipts, or fuel meter readings.

40 CFR Section 60.48c(g); Minn. R. 7011.0570


07900050 - 001

Facility Name:

Permit Number:

05/07/12A-11

Subject Item: EU 006 Solid Fuel Drying and Prep

Associated Items: SV 003 Solid fuel drying and prep

What to do Why to do itTotal Particulate Matter: less than or equal to 0.30 grains/dry standard cubic foot ofexhaust gas unless required to further reduce emissions to comply with the lessstringent limit of either Minn. R. 7011.0730 or Minn. R. 7011.0735.

Minn. R. 7011.0715, subp. 1(A)

Opacity: less than or equal to 20 percent Minn. R. 7011.0715, subp. 1(B)

Initial Performance Test: due 365 days after Initial Startup of EU 006 to verify theVOC emission factor (this is not a test for compliance determination).

The VOC emission factor for this unit is 2.90 lbs/hr.

Minn. R. 7017.2020, subp. 1

Initial Performance Test: due 365 days after Initial Startup of EU 006 to verify thePM, PM10 and PM2.5 emission factor (this is not a test for compliancedetermination).

The PM, PM10 and PM2.5 emission factor for this unit is 0.00 lbs/hr.

Minn. R. 7017.2020, subp. 1


07900050 - 001

Facility Name:

Permit Number:

05/07/12A-12

Subject Item: EU 007 Flare

Associated Items: SV 004 Flare

What to do Why to do itOperating Hours: less than or equal to 200 hours/year using 12-month Rolling Sum. Calculated by the 15th of the month for the preceding month.


Total Particulate Matter: less than or equal to 0.30 grains/dry standard cubic foot ofexhaust gas unless required to further reduce emissions to comply with the lessstringent limit of either Minn. R. 7011.0730 or Minn. R. 7011.0735.

Minn. R. 7011.0610, subp. 1(A)(1) and Minn. R.7011.0735

Opacity: less than or equal to 20 percent except for one six-minute period per hourof not more than 60 percent opacity.

Minn. R. 7011.0610, subp. 1(A)(2)

The Permittee shall keep records of hours of operation on a daily basis. Minn. R. 7007.0800, subp. 5

TABLE B: SUBMITTALSFacility Name: Hometown BioEnergy

Permit Number: 07900050 - 001

05/07/12B-1

Also, where required by an applicable rule or permit condition, send to the Permit Document Coordinator notices of:- accumulated insignificant activities,- installation of control equipment,- replacement of an emissions unit, and- changes that contravene a permit term.

Send any application for a permit or permit amendment to:

AQ Permit Document Coordinator Industrial Division Minnesota Pollution Control Agency 520 Lafayette Road North St. Paul, Minnesota 55155-4194

Unless another person is identified in the applicable Table, send all other submittals to:

AQ Compliance Tracking Coordinator Industrial Division Minnesota Pollution Control Agency 520 Lafayette Road North St. Paul, Minnesota 55155-4194

Each submittal must be postmarked or received by the date specified in the applicable Table. Those submittals required by parts7007.0100 to 7007.1850 must be certified by a responsible official, defined in Minn. R. 7007.0100, subp. 21. Other submittals shallbe certified as appropriate if certification is required by an applicable rule or permit condition.

Send submittals that are required to be submitted to the U.S. EPA regional office to:

Mr. George Czerniak Air and Radiation Branch EPA Region V 77 West Jackson Boulevard Chicago, Illinois 60604

Send submittals that are required by the Acid Rain Program to:

U.S. Environmental Protection Agency Clean Air Markets Division 1200 Pennsylvania Avenue NW (6204N) Washington, D.C. 20460

Table B lists most of the submittals required by this permit. Please note that some submittal requirements may appear in Table Aor, if applicable, within a compliance schedule located in Table C. Table B is divided into two sections in order to separately listone-time only and recurrent submittal requirements.

TABLE B: RECURRENT SUBMITTALSFacility Name: Hometown BioEnergy


05/07/12B-2

What to send When to send Portion of Facility AffectedSemiannual Deviations Report due 30 days after end of each calendar

half-year following Permit Issuance. The firstsemiannual report submitted by the Permitteeshall cover the calendar half-year in which thepermit is issued. The first report of eachcalendar year covers January 1 - June 30.The second report of each calendar yearcovers July 1 - December 31. If no deviationshave occurred, the Permittee shall submit thereport stating no deviations.

Total Facility

Compliance Certification due 31 days after end of each calendar yearfollowing Permit Issuance (for the previouscalendar year). The Permittee shall submitthis to the Commissioner on a form approvedby the Commissioner. This report covers alldeviations experienced during the calendaryear.

Total Facility

APPENDIX I Facility Name: Hometown BioEnergy Permit Number: 07900050-001

Insignificant Activities and General Applicable Requirements

The permit is required to include periodic monitoring for all emissions units, including insignificant activities, per EPA guidance. The insignificant activities at this Facility are only subject to general applicable requirements.

Insignificant Activity General Applicable

Emission limit

Discussion

Fuel use: space heaters fueled by, kerosene, natural gas, or propane, less than 420,000 Btu/hr

PM < 0.6 or 0.4 lb/MMBtu, depending on year constructed Opacity < 20% with exceptions

(Minn. R. 7011.0510/515)

Based on the fuels used and EPA published emissions factors, it is highly unlikely that it could violate the applicable requirement. In addition, these types of units are typically operated and vented inside a building, so testing for PM or opacity is not feasible.

Emissions from gasoline storage tanks as defined in MInn. R. 7007.1300, subp. 3 (E)

Combined capacity less than 100,000 gallons.

Emissions from a laboratory, as defined in Minn. R. 7007.1300, subp. 3 (G)

PM, variable depending on airflow Opacity < 20%

(Minn. R. 7011.0710/715)

These are very small, intermittent, bench-top operations that typically do not even have any emissions. It is highly unlikely that they could violate the applicable requirement.

Brazing, soldering or welding equipment


(Minn. R. 7011.0710/715)

For these units, based on EPA published emissions factors, it is highly unlikely that they could violate the applicable requirement. In addition, these units are typically operated and vented inside a building, so testing for PM or opacity is not feasible.

Cleaning operations: alkaline/phosphate cleaners and associated cleaners and associated burners


(Minn. R. 7011.0610+ Minn. R. 7011.0710/715)

For these units, there are some factors available for the burners, but very little information regarding the cleaning operation itself. However, based on general knowledge of how they operate, it is highly unlikely that they could violate the applicable requirement or that testing would be feasible.

Infrequent use of spray paint equipment for routine housekeeping or plant upkeep activities not associated with primary production processes at the stationary source

PM, variable depending on airflow or process weight rate Opacity < 20%

(Minn. R. 7011.0715)

While spray equipment will have the potential to emit particulate matter, these particular activities are those not associated with production, so they would be infrequent and usually occur outdoors. Testing or monitoring is not feasible.

APPENDIX II Facility Name: Hometown BioEnergy Permit Number: 07900050-001 Best Management Practices Plan - Odor Prevention This best management practices (BMP) addresses potential odors from the planned Hometown BioEnergy anaerobic digestion facility to be located in Le Sueur, Minnesota. The plan describes the potential odor sources and the odor abatement BMPs in place to minimize the possibility of odors. MMPA intends to be a good neighbor and will be responsive to complaints raised. However, if odors from the facility occur during normal operations and the odor complaints are confirmed by the City of Le Sueur or the MPCA, Hometown BioEnergy will implement this response plan. The facility is intended to operate an average of 16 hours per day and is not expected to produce odor during normal operations.

I. Possible Sources of Odorous Emissions

Raw material receiving: The facility will receive agricultural feedstock materials daily for same day incorporation into the digester process. Feedstock receiving occurs in an enclosed area and short term, temporary storage of feedstock supply in contained indoors. The feedstock storage room is ventilated to a biofilter. Anaerobic Digestion Process and Vessels: Digestion of feedstock occurs, necessarily, in sealed vessels to capture the resulting biogas. Raw biogas is conditioned to reduce the moisture and hydrogen sulfide content. Biogas is stored in unpressurized gas vessels. Biogas conditioning upsets or over pressurization conditions will be controlled by flaring. Digester Solids Drying: The primary odor causing components in the digestate remaining after the biogas production stage are primarily volatile organic compounds (VOCs) in the form of small amounts of residual volatile fatty acids. Anaerobic digestion of volatile fatty acid conversion in the digesters will be nearly complete and most of the residual volatile fatty acids will partition to the liquid fraction during screw press separation and be transferred to the liquid by-product storage pond. Very little residual volatile fatty acids will be associated with the separated solids, which will reduce the potential for odor emissions during the drying process. Biofilter: A biofilter will be used to control odors from feedstock material receiving. The biofilter consists primarily of a bed of woodchips that provides a microbial growth support medium with sufficient residence time for the air stream to have contact with the bacteria that breakdown odor compounds. Silage storage: Hometown BioEnergy will use sweet corn silage as a primary feedstock and will store a one-year supply on site. The silage storage pile will include a soil cement pad plus a cover to contain the silage and to prevent the infiltration of precipitation. The cover will be opened as silage continues to be retrieved to supply the digestion process. Storage Ponds: Nutrient rich supernatant recovered from the dewatering process will be stored on-site in covered, lined storage ponds and seasonally applied to nearby agricultural land as a soil amendment. A portion of the liquid will be recycled and used in the feedstock pretreatment process to prepare the feedstock for digestion.

II. Odor Abatement Practices and Controls

Potential odors from facility sources, if they occur, will be controlled as described below: Raw material receiving: Normal odor control from feedstock receiving is provided enclosure and by ventilation to the biofilter. In the event of a receiving system breakdown and extended feedstock storage, the ventilation system and biofilter will continue to operate to control odor. If the ventilation or biofilter systems experience a temporary shutdown or breakdown, the feedstock continues to be enclosed to avoid odor outside of the facility.

Anaerobic Digestion Process and Vessels: Any leaks on the digesters would not allow for the production and capture of biogas; therefore, the digester would be taken off line for repair. Any biogas that needs to be vented to accommodate repairs or to reset a malfunction will be controlled by flaring. The flare is on continuous standby to control any biogas that cannot be handled along normal procedures. Digester Solids Drying: Odor emissions from solids drying may be addressed by confirming that the minimum dryer exhaust velocities are being achieved and take corrective actions if needed. Hometown BioEnergy will also assess the plant’s solids retention times (SRT) in the anaerobic digestion process and VFA levels in the separated solids, if needed, prior to the drying operation.

Biofilter: The biofilter is monitored by an O&M plan, which includes a weekly odor check and biofilter inspection if excessive odor is detected. Biofilter media is replaced if the pressure drop exceeds the recommended range.

Silage storage: If odor from silage storage is excessive, Hometown BioEnergy will inspect the silage cover to determine that the covering is effective.

Storage Ponds: The storage pond covers will be inspected regularly to avoid both the escape of odor or drainage of stormwater into the ponds. Temporary, small amounts of biogas or hydrogen sulfide production from the ponds are possible if residual solids reach the ponds, but it is not normal operation. Options for gas emissions would include routing the gas to the biogas conditioning system or the flare.

APPENDIX III Facility Name: Hometown BioEnergy Permit Number: 07900050-001 Modeled Parameters

SCREEN3 Modeling Input Scenario 1 Scenario 2

All flow to SV 001

66% of flow to SV 001

34% of flow to SV 003

Source Type Point Point Point Emission rate (g/s) 1 1 1 Stack Height (m) 15.2 15.2 15.2 Stack Inside Diameter (m) 0.9 0.9 0.9 Stack Inside Velocity (m/s) 43.7 28.9 14.9 Stack Gas Exit Temp (K) 723.7 723.7 338.2 Ambient Air Temp (K) 293 293 293 Receptor Height 0 0 0 Urban/Rural Option Rural Rural Rural Building Height (m) 12.3 12.3 12.3 Min Horiz Bldg Dim (m) 17.7 17.7 17.7 Max Horiz Bldg Dim (m) 30.5 30.5 30.5 Min Receptor Distance (m) 61 61 42.7 Max Receptor Distance (m) 1000 1000 1000

SCREEN3 Modeling Outputs

Scenario 1 Scenario 2

All flow

to SV 001 66% of Flow

to SV 001 34% of Flow

to SV 003

Total Target Levels Stack Height:

15.2 m Stack Height:

15.2 m Stack Height:

15.2 m Ambient Air Impact ug/m3 ug/m3 ug/m3 ug/m3 ug/m3 PM10 24-hr 150 2.1 1.8 2.3 4.1 PM2.5 24-hr 35 2.1 1.8 2.3 4.1 SO2 1-hr 196 41.9 36.0 47.5 83.5 NO2 1-hr * 188 69.1 59.3 78.2 137.6 CO 1-hr 35,000 151.8 130.3 171.9 302.2 CO 8-hr 10,000 106.2 91.2 120.3 211.6

*The ambient air impact for NO2 is reported as 20% less than the total NOx concentration.

Technical Support Document, Permit Action Number: 07900050-001 Page 1 of 8 Date: 5/7/2012

TECHNICAL SUPPORT DOCUMENT For

AIR EMISSION PERMIT NO. 07900050-001 This technical support document (TSD) is intended for all parties interested in the permit and to meet the requirements that have been set forth by the federal and state regulations (40 CFR § 70.7(a)(5) and Minn. R. 7007.0850, subp. 1). The purpose of this document is to provide the legal and factual justification for each applicable requirement or policy decision considered in the preliminary determination to issue the permit.

1. General Information

1.1 Applicant and Stationary Source Location:

Table 1. Applicant and Source Address

Applicant/Address Stationary Source/Address (SIC Code: 4931)

Hometown BioEnergy LLC 200 South Sixth Street, Suite 300 Minneapolis, MN 55402

Hometown BioEnergy LLC State Highway 112 & County Road 115 Le Sueur, Le Sueur County

Contact: Kelsey Dahlen Phone: 612-349-6868

1.2 Facility Description

Hometown BioEnergy is designed to produce electricity by combusting biogas that has been created onsite through anaerobic digestion. The facility will have four 2-MW reciprocating engines (EU 001- EU 004) paired with generators. Each of the engines will be controlled with a CO catalyst (CE 001 – CE 004) which will reduce carbon monoxide (CO) and hazardous air pollutants (HAPs). The anaerobic digester will use agricultural and food processing residuals as feedstock to create biogas. Hydrogen sulfide (H2S) and moisture will be removed from the biogas through the use of a biofilter before being used in the engines. The exhaust heat from the engines will be used to dry the solids that remain after anaerobic digestion (EU 006). The dried solids will be taken off-site for use as solid fuel.

The facility will have a 10 MMBtu/hr propane-fired boiler (EU 005). A flare (EU 007) will be maintained with a propane-fired pilot for the purpose of combusting excess biogas in the event that more biogas is created than can be used or stored onsite.

1.3 Description of any Changes Allowed with this Permit Issuance

This is a first-time total facility permit.


1.4 Facility Emissions:

Table 2. Total Facility Potential to Emit Summary

PM tpy

PM10 Tpy

PM2.5

tpy SO2 tpy

NOx tpy

CO tpy

CO2e Tpy

VOC tpy

SingleHAP tpy

All HAPstpy

Total Facility Limited Potential Emissions

17.0 6.0 4.0 8.5 55.3 89.2 44,399 21.0 6.1 8.9

Total Facility Actual Emissions

NA NA NA NA NA NA * NA *

*Not reported in MN emission inventory.

Table 3. Facility Classification

Classification Major/Affected Source

Synthetic Minor/Area Minor/Area

PSD x

Part 70 Permit Program x

Part 63 NESHAP x

2. Regulatory and/or Statutory Basis

New Source Review

The facility is a minor source under New Source Review regulations.

Part 70 Permit Program

The facility has accepted limits to be classified as a minor source under the Part 70 permit program.

New Source Performance Standards (NSPS)

EU 001-EU 004 are subject to 40 CFR Part 60 Subpart JJJJ - Standards of Performance for Stationary Spark Ignition Internal Combustion Engines.

EU 005 is subject to 40 CFR Part 60 Subpart Dc—Standards of Performance for Small Industrial-Commercial-Institutional Steam Generating Units.

National Emission Standards for Hazardous Air Pollutants (NESHAP)

EU 001-EU 004 are subject to 40 CFR Part 63 Subpart ZZZZ - National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines. The conditions of Subpart ZZZZ are met through complying with 40 CFR Part 60 Subpart JJJJ - Standards of Performance for Stationary Spark Ignition Internal Combustion Engines.


Compliance Assurance Monitoring (CAM)

This facility is not subject to CAM because it is minor for Part 70.

Environmental Review & AERA

The facility is voluntarily conducting an Environmental Assessment Worksheet (EAW).

Minnesota State Rules

Portions of the facility are subject to the following Minnesota Standards of Performance:

• Minn. R. 7011.0515 Standards of Performance for New Indirect Heating Equipment • Minn. R. 7011.0610 Standards of Performance for Fossil-Fuel-Burning Direct Heating Equipment • Minn. R. 7011.0715 Standards of Performance for Post-1969 Industrial Process Equipment • Minn. R. 7011.2300 Standards of Performance for Stationary Internal Combustion Engines

Table 4. Regulatory Overview of Facility

Level* Applicable Regulations Comments:

GP 001

Title I Condition: To avoid major source classification under 40 CFR § 70.2 and Minn. R. 7007.0200

Annual operating hour limit to prevent CO emissions from exceeding the Part 70 emissions threshold.

Minn. R. 7011.2300 Standards of Performance for Stationary Internal Combustion Engines. Limits for opacity and SO2

40 CFR Part 241 Solid Wastes Used as Fuels or Ingredients in Combustion Units. Requirements to ensure the biogas is classified as fuel and not solid waste.

40 CFR pt. 60, subp. JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines. Determination of applicable limits from rule:

• The units are manufactured post-2011

• Maximum engine power is ≥ 1,350 HP

• The fuel is limited to biogas and closest to natural gas in composition.

40 CFR pt. 63, subp. ZZZZ National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (RICE). Determination of applicable limits from rule:

• The engines are new stationary RICE located at an area source.


Level* Applicable Regulations Comments:

EU 005 Minn. R. 7011.0515 Standards of Performance for New Indirect Heating Equipment. Determination of applicable limits from rule:

• This facility is located outside Minneapolis-St. Paul and Duluth

• This unit does not combust solid fuel.

40 CFR pt. 60, subp. Dc Standards of Performance for Small Industrial-Commercial-Institutional Steam Generating Units. Determination of applicable limits from rule:

• The unit combusts only natural gas as defined in 40 CFR pt. 60, subp. Dc

EU 006 Minn. R. 7011.0715 Standards of Performance for Post-1969 Industrial Process Equipment. Limits for PM and opacity.

EU 007

Title I Condition: To avoid major source classification under 40 CFR § 70.2 and Minn. R. 7007.0200

Annual operating hours limit to prevent exceeding the Part 70 emissions threshold.

Minn. R. 7011.0610 Standards of Performance for Fossil-Fuel-Burning Direct Heating Equipment. Determination of applicable limits from rule:

• This facility is located outside Minneapolis-St. Paul and Duluth

• This unit does not combust solid fuel.

*Where the requirement appears in the permit (e.g., EU, SV, GP, etc.).

3. Technical Information

SCREEN3

Attachment 2 to this TSD contains details of SCREEN3 analysis of National Ambient Air Quality Standards (NAAQS). Both operating options were evaluated with SCREEN3; based on the results of the SCREEN3 model, none of the NAAQS would be exceeded from this project. Modeling parameters are listed in Appendix I to the permit.

40 CFR 241 – Solid Wastes Used as Fuels or Ingredients in Combustion Units

The facility is required to demonstrate compliance with 40 CFR 241 because biogas is being combusted at the facility and not a “traditional fuel.” The biogas must contain contaminants at levels comparable in concentration or lower than those in traditional fuels which the combustion unit is designed to burn (natural gas). The facility has chosen to demonstrate this by testing the biogas for H2S and other possible contaminants.

Hydrogen Sulfide Sampling


The facility will conduct monthly sampling of the biogas from the fuel feed pipe to the engines for H2S following ASTM Method D-5504 and EPA Method 18. This method of sampling is suggested as a sampling requirement in an EPA letter dated January 30, 2012 (Attachment 3) to Riverview LLC, a facility that operates engines combusting digester gas. The letter allows that monthly sampling can be relaxed to quarterly sampling if sample results show little variability in the fuel. The facility will have a laboratory with the capability to perform sample analysis onsite. The initial fuel analysis will be analyzed by the onsite laboratory and confirmed by third-party laboratory analysis.

Odor Management

Feedstock, other than silage, will be received in an enclosed building. The feedstock trucks will unload in the enclosed receiving area and be rinsed to ensure all feedstock enters the process. The unloading area will be operated under negative pressure. The air from the receiving area will be routed to a biofilter. The Operation and Maintenance (O&M) Plan for the biofilter is included as Attachment 4 to this TSD. The facility will follow the Odor Management Plan which is Appendix II to the permit.

3.1 Calculations of Potential to Emit

Attachment 1 to this TSD contains a detailed spreadsheet with calculations and a summary of the PTE of the Facility that was prepared by the MPCA and the Permittee.

3.2 Periodic Monitoring

In accordance with the Clean Air Act, it is the responsibility of the owner or operator of a facility to have sufficient knowledge of the facility to certify that the facility is in compliance with all applicable requirements.

In evaluating the monitoring included in the permit, the MPCA considered the following:

• The likelihood of the facility violating the applicable requirements; • Whether add-on controls are necessary to meet the emission limits; • The variability of emissions over time; • The type of monitoring, process, maintenance, or control equipment data already available for

the emission unit; • The technical and economic feasibility of possible periodic monitoring methods; and • The kind of monitoring found on similar units elsewhere.

Table 5 summarizes the periodic monitoring requirements for those emission units for which the monitoring required by the applicable requirement is nonexistent or inadequate.


Table 5. Periodic Monitoring

Level* Requirement (basis) Additional Monitoring Discussion GP 001 (Engines)

Annual operation ≤ 31,000 hrs/year (Title I limit to avoid Part 70) SO2 ≤ 0.50 lb/mmBtu (Minn. R. 7011.2300) H2S ≤ 300 ppm in fuel 40 CFR 241 CO ≤ 2.0 g/hp-hr (NSPS Subpart JJJJ) NOx ≤ 1.0 g/hp-hr (NSPS Subpart JJJJ) VOC ≤ 0.70 g/hp-hr (NSPS Subpart JJJJ)

Recordkeeping: Daily records of operating time; monthly calculations of rolling sum. Monthly fuel sample for H2S. Monthly fuel sample for H2S. Performance testing for CO every 8,760 hours of operation. Performance test for NOx every 8,760 hours of operation Performance test for VOCs every 8,760 hours of operation

The annual operation limit is the combined operating time of all four engines. Limit on H2S to demonstrate that the biogas does not contain contaminants in a concentration greater than the traditional fuel the unit is capable of combusting.The limits from NSPS Subpart JJJJ are for engines burning natural gas. Because the composition of biogas is similar to natural gas, it is reasonable to use the limits for units combusting natural gas.

GP 002

(CO Catalyst)

CO: Control Efficiency ≥ 60%

VOC: Control Eff. ≥ 60%

HAPs: Control Eff. ≥ 60%

Formaldehyde: Control Eff. ≥ 60%

Temperature: ≥ 550 degrees F and ≤ 1250 degrees F

(Title I to avoid Part 70)

Daily recordkeeping of temperature, periodic inspection and catalysis activity analysis.

EU 005

(Hot Water Boiler)

PM: < 0.40 lb/MMBtu

Opacity: < 20 % with exceptions

(Minn. R. 7011.0515)

None The PTE for this equipment design and allowable fuel is 0.008 lb/MMBtu, significantly lower than the limit.

EU 006

(Solid Fuel Drying)

PM: < 0.30 grains/dscf

(Minn. R. 7011.0715)

One-time performance test to verify emission factor for PM and VOCs.

Based on the PTE for this equipment it is highly unlikely that the limit will be exceeded.


Level* Requirement (basis) Additional Monitoring Discussion

EU 007

(Flare)

Operation < 200 hrs/yr on a 12-month rolling sum

(Title I to avoid Part 70)

PM: < 0.30 grains/dscf

Opacity: < 20 % with exceptions

(Minn. R. 7011.0610)

Daily recordkeeping, monthly calculations for 12 month rolling sum.

Based on the PTE for this equipment it is highly unlikely that the limit will be exceeded.

*Where the requirement appears in the permit (e.g., EU, SV, GP, etc.).

3.3 Insignificant Activities

Hometown BioEnergy has several operations which are classified as insignificant activities under the MPCA’s permitting rules. These are listed in Appendix I to the permit.

3.4 Permit Organization

In general, the permit meets the MPCA Delta Guidance for ordering and grouping of requirements. One area where this permit deviates slightly from Delta guidance is in the use of appendices. While appendices are fully enforceable parts of the permit, in general, any requirement that the MPCA thinks should be electronically tracked (e.g., limits, submittals, etc.), should be in Table A or B of the permit. The main reason is that the appendices are word processing sections and are not part of the electronic tracking system. Violation of the appendices can be enforced, but the computer system will not automatically generate the necessary enforcement notices or documents. Staff must generate these

3.5 Comments Received Public Notice Period: February 23, 2012 – March 24, 2012

Comments were received from the public during the public notice period. Six comment letters were received and are included as Attachment 7 to this document. The MPCA’s response to comments are included as Attachment 8 to this document. The comments resulted in changes to the permit. One requirement was split into two requirements for clarity; requirements were added to EU 006 to test for VOC and PM to confirm the emission factor used in the calculations; and the points calculation for additional fees was corrected.

4. Permit Fee Assessment

This permit action is the issuance of an individual State Permit based on an application received October 12, 2011. Attachment 6 to this TSD contains the MPCA’s assessment of Application and Additional Points used to determine the permit application fee for this permit action as required by Minn. R. 7002.0019. The permit action includes limits to avoid Part 70, two NSPSs, one NESHAP, and the EAW for which additional points apply.


5. Conclusion

Based on the information provided by Hometown BioEnergy, the MPCA has reasonable assurance that the proposed operation of the emission facility, as described in the Air Emission Permit No. 07900050-001 and this TSD, will not cause or contribute to a violation of applicable federal regulations and Minnesota Rules.

Staff Members on Permit Team: Adriane Lenshek (permit writer/engineer) Jennifer Carlson (enforcement) Jim Kohler (stack testing) Jeff Hedman (peer reviewer)

AQ File No. 4494; DQ 3698 Attachments: 1. PTE Summary and Calculation Spreadsheets

2. SCREEN3 3. EPA Letter to Riverview LLC 4. Biofilter O&M Plan 5. Facility Description and CD-01 Forms 6. Points Calculator 7. Public Comments 8. Response to Comments

Attachment 1 - PTE Summary and Calculation Spreadsheets

Hom

etow

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Emis

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Inve

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ptem

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2011

Tabl

e A

- 1

Hom

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Air

Emis

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Inve

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yJa

nuar

y 2

012

Sta

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Em

issi

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ctor

(per

Con

trol

Effi

cien

cy

Flow

thro

ugh

SV

001

Not

esID

IDD

escr

iptio

n(u

nits

/hr)

(uni

ts/y

r)U

nits

(lb/U

nit)

(lb/h

r)(to

n/yr

)(%

)lb

/hr

ton/

yr(lb

/hr)

(ton/

yr)

(%)

PM

2,82

6--

-hp

0.00

007

0.75

3.3

-0.

753.

30.

752.

966

[1],

[2],

[3]

PM

102,

826

---

hp0.

0000

70.

753.

3-

0.75

3.3

0.75

2.9

66[1

], [2

], [3

]

PM

2.5

2,82

6--

-hp

0.00

007

0.75

3.3

-0.

753.

30.

752.

966

[1],[

2],[3

],[19

]

SO

22,

826

---

hp0.

0017

820

.18

88.4

902.

028.

82.

027.

866

[1],

[2],

[3]

NO

x2,

826

---

hp0.

0011

012

.46

54.6

-12

.46

54.6

12.4

648

.366

[1],

[2],

[3]

VO

C2,

826

---

hp0.

0005

15.

7325

.160

2.29

10.0

2.29

8.9

66[1

], [2

], [3

], [4

]

CO

2,82

6--

-hp

0.00

4954

.83

240.

160

21.9

396

.121

.93

85.0

66[1

], [2

], [3

], [4

]

mm

btu

1.90

576

CO

2 (G

HG

in k

g/M

MB

tu)

---

---

---

---

---

---

---

103.

3745

2.8

103.

3740

0.6

66[2

1]

CO

2(G

HG

in k

g/M

MB

tu)

18.4

416

1,53

4M

MB

tu52

.07

3840

.733

644.

4-

3,84

0.7

33,6

44.4

3840

.729

765.

366

[2],

[3],

[5]

CH

4(G

HG

in k

g/M

MB

tu)

18.4

416

1,53

4M

MB

tu0.

6850

.42

441.

6-

50.4

441.

650

.42

390.

766

[1],

[2],

[3]

N2O

(GH

G in

kg/

MM

Btu

)18

.44

161,

534

MM

Btu

0.00

063

0.05

0.4

-0.

00.

40.

050.

466

[2],

[3],

[6]

CO

2e(G

HG

in k

g/M

MB

tu)

18.4

416

1,53

4M

MB

tu66

.62

4913

.843

045.

1-

4,91

3.8

43,0

45.1

4913

.838

082.

166

[3],

[7],

[8]

Hig

hest

Sin

gle

HA

P

(For

mal

dehy

de)

18.4

416

1,53

4M

MB

tu0.

053.

8917

.160

1.56

6.8

1.56

6.0

66[1

], [2

], [3

], [4

], [9

]

Tota

l HA

P5.

3323

.360

2.13

9.3

2.13

8.3

66[1

][2]

[3][

4][9

]

Sta

ckV

ent

Em

issi

onFa

ctor

Con

trol

Effi

cien

cy

Flow

from

Eng

ines

Not

es

IDID

Des

crip

tion

(uni

ts/h

r)(u

nits

/yr)

Uni

ts(lb

/Uni

t)(lb

/hr)

(ton/

yr)

(%)

lb/h

rto

n/yr

(lb/h

r)(to

n/yr

)(%

)

SV

003

EU

006

PM

34[1

0]P

M10

34[1

0]

PM

2.5

34[1

0], [

19]

SO

234

[10]

NO

x34

[10]

VO

C13

1511

,521

,700

Lite

rs0.

0022

2.9

12.7

-2.

912

.72.

911

.234

[10]

CO

34[1

0]C

O2

(GH

G in

kg/

MM

Btu

)34

[10]

, [22

]

CO

2(G

HG

in k

g/M

MB

tu)

34[1

0]

CH

4(G

HG

in k

g/M

MB

tu)

34[1

0]

N2O

(GH

G in

kg/

MM

Btu

)34

[10]

CO

2e(G

HG

in k

g/M

MB

tu)

34[1

0]

Tota

l HA

P34

[10]

Gen

erat

orE

ngin

es

Sol

id F

uel

Dry

ing

and

Pre

para

tion

SV

001

EU

001,

E

U00

2,E

U00

3,E

U00

4

Em

issi

on S

ourc

eP

ollu

tant

Max

imum

Thr

ough

put

Unc

ontro

lled

PTE

Con

trolle

d P

TElim

ited

cont

rolle

d P

TE

Em

issi

on S

ourc

eP

ollu

tant

Max

imum

Thr

ough

put

(per

Eng

ine)

Unc

ontro

lled

PTE

(all

engi

nes)

Con

trolle

d P

TE

(all

engi

nes)

limite

d co

ntro

lled

PTE

(all

engi

nes)

Hom

etow

n Bi

oEne

rgy

Emis

sion

Inve

ntor

y Se

ptem

ber

2011

Tabl

e A

- 1

Hom

etow

n B

ioEn

ergy

Air

Emis

sion

Inve

ntor

yJa

nuar

y 2

012

Sta

ckV

ent

Em

issi

onFa

ctor

Con

trol

Effi

cien

cyID

IDD

escr

iptio

n(u

nits

/hr)

(uni

ts/y

r)U

nits

(lb/U

nit)

(lb/h

r)(to

n/yr

)(%

)lb

/hr

ton/

yr(lb

/hr)

(ton/

yr)

Not

es

SV

002

EU

005

PM

1087

,600

MM

Btu

0.00

770.

080.

34-

0.08

0.34

0.08

0.34

[11]

PM

1010

87,6

00M

MB

tu0.

0077

0.08

0.34

-0.

080.

340.

080.

34[1

1]10

MM

Btu

/hr

PM

2.5

1087

,600

MM

Btu

0.00

770.

080.

34-

0.08

0.34

0.08

0.34

[11]

, [19

]P

ropa

ne-fi

red

SO

210

87,6

00M

MB

tu0.

016

0.16

0.72

-0.

160.

720.

160.

72[1

1], [

12]

NO

x10

87,6

00M

MB

tu0.

141.

426.

22-

1.42

6.22

1.42

6.22

[11]

VO

C10

87,6

00M

MB

tu0.

011

0.11

0.48

-0.

110.

480.

110.

48[1

1]C

O10

87,6

00M

MB

tu0.

082

0.82

3.59

-0.

823.

590.

823.

59[1

1]C

O2

(GH

G in

kg/

MM

Btu

)10

87,6

00M

MB

tu61

.46

614.

653

83.9

-61

4.60

5,38

3.9

614.

653

83.9

[13]

CH

4(G

HG

in k

g/M

MB

tu)

1087

,600

MM

Btu

0.00

300.

030.

26-

0.03

0.26

0.03

0.26

[13]

N2O

(GH

G in

kg/

MM

Btu

)10

87,6

00M

MB

tu0.

0006

0.01

0.05

-0.

010.

050.

010.

05[1

3]C

O2e

(GH

G in

kg/

MM

B10

87,6

00M

MB

tu61

.761

7.1

5405

.7-

617.

095,

405.

761

7.1

5405

.7[7

]

Sta

ckV

ent

Em

issi

onFa

ctor

Con

trol

Effi

cien

cyID

IDD

escr

iptio

n(u

nits

/hr)

(uni

ts/y

r)U

nits

(lb/U

nit)

(lb/h

r)(to

n/yr

)(%

)lb

/hr

ton/

yr(lb

/hr)

(ton/

yr)

Not

es

SV

004

EU

007

PM

0.00

544

MM

Btu

0.00

770.

0000

40.

0002

-0.

000.

0002

0.00

004

0.00

02[1

1]P

M10

0.00

544

MM

Btu

0.00

770.

0000

40.

0002

-0.

000.

000.

0000

40.

0002

[11]

PM

2.5

0.00

544

MM

Btu

0.00

770.

0000

40.

0002

-0.

000.

000.

0000

40.

0002

[11]

, [19

]S

O2

0.00

544

MM

Btu

0.01

60.

0001

0.00

04-

0.00

0.00

0.00

008

0.00

04[1

1], [

12]

NO

x0.

005

44M

MB

tu0.

140.

0007

0.00

31-

0.00

0.00

0.00

070.

0031

[11]

VO

C0.

005

44M

MB

tu0.

011

0.00

010.

0002

-0.

000.

000.

0000

50.

0002

[11]

CO

0.00

544

MM

Btu

0.08

0.00

040.

0018

-0.

000.

000.

0004

0.00

18[1

1]P

M75

657,

000

MM

Btu

0.00

760.

62.

5-

0.6

0.06

0.6

0.06

[23]

PM

1075

657,

000

MM

Btu

0.00

760.

62.

5-

0.6

0.06

0.6

0.06

[23]

PM

2.5

7565

7,00

0M

MB

tu0.

0076

0.6

2.5

-0.

60.

060.

60.

06[2

3]S

O2

7565

7,00

0M

MB

tu0.

0006

0.0

0.2

-0.

00.

000.

00.

00[2

3]N

Ox

7565

7,00

0M

MB

tu0.

100

7.5

32.9

-7.

50.

757.

50.

75[2

3]V

OC

7565

7,00

0M

MB

tu0.

0055

0.4

1.8

-0.

40.

040.

40.

04[2

3]C

O75

657,

000

MM

Btu

0.08

56.

427

.9-

6.4

0.64

6.4

0.64

[23]

CO

2(G

HG

in k

g/M

MB

tu)

7565

7,00

0M

MB

tu54

.71

4103

.335

944.

5-

4,10

3.3

410.

341

03.3

410.

3[1

3]C

H4

(GH

G in

kg/

MM

Btu

)75

657,

000

MM

Btu

0.00

100.

080.

66-

0.1

0.01

0.08

0.01

[13]

N2O

(GH

G in

kg/

MM

Btu

)75

657,

000

MM

Btu

0.00

010.

010.

07-

0.01

0.00

0.01

0.00

[13]

CO

2e(G

HG

in k

g/M

MB

tu)

7565

7,00

0M

MB

tu54

.841

07.2

3597

8.6

-4,

107.

241

0.7

4107

.241

0.7

[7]

Hig

hest

Sin

gle

HA

P

(For

mal

dehy

de)

18.4

416

1,53

4M

MB

tu0.

0000

740.

0054

0.02

380.

000.

0054

0.02

376

0.00

540.

0237

6[2

3]To

tal H

AP

18.4

416

1,53

4M

MB

tu0.

140.

598

0.00

0.14

0.60

0.14

0.59

8[2

3]

Boi

ler (

Hot

W

ater

)

Flar

e - p

ilot

gas

and

flarin

g em

issi

ons;

5,00

0 B

tu/h

r pr

opan

e pi

lot

75 M

MB

tu/h

r ca

paci

tydu

ring

emer

genc

yfir

ing

limite

d co

ntro

lled

PTE

Em

issi

on S

ourc

eP

ollu

tant

Max

imum

Thr

ough

put

Unc

ontro

lled

PTE

Con

trolle

d P

TElim

ited

cont

rolle

d P

TE

Em

issi

on S

ourc

eP

ollu

tant

Max

imum

Thr

ough

put

Unc

ontro

lled

PTE

Con

trolle

d P

TE

Hom

etow

n Bi

oEne

rgy

Emis

sion

Inve

ntor

y Se

ptem

ber

2011

Tabl

e A

- 1

Hom

etow

n B

ioEn

ergy

Air

Emis

sion

Inve

ntor

yJa

nuar

y 2

012

Em

issi

onFa

ctor

Con

trol

Effi

cien

cyN

otes

IDD

escr

iptio

n(u

nits

/hr)

(uni

ts/y

r)U

nits

(lb/U

nit)

(lb/h

r)(to

n/yr

)(%

)lb

/hr

ton/

yr(lb

/hr)

(ton/

yr)

Truc

k Tr

affic

PM

---

4,50

0V

MT

3.98

---

9.0

-9.

0--

-9

[15]

, [17

](R

aw M

ater

ial)

PM

10--

-4,

500

VM

T0.

80--

-1.

8-

1.8

---

2[1

5], [

17]

PM

2.5

---

4,50

0V

MT

0.20

---

0.4

-0.

4--

-0.

4[1

5], [

17]

Truc

k Tr

affic

PM

---

2,40

0V

MT

3.98

---

4.8

-4.

8--

-5

[16]

, [17

](L

iqui

d Fe

rtiliz

eP

M10

---

2,40

0V

MT

0.80

---

1.0

-1.

0--

-1

[16]

, [17

]P

M2.

5--

-2,

400

VM

T0.

20--

-0.

2-

0.2

---

0.2

[16]

, [17

]

FS00

2C

H4

(GH

G in

kg/

MM

Btu

)--

-5

acre

s--

---

-22

.4-

22.4

---

22[1

8]

CO

2e (G

HG

in k

g/M

MB

---

5ac

res

---

---

500.

2-

500.

2--

-50

0[1

8]

Insi

g.A

ctiv

ity

Rec

eivi

ngA

rea/

Pro

cess

Pla

nt to

B

iofil

ter

VO

C3.

0E+0

62.

6E+1

0cf

m-

0.8

3.5

900.

080.

350.

080.

31[2

0]

Tota

l em

issi

ons

by p

ollu

tant

:

(lb/h

r)(to

n/yr

)P

M1.

3919

.9P

M10

1.39

8.9

PM

2.5

1.39

6.8

SO

220

.39

89.3

NO

x21

.494

VO

C9

40C

O62

272

CO

2e (M

etric

tons

/yr)

9,63

884

,930

Hig

hest

Sin

gle

HA

P (F

orm

alde

hyde

)4

17To

tal H

AP

524

* U

ncon

trolle

d P

TE =

eng

ine

oper

atio

n w

ith n

o co

ntro

l equ

ipm

ent,

oper

atin

g 8,

760

hour

s/ye

ar*

Con

trolle

d P

TE =

eng

ine

oper

atio

n w

ith c

ontro

l equ

ipm

ent,

oper

atin

g 8,

760

hour

s/ye

ar*

Lim

ited

Con

trolle

d P

TE =

eng

ine

oper

atio

n w

ith c

ontro

l equ

ipm

ent,

oper

atin

g 7,

750

hour

s/ye

ar*

Max

imum

Sta

te P

erm

it E

mis

sion

s =

Rep

rese

nts

Fede

ral T

otal

Fac

ility

PTE

Thr

esho

lds

* 86

% o

f CO

2 is

bio

geni

c

10.0

25.0

100.

010

0.0

100.

010

0.0

100,

000.

0

Max

imum

Sta

te

Per

mit

Em

issi

ons

(ton/

yr)

100.

010

0.0

100.

0

20.6

89.2

44,3

98.8

6.1

8.9

17.0

6.0

4.0

8.5

55.3

Liqu

id B

y-P

rodu

ctLa

goon

Unc

ontro

lled

PTE

(Ent

ire F

acili

ty)

Con

trolle

d P

TE

(Ent

ire F

acili

ty)

(ton/

yr)

17.4

6.4

4.3

9.6

limite

d co

ntro

lled

PTE

FS00

1

Em

issi

on S

ourc

eP

ollu

tant

Max

imum

Thr

ough

put

Unc

ontro

lled

PTE

Con

trolle

d P

TE

61.6

23.3

100.

349

,361

.76.

89.

9

Lim

ited

Con

trolle

d P

TE (E

ntire

Fac

ility

)

(ton/

yr)

Hom

etow

n Bi

oEne

rgy

Emis

sion

Inve

ntor

y Se

ptem

ber

2011

Tabl

e A

- 1

Hom

etow

n B

ioEn

ergy

Air

Emis

sion

Inve

ntor

yJa

nuar

y 2

012

Not

es: [1

]

[2]

Num

ber o

f eng

ines

4M

axim

um O

pera

ting

Hou

rs p

er y

ear

8760

hrs/

engi

neE

stim

ated

Act

ual O

pera

ting

Hou

rs p

er y

ear

7,75

0hr

s/en

gine

[3]

[4]

[5]C

O2

Em

issi

on F

acto

r for

bio

gas

obta

ined

from

40

CFH

R 9

8 S

ubpa

rt C

Tab

le C

-1.

[6]N

2O E

mis

sion

fact

or fo

r bio

gas

obta

ined

from

40

CFR

98

Sub

part

C T

able

C-2

.[7

]Glo

bal W

arm

ing

Pot

entia

ls o

btai

ned

from

CFR

Titl

e 40

, Par

t 98,

Sub

part

C, T

able

A-1

.

CO

2 1

C

H4

21

N2O

31

0

[8]

CO

2 fro

m th

e en

gine

s is

the

resu

lt of

bio

gas

com

bust

ion

whi

ch is

not

cou

nted

for m

anda

tory

repo

rting

.[9

][1

0]

[11]

[12]

[13]

[14]

[Not

es c

ontin

ued

on n

ext p

age}

34%

of a

ir flo

w g

ener

ated

by

the

four

gen

erat

or e

ngin

es is

em

itted

thro

ugh

SV

003.

See

"Air

Flow

Dia

gram

" for

flow

rate

s. V

OC

em

issi

ons

incl

ude

a po

rtion

of

the

engi

nes

and

VO

Cs

from

the

drye

rs;

drye

r par

ticul

ate

emis

sion

s ar

e ne

glig

ible

from

a b

elt d

ryer

, par

ticul

ate

emis

sion

s fro

m th

e en

gine

s di

verte

d th

roug

h dr

yers

are

repr

esen

ted.

Pro

pane

em

issi

on fa

ctor

s fro

m A

P-4

2: 1

.5 L

ique

fied

Pet

role

um G

as C

ombu

stio

n, T

able

1.5

-1, c

onve

rted

to lb

/MM

Btu

usi

ng 9

1.5

MM

BTU

/1,0

00 g

al p

ropa

neS

ulfu

r con

cent

ratio

n ba

sed

on G

as P

roce

ssor

s A

ssoc

iatio

n E

ngin

eerin

g D

ata

Boo

k (N

inth

Edi

tion,

197

2), F

igur

e 15

-50

(GP

A L

ique

fied

Pet

role

um G

as

Spe

cific

atio

ns, r

ev. 1

979)

, Com

mer

cial

Pro

pane

= 1

5 gr

/100

scf

GH

G E

mis

sion

fact

ors

for p

ropa

ne o

btai

ned

from

40

CFR

98

Sub

part

C T

able

C-1

and

Tab

le C

-2.

Flar

es a

re n

ot in

lcud

ed in

GH

G e

mis

sion

s pe

r CFR

Titl

e 40

, Par

t 98,

Sub

part

C, p

ages

725

-726

.

HA

P e

mis

sion

fact

ors

and

calc

ulat

ions

can

be

foun

d in

Tab

le A

- 3

HA

P -

Eng

ines

Em

issi

on fa

ctor

s (P

M, P

M10

, NO

x, C

O, V

OC

(NM

HC

), C

H4)

fro

m m

anuf

actu

rer's

dat

a fo

r Cum

min

s Q

SV

91 s

erie

s en

gine

; Unc

ontro

lled

SO

2em

issi

ons

are

less

than

the

stat

e pe

rmit

thre

shol

d an

d ar

e ba

sed

on a

n H

2S c

once

ntra

tion

of 1

,000

ppm

in ra

w b

ioga

s. R

aw b

ioga

s is

con

ditio

ned

to re

mov

e 90

% o

f H2S

an

d to

redu

ce m

oist

ure

cont

ent t

o m

eet a

des

ired

fuel

gas

spe

cific

atio

n (S

ee A

pp G

), w

hich

incl

udes

an

H2S

con

cent

ratio

n of

100

ppm

.

Eng

ine

info

rmat

ion

for t

hrou

ghpu

t is

on "C

umm

ins

QS

V91

Info

" wor

shee

t tab

Max

imum

ann

ual t

hrou

ghpu

t and

est

imat

ed a

nnua

l thr

ough

put t

o ca

lcul

ate

PTE

and

Est

imat

ed E

mis

sion

s, re

spec

tivel

y, u

se th

e fo

llow

ing

annu

al h

ours

of

oper

atio

n:

66%

of a

ir flo

w g

ener

ated

by

the

four

gen

erat

or e

ngin

es is

em

itted

thro

ugh

SV

001.

The

rem

aini

ng p

ortio

n is

rout

ed to

the

Fuel

Dry

ing

and

Pre

para

tion

Dry

ers.

S

ee "A

ir Fl

ow D

iagr

am" f

or fl

ow ra

tes.

Inlc

udes

60

% c

ontro

l fro

m C

O c

atal

yst i

n C

ontro

lled

PTE

and

Est

imat

ed A

ctua

l PTE

to s

how

a c

onse

rvat

ive

emis

sion

est

imat

eC

O C

atal

yst s

peci

ficat

ions

pro

vide

90%

con

trol f

or C

O. C

atal

ytic

con

trol w

ill b

e a

surr

ogat

e fo

r org

anic

HA

P e

mis

sion

s. S

ee A

ppen

dix

G fo

r spe

cific

atio

ns.

CO2e

Con

vers

ion

Fact

ors

Hom

etow

n Bi

oEne

rgy

Emis

sion

Inve

ntor

y Se

ptem

ber

2011

Tabl

e A

- 1

Hom

etow

n B

ioEn

ergy

Air

Emis

sion

Inve

ntor

yJa

nuar

y 2

012 [15]

Max

thro

ughp

ut:

150,

000

tons

Qua

ntity

per

truc

k:25

tons

/truc

kN

umbe

r of t

ruck

s:6,

000

truck

s

Add

itio

inal

Cor

n S

ilage

Tru

cks

3,00

0tru

cks

Tota

l Raw

Mat

eria

l Tru

cks

9,00

0tru

cks

Mile

s tra

vele

d:0.

5m

iles/

truck

Tota

l Raw

Mat

eria

l Mile

age:

4,50

0V

MT

[16]

Max

imum

liqu

id fe

rtiliz

er s

hipp

ed b

y tru

ckV

olum

e of

Liq

uid

Ferti

lizer

Lag

oon:

gallo

nsC

apac

ity p

er tr

uck:

5,00

0ga

l/tru

ckN

umbe

r of t

ruck

s:4,

800

truck

sM

iles

trave

led:

0.5

mile

s/tru

ckTo

tal L

iqui

d Fe

rtiliz

er M

ileag

e:2,

400

VM

T[1

7]P

M/P

M10

Em

issi

ons

calc

ulat

ed u

sing

the

AP

-42

equa

tion

for P

aved

Roa

ds, C

hapt

er 1

3, S

ectio

n 2,

Equ

atio

n 1,

Jan

uary

201

1.E

mis

sion

Fac

tor =

k

* (s

L)0.

91 *

(W)1.

02

Var

iabl

eD

escr

iptio

nP

MP

M10

PM

2.5

k =

Par

ticle

siz

e m

ultip

lier f

or p

artic

le s

ize

rang

e an

d un

its o

f int

eres

t0.

011

0.00

220.

0005

4sL

=R

oad

surfa

ce s

ilt lo

adin

g*, g

/m2

15.8

15.8

15.8

W =

Ave

rage

wei

ght (

tons

) of t

he v

ehic

les

trave

ling

the

road

27.5

027

.50

27.5

Em

issi

on F

acto

r =E

mis

sion

Fac

tor (

lb/v

ehic

le m

iles

trave

led

(VM

T))

3.98

0.80

0.20

[18]

[19]

PM

2.5

is a

ssum

ed to

be

equa

l to

PM

10[2

0]

[21]

The

CO

2 em

issi

ons

repr

esen

t the

por

tion

of C

O th

at is

con

vert

ed to

CO

2 dur

ing

com

bust

ion.

[22]

[23]

200

hour

s/ye

ar

The

CO

2 em

issi

ons

com

bine

the

CO2 e

mis

sion

s ge

nera

ted

from

the

engi

nes

plus

the

CO2 e

mis

sion

s as

a r

esul

t of C

O c

onve

rsio

n du

ring

com

bust

ion

Bio

gas

bypa

ss c

ombu

stio

n ca

lcul

atio

ns fo

r the

flar

e us

e em

issi

on fa

ctor

s fro

m A

P-4

2: 1

.4 N

atur

al G

as C

ombu

stio

n, T

able

s 1.

4-1

thro

ugh

1.4-

4; u

sing

the

full

engi

ne c

apac

ity to

est

imat

e ga

s go

ing

to th

e fla

re is

con

serv

ativ

e be

caus

e th

e en

gine

s ar

e ex

pect

ed to

ope

rate

onl

y 12

-16

hour

s pe

r day

; fla

re is

lim

ited

to

200

hour

s of

ope

ratio

n pe

r yea

r.

Max

imum

thro

ughp

ut is

am

ount

of r

aw m

ater

ial d

eliv

ered

ann

ually

by

truck

.

Dur

ing

the

mon

ths

of A

ugus

t and

Sep

tem

ber,

swee

t cor

ns s

ilage

load

s w

ill b

e de

liver

ed 2

tim

es p

er h

our,

24 h

ours

a d

ay in

add

ition

to n

orm

ally

sch

edul

ed

deliv

erie

s

24,0

00,0

00

*Silt

load

ing

fact

or is

bas

ed o

n sa

mpl

ing

done

by

Bar

r at a

n et

hano

l pla

nt in

cen

tral I

owa.

The

val

ue is

the

aver

age

from

22

sam

plin

g ev

ents

in 2

006-

2008

. Th

e fa

cilit

y at

whi

ch th

e sa

mpl

es w

ere

take

n in

clud

ed a

90%

con

trol e

ffici

ency

due

to s

wee

ping

and

wat

erin

g. T

he fa

ctor

use

d he

re a

ssum

es n

o co

ntro

ls. T

he

fact

or u

sed

is w

ithin

the

rang

e of

indu

stria

l sou

rces

list

ed in

AP

-42.

Odo

r em

issi

ons

from

the

rece

ivin

g an

d pl

ant a

rea

vent

ilatio

n is

bas

ed o

n am

bien

t mea

sure

men

ts o

f odo

r com

poun

ds p

erfo

rmed

for v

eget

able

was

te

com

post

ing.

Thi

s is

a c

onse

rvat

ive

mea

sure

men

t for

Hom

etow

n B

ioE

nerg

y ra

w m

ater

ial r

ecei

pts

whi

ch w

ill a

rriv

e da

ily a

nd b

e pr

oces

sed

daily

. O

dor d

ata

take

n fro

m Q

uant

ifyin

g O

dour

Em

issi

on fr

om C

ompo

stin

g; P

. Hob

bs1,

R. N

oble

2, J

. Will

iam

s1, A

. Dob

rovi

n-P

enni

ngto

n2; 1

Inst

itute

of G

rass

land

and

E

nviro

nmen

tal R

esea

rch,

Nor

th W

yke

Res

earc

h S

tatio

n, O

keha

mpt

on,

Dev

on E

X20

2S

B 2

Hor

ticul

ture

Res

earc

h In

tern

atio

nal,

Wel

lesb

ourn

e, W

arw

ick.

C

V35

9E

F; S

usta

inab

le O

rgan

ic W

aste

Man

agem

ent f

or E

nviro

men

tal P

rote

ctio

n an

d Fo

od S

afet

y; T

able

1; P

age

239.

C

alcu

latio

n de

tail

prov

ided

in T

able

A-

6. 9

0% R

emov

al e

ffici

ency

Sou

rce:

Odo

ur C

ontro

l of F

ood

Pro

cess

ing

Ope

ratio

ns b

y A

ir C

lean

ing

Tech

nolo

gies

(Bio

filtra

tion)

Liqu

id F

ertil

izer

Lag

oon

GH

G E

mis

sion

s ca

lcul

atio

ns c

an b

e fo

und

in T

able

A -

5. E

mis

sion

s ar

e i

tit

Tabl

e A

-2H

omet

own

BioE

nerg

yIn

form

atio

n on

Cum

min

s N

atur

al g

as g

ener

ator

set

QSV

91 s

erie

s en

gine

, upd

ated

7/1

9/20

11Ja

nuar

y 2

012

RP

M15

14Em

issi

on S

pecs

wit

hout

CO

cat

alys

t*R

ated

Ele

ctric

al O

utpu

t (kW

e)1

2,00

0g/

hp-h

rlb

/hp-

hrD

uty

Cont

inuo

usPM

0.03

6.61

E-05

Com

pres

sion

Rat

io12

.5PM

100.

036.

61E-

05C

ycle

s P

er S

ec (H

ertz

)SO

20.

810

1.78

E-03

Cyl

inde

rsN

OX

0.5

1.10

E-03

Sta

rting

Sys

tem

NM

HC

0.23

5.07

E-04

RP

M15

14CO

2.2

4.85

E-03

Rat

ed E

lect

rical

Out

put (

kWe)

2,00

0CH

44.

469.

83E-

03B

rake

Hor

sepo

wer

2826

* pr

ovid

ed b

y Cu

mm

ins

Fuel

Inpu

t (M

MB

TU/H

r)18

.44

73.7

6C

alcu

late

d Fu

el In

put @

Ful

l Loa

d (B

TU/b

hp-h

r)65

25C

alcu

late

d Fu

el C

onsu

mpt

ion

Rat

e (c

f/hr)

42,9

84E

xhau

st G

as F

low

Mas

s (lb

/hr)

2777

1E

xhau

st G

as F

low

Vol

ume

(cfm

)15

212

Cal

ulat

ion

of S

O2

Em

issi

on F

acto

rN

otes

H2S

Con

tent

of r

aw d

iges

ter g

as (m

g H

2S/m

3)10

00Pr

ojec

t des

ign

basi

sE

lect

rical

out

put (

btu/

scf)

429

From

"Cu

mm

ins,

pos

t-pr

opos

al D

ocs,

7/2

6/11

" PD

F M

olec

ular

wei

ght o

f H2S

34.0

8g/

mol

Mol

ecul

ar w

eigh

t of S

O2

64.0

64g/

mol

cubi

c fe

et p

er c

ubic

met

er35

.314

7co

nver

sion

fact

orm

illig

ram

s pe

r gra

m10

00co

nver

sion

fact

or

SO

2 em

issi

on fa

ctor

0.81

0g/

bhp-

hr

** A

por

tion

of th

e en

gine

exh

aust

gas

will

be

rout

ed to

sup

ply

air f

low

to th

e dr

yers

. The

por

tion

not r

oute

d to

the

drye

rs w

ill b

e ro

uted

thro

ugh

SV

001

S

ee "

Air

Flo

w D

iagr

am"

1 gr

am =

15.

432

grai

ns30

8.64

gram

s/10

0cuf

tN

atur

al g

as h

as 2

0 gr

ains

per

100

ft3

3.08

64g/

ft3

108.

9807

84g/

m3

C200

0

Tabl

e A

-3H

omet

own

BioE

nerg

yN

SPS

JJJJ

Cal

cula

tion

sJa

nuar

y 2

012

Cum

min

s C2

000

Spec

sRP

M15

14

Rate

d El

ectr

ical

Out

put (

kWe)

12,

000

Dut

yCo

ntin

uous

Com

pres

sion

Rat

io12

.5Cy

cles

Per

Sec

(Her

tz)

Cylin

ders

Star

ting

Syst

emRP

M15

14Ra

ted

Elec

tric

al O

utpu

t (kW

e)2,

000

Brak

e H

orse

pow

er28

26Fu

el In

put (

MM

BTU

/Hr)

18.4

4Ca

lcul

ated

Fue

l Inp

ut @

Ful

l Loa

d (B

TU/b

hp-h

r)65

25Ca

lcul

ated

Fue

l Con

sum

ptio

n Ra

te (c

f/hr

)42

,984

Exha

ust G

as F

low

Mas

s (lb

/hr)

2777

1Ex

haus

t Gas

Flo

w V

olum

e (c

fm)

1521

2

Pollu

tant

NSP

S JJ

JJ E

mis

sion

St

anda

rd [1

]g/

HP-

hrlb

/hr

tpy

NO

x2.

012

.46

54.6

CO5.

031

.15

136.

4VO

C1.

06.

2327

.3

[1] S

ubpa

rt JJ

JJ T

able

1: L

andf

ill/D

iges

ter

Gas

HP

> 50

0, M

anuf

actu

re d

ate

afte

r 7/

1/20

10 E

mis

sion

Sta

ndar

ds[2

] Lim

ited

Emis

sion

s ca

lcul

ated

for

Form

GI-0

7

Lim

ited

Emis

sion

s pe

r en

gine

[2]

Table A-4Hometown BioEnergyHAP Emissions Calculations - EnginesJanuary 2012

HAP

EmissionFactor [1]

lb/MMBtu,fuel input

UncontrolledPTE,

each enginelb/hr

UncontrolledPTE -

combinedtpy

ControlEfficiency [2]

ControlledPTE - all

engines tpy

LimitedControlled

PTE [3]tpy

1,1,2,2-Tetrachloroethane 4.00E-05 7.38E-04 1.29E-02 60% 5.17E-03 4.57E-031,1,2-Trichloroethane 3.18E-05 5.86E-04 1.03E-02 60% 4.11E-03 3.64E-031,1-Dichloroethane 2.36E-05 4.35E-04 7.62E-03 60% 3.05E-03 2.70E-031,2-Dichloroethane 2.36E-05 4.35E-04 7.62E-03 60% 3.05E-03 2.70E-031,2-Dichloropropane 2.69E-05 4.96E-04 8.69E-03 60% 3.48E-03 3.08E-031,3-Butadiene 2.67E-04 4.92E-03 8.63E-02 60% 3.45E-02 3.05E-021,3-Dichloropropene 2.64E-05 4.87E-04 8.53E-03 60% 3.41E-03 3.02E-032-Methylnaphthalene 3.32E-05 6.12E-04 1.07E-02 60% 4.29E-03 3.80E-032,2,4-Trimethylpentane 2.50E-04 4.61E-03 8.08E-02 60% 3.23E-02 2.86E-02Acenaphthene 1.25E-06 2.31E-05 4.04E-04 60% 1.62E-04 1.43E-04Acenaphthylene 5.53E-06 1.02E-04 1.79E-03 60% 7.15E-04 6.32E-04Acetaldehyde 8.36E-03 1.54E-01 2.70E+00 60% 1.08E+00 9.56E-01Acrolein 5.14E-03 9.48E-02 1.66E+00 60% 6.64E-01 5.88E-01Benzene 4.40E-04 8.11E-03 1.42E-01 60% 5.69E-02 5.03E-02Benzo(b)fluoranthene 1.66E-07 3.06E-06 5.36E-05 60% 2.15E-05 1.90E-05Benzo(e)pyrene 4.15E-07 7.65E-06 1.34E-04 60% 5.36E-05 4.74E-05Benzo(g,h,i)perylene 4.14E-07 7.63E-06 1.34E-04 60% 5.35E-05 4.73E-05Biphenyl 2.12E-04 3.91E-03 6.85E-02 60% 2.74E-02 2.42E-02Carbon Tetrachloride 3.67E-05 6.77E-04 1.19E-02 60% 4.74E-03 4.20E-03Chlorobenzene 3.04E-05 5.61E-04 9.82E-03 60% 3.93E-03 3.48E-03Chloroethane 1.87E-06 3.45E-05 6.04E-04 60% 2.42E-04 2.14E-04Chloroform 2.85E-05 5.26E-04 9.21E-03 60% 3.68E-03 3.26E-03Chrysene 6.93E-07 1.28E-05 2.24E-04 60% 8.96E-05 7.92E-05Ethylbenzene 3.97E-05 7.32E-04 1.28E-02 60% 5.13E-03 4.54E-03Ethylene Dibromide 4.43E-05 8.17E-04 1.43E-02 60% 5.72E-03 5.06E-03Fluoranthene 1.11E-06 2.05E-05 3.59E-04 60% 1.43E-04 1.27E-04Fluorene 5.67E-06 1.05E-04 1.83E-03 60% 7.33E-04 6.48E-04Formaldehyde 0.05 0.97 1.71E+01 60% 6.82E+00 6.04E+00Methanol 2.50E-03 4.61E-02 8.08E-01 60% 3.23E-01 2.86E-01Methylene Chloride 2.00E-05 3.69E-04 6.46E-03 60% 2.58E-03 2.29E-03n-Hexane 1.11E-03 2.05E-02 3.59E-01 60% 1.43E-01 1.27E-01Naphthalene 7.44E-05 1.37E-03 2.40E-02 60% 9.61E-03 8.51E-03PAH 2.69E-05 4.96E-04 8.69E-03 60% 3.48E-03 3.08E-03Phenanthrene 1.04E-05 1.92E-04 3.36E-03 60% 1.34E-03 1.19E-03Phenol 2.40E-05 4.43E-04 7.75E-03 60% 3.10E-03 2.74E-03Pyrene 1.36E-06 2.51E-05 4.39E-04 60% 1.76E-04 1.55E-04Styrene 2.36E-05 4.35E-04 7.62E-03 60% 3.05E-03 2.70E-03Tetrachloroethane 2.48E-06 4.57E-05 8.01E-04 60% 3.20E-04 2.84E-04Toluene 4.08E-04 7.52E-03 1.32E-01 60% 5.27E-02 4.66E-02Vinyl Chloride 1.49E-05 2.75E-04 4.81E-03 60% 1.93E-03 1.70E-03Xylene 1.84E-04 3.39E-03 5.94E-02 60% 2.38E-02 2.10E-02Total HAP 1.33 23.3 9.3 8.26Highest Single HAP 0.97 17.1 6.8 6.04Notes:[1] HAP Emission factors from AP-42, Section 3.2, Table 3.2-2 for natural gas fired 4-stroke lean burn engines[2] Inlcudes 60 % control from CO catalyst in PTE and Estimated Emissions[3] Number of engines 4 Maximum Operating Hours per year 8760 hrs/engine Limited Operating Hours per year 7,750 hrs/engine

Table A-4Hometown BioEnergyHAP Emissions Calculations - Emergency Flare EmissionsJanuary 2012

HAP

Emission Factor [1]

lb/MMBtu, fuel input

UncontrolledPTE, bypass

from all engineslb/hr

Uncontrolled PTE - bypass from all

engines combinedtpy [2]

ControlEfficiency

Controlled PTE tpy

Limited / controlled tpy

Benzene 2.06E-06 1.52E-04 6.65E-04 - 6.65E-04 1.52E-05Dichlorobenzene 1.18E-06 8.68E-05 3.80E-04 - 3.80E-04 8.68E-06Formaldehyde 7.35E-05 5.42E-03 2.38E-02 - 2.38E-02 5.42E-04Hexane 1.76E-03 1.30E-01 5.70E-01 - 5.70E-01 1.30E-02Naphthalene 5.98E-07 4.41E-05 1.93E-04 - 1.93E-04 4.41E-06Toluene 3.33E-06 2.46E-04 1.08E-03 - 1.08E-03 2.46E-05Benzo(a)anthracene 1.76E-09 1.30E-07 5.70E-07 - 5.70E-07 1.30E-08Benzo(a)pyrene 1.18E-09 8.68E-08 3.80E-07 - 3.80E-07 8.68E-09Benzo(b)fluoranthene 1.76E-09 1.30E-07 5.70E-07 - 5.70E-07 1.30E-08Benzo(k)fluoranthene 1.76E-09 1.30E-07 5.70E-07 - 5.70E-07 1.30E-08Chrysene 1.76E-09 1.30E-07 5.70E-07 - 5.70E-07 1.30E-08Dibenzo(a,h)anthracene 1.18E-09 8.68E-08 3.80E-07 - 3.80E-07 8.68E-09Indeno(1,2,3-cd)pyrene 1.76E-09 1.30E-07 5.70E-07 - 5.70E-07 1.30E-08PAH Total 8.65E-08 6.38E-06 2.79E-05 - 2.79E-05 6.38E-07POM - Polycyclic organic ma 8.65E-08 6.38E-06 2.79E-05 - 2.79E-05 6.38E-07Arsenic (7440-38-2) 1.96E-07 1.45E-05 6.33E-05 - 6.33E-05 1.45E-06Beryllium (744-43-0-9) 1.18E-08 8.68E-07 3.80E-06 - 3.80E-06 8.68E-08Cadmium (7440-43-9) 1.08E-06 7.95E-05 3.48E-04 - 3.48E-04 7.95E-06Chromium 1.37E-06 1.01E-04 4.43E-04 - 4.43E-04 1.01E-05Cobalt 8.24E-08 6.07E-06 2.66E-05 - 2.66E-05 6.07E-07Manganese (74439-96-5) 3.73E-07 2.75E-05 1.20E-04 - 1.20E-04 2.75E-06Mercury (7439-97-6) 2.55E-07 1.88E-05 8.24E-05 - 8.24E-05 1.88E-06Nickel (7440-02-0) 2.06E-06 1.52E-04 6.65E-04 - 6.65E-04 1.52E-05Selenium (7782-49-2) 2.35E-08 1.74E-06 7.60E-06 - 7.60E-06 1.74E-07Total HAP 0.14 0.6 - 0.598 0.0137Highest Single HAP 0.13 0.6 - 0.570 0.0130

Notes:[1] HAP Emission factors from AP-42, Section 1.4, Tables 1.4-3 and 1.4-4 for natural gas fired 4-stroke lean burn engines[2] Maximum Fuel Throughput per engine = 18.44 MMBtu/hr PTE is limited to 200 flare operating hours per year[3] Number of engines 4 Maximum Flare Operating Hours per year 200 hrs Estimated Flare Actual Operating Hours pe 20 hrs

Table A-4aHometown BioEnergyHAP Emissions Calculations - DryerJanuary 2012

lb/hr tpy lb/hr tpy1,1,2,2-Tetrachloroethane 4.00E-05 34% 4.06E-04 1.78E-03 4.06E-04 1.57E-031,1,2-Trichloroethane 3.18E-05 34% 3.22E-04 1.41E-03 3.22E-04 1.25E-031,1-Dichloroethane 2.36E-05 34% 2.39E-04 1.05E-03 2.39E-04 9.27E-041,2-Dichloroethane 2.36E-05 34% 2.39E-04 1.05E-03 2.39E-04 9.27E-041,2-Dichloropropane 2.69E-05 34% 2.73E-04 1.19E-03 2.73E-04 1.06E-031,3-Butadiene 2.67E-04 34% 2.71E-03 1.19E-02 2.71E-03 1.05E-021,3-Dichloropropene 2.64E-05 34% 2.68E-04 1.17E-03 2.68E-04 1.04E-032-Methylnaphthalene 3.32E-05 34% 3.37E-04 1.47E-03 3.37E-04 1.30E-032,2,4-Trimethylpentane 2.50E-04 34% 2.53E-03 1.11E-02 2.53E-03 9.82E-03Acenaphthene 1.25E-06 34% 1.27E-05 5.55E-05 1.27E-05 4.91E-05Acenaphthylene 5.53E-06 34% 5.61E-05 2.46E-04 5.61E-05 2.17E-04Acetaldehyde 8.36E-03 34% 8.48E-02 3.71E-01 8.48E-02 3.28E-01Acrolein 5.14E-03 34% 5.21E-02 2.28E-01 5.21E-02 2.02E-01Benzene 4.40E-04 34% 4.46E-03 1.95E-02 4.46E-03 1.73E-02Benzo(b)fluoranthene 1.66E-07 34% 1.68E-06 7.37E-06 1.68E-06 6.52E-06Benzo(e)pyrene 4.15E-07 34% 4.21E-06 1.84E-05 4.21E-06 1.63E-05Benzo(g,h,i)perylene 4.14E-07 34% 4.20E-06 1.84E-05 4.20E-06 1.63E-05Biphenyl 2.12E-04 34% 2.15E-03 9.41E-03 2.15E-03 8.33E-03Carbon Tetrachloride 3.67E-05 34% 3.72E-04 1.63E-03 3.72E-04 1.44E-03Chlorobenzene 3.04E-05 34% 3.08E-04 1.35E-03 3.08E-04 1.19E-03Chloroethane 1.87E-06 34% 1.90E-05 8.30E-05 1.90E-05 7.35E-05Chloroform 2.85E-05 34% 2.89E-04 1.27E-03 2.89E-04 1.12E-03Chrysene 6.93E-07 34% 7.03E-06 3.08E-05 7.03E-06 2.72E-05Ethylbenzene 3.97E-05 34% 4.02E-04 1.76E-03 4.02E-04 1.56E-03Ethylene Dibromide 4.43E-05 34% 4.49E-04 1.97E-03 4.49E-04 1.74E-03Fluoranthene 1.11E-06 34% 1.13E-05 4.93E-05 1.13E-05 4.36E-05Fluorene 5.67E-06 34% 5.75E-05 2.52E-04 5.75E-05 2.23E-04Formaldehyde 0.05 34% 5.35E-01 2.34E+00 5.35E-01 2.07E+00Methanol 2.50E-03 34% 2.53E-02 1.11E-01 2.53E-02 9.82E-02Methylene Chloride 2.00E-05 34% 2.03E-04 8.88E-04 2.03E-04 7.86E-04n-Hexane 1.11E-03 34% 1.13E-02 4.93E-02 1.13E-02 4.36E-02Naphthalene 7.44E-05 34% 7.54E-04 3.30E-03 7.54E-04 2.92E-03PAH 2.69E-05 34% 2.73E-04 1.19E-03 2.73E-04 1.06E-03Phenanthrene 1.04E-05 34% 1.05E-04 4.62E-04 1.05E-04 4.09E-04Phenol 2.40E-05 34% 2.43E-04 1.07E-03 2.43E-04 9.43E-04Pyrene 1.36E-06 34% 1.38E-05 6.04E-05 1.38E-05 5.34E-05Styrene 2.36E-05 34% 2.39E-04 1.05E-03 2.39E-04 9.27E-04Tetrachloroethane 2.48E-06 34% 2.51E-05 1.10E-04 2.51E-05 9.74E-05Toluene 4.08E-04 34% 4.14E-03 1.81E-02 4.14E-03 1.60E-02Vinyl Chloride 1.49E-05 34% 1.51E-04 6.62E-04 1.51E-04 5.85E-04Xylene 1.84E-04 34% 1.87E-03 8.17E-03 1.87E-03 7.23E-03Total HAP 0.7 3.2 0.7 2.8Highest Single HAP 0.5 2.3 0.5 2.1Notes:[1] HAP Emission factors from AP-42, Section 3.2, Table 3.2-2 for natural gas fired 4-stroke lean burn engines[2] Emissions represented here are also represented in the engine HAP emissions for EU001 - EU004[3] Maximum Operating Hours per year 8760 Limited Hours 7,750

HAP

EmissionFactor [1]

lb/MMBtu,fuel input

Flow From Engines

Estimated Controlled PTE through SV003 (portion of

engine PTE included) [2], [3]

Limited PTE through SV003 (portion of engine PTE

included) [2], [3]

Tabl

e A

-5H

omet

own

Bio

Ener

gyM

ass

Bal

ance

Ja

nuar

y 2

012

Tota

lSo

lids

Solid

sVo

latil

eSo

lids

Iner

tsW

ater

Com

pute

dSo

lids

MTP

D [1

]%

MTP

D [1

]M

TPD

[1]

MTP

D [1

]M

TPD

[1]

%Fe

edst

ock

In32

5.0

23.0

%74

.867

.37.

525

0.3

23.0

%A

dd S

uper

nata

nt19

8.8

2.5%

3.8

2.3

1.5

195.

01.

9%A

fter S

uper

nata

nt A

dd52

3.8

78.6

69.6

9.0

445.

215

.0%

Not

Con

verte

d to

Met

hane

20.0

%10

0%D

iges

ter D

isch

arge

470.

05.

3%24

.815

.89.

044

5.2

5.3%

Pre

ssat

e fro

m P

ress

to D

ryer

47.3

30.0

%14

.29.

15.

233

.1P

ress

Wat

er42

2.7

2.5%

10.6

6.7

3.8

412.

1R

ecirc

Per

cent

0.5

Less

Rec

ircul

atio

n19

8.8

2.5%

5.0

3.2

1.8

193.

9W

ater

To

Land

App

licat

ion

223.

82.

5%5.

63.

62.

021

8.2

Rec

ircul

atio

n19

8.8

2.5%

3.8

2.3

1.5

195.

01.

9%S

olid

s Fl

ow to

Dry

er

47.3

30.0

%14

.29.

34.

933

.1H

eat F

low

req

per t

on o

f wat

er re

mov

ed (m

mbt

u/to

n)S

olid

Fue

l fro

m D

ryer

@ 9

0% S

olid

s15

.890

.0%

14.2

9.3

4.9

1.6

Hea

t Flo

w to

Dry

er @

120

0 bt

u/lb

of w

ater

eva

pW

ater

rem

oved

in d

ryer

31

.631

.6W

ater

rem

oved

in d

ryer

(lbs

/hr)

4340

.443

40.4

Flow

Fro

m B

elt P

ress

223.

82.

5%5.

63.

62.

021

8.2

Not

esA

nnua

l Sol

ids

to d

ryer

(tpy

)[2

]A

nnua

l Sol

ids

from

dry

er (t

py)

[3]

Wat

er re

mov

ed in

dry

er (L

/day

)V

OC

Con

tent

in w

ater

rem

oved

by

drye

r (m

g/L)

500

1000

#RE

F!V

OC

Con

tent

in w

ater

rem

oved

by

drye

r (lb

/L)

0.00

110.

0022

VO

C re

leas

ed (k

g/da

y)15

.831

.6V

OC

rele

ased

(MTP

D)

0.02

0.03

Max

VO

C e

mis

sion

s fro

m D

ryer

(tpy

)6.

312

.7#R

EF!

Not

es[1

]M

TPD

= m

etric

tonn

es p

er d

ay[4

] V

OC

's re

leas

ed fr

om th

e dr

yers

are

exp

ecte

d to

rang

e fro

m 5

00 m

g/L

to 1

000

mg/

L[2

]S

olid

s co

nten

t of s

tream

ent

erin

g dr

yers

is 3

0%[5

] M

ax V

OC

em

issi

ons

from

dry

er a

re b

ased

on

a V

OC

con

tent

of 1

000

mg/

L[3

]So

lids

cont

ent o

f str

eam

exi

ting

drye

rs is

90%

Dry

er

Land

App

licat

ion

Dry

er V

OC

Em

issi

ons

Der

ivat

ion

VOC

Bal

ance

19,0

116,

337

31,5

66

Dig

este

rs

Bel

t Pre

ss

Tabl

e A

-6H

omet

own

Bio

Ener

gyPo

tent

ial t

o Em

it G

reen

hous

e G

as C

alcu

latio

ns -

Liqu

id S

tora

ge P

ond

Janu

ary

201

2

Dig

este

d Li

quid

Man

ure

Bas

ins:

Val

ueS

ourc

eV

olat

ile S

olid

s Lo

adin

g to

Bas

ins,

afte

r dig

estio

n an

d so

lids

sepa

ratio

n (k

g V

S/y

r) =

1,30

1,46

3Ta

ble

A-6

Max

imum

met

hane

pro

duci

ng c

apac

ity o

f vol

atile

sol

ids

(m3C

H4/k

g V

S) =

0.24

[1]

Vol

ume

of m

etha

ne (m

3/yr

) =31

2,35

1C

arbo

n D

ioxi

de d

ensi

ty a

t STP

(kg/

m3 ) =

1.80

Met

hane

den

sity

at S

TP (k

g/m

3 ) =0.

65A

nnua

l Bas

in T

empe

ratu

re (o C

) =10

[1]

Met

hane

con

vers

ion

fact

or b

ased

on

T, fo

r cru

st-c

over

ed b

asin

s (%

) =10

%[2

]M

etha

ne C

arbo

n In

tens

ity F

acto

r =21

% T

otal

Are

aC

H4 (

tpy)

CO

2 [3]

(tpy

)C

O2e

(tpy

)10

0.00

%22

.430

.250

0.2

[2] A

lthou

gh th

e st

orag

e ba

sin

does

not

hav

e a

"cru

st c

over

", it

will

hav

e a

synt

hetic

cov

er.

The

met

hane

con

vers

ion

fact

or fo

r cru

st-c

over

ed s

ettli

ng b

asin

s is

ther

efor

e ap

plie

d.

[3] C

arbo

n di

oxid

e em

issi

ons

from

bio

gas

gene

ratio

n in

the

basi

n is

bas

ed o

n a

volu

met

ric fr

actio

n of

74%

met

hane

in th

e bi

ogas

, whi

ch im

plie

s 26

% c

arbo

n di

oxid

e by

diff

eren

ce.

Saf

ley

L.

M. a

nd W

este

rman

P. W

. 199

2. P

erfo

rman

ce o

f a lo

w te

mpe

ratu

re la

goon

dig

este

r. B

iore

sour

ce T

echn

olog

y 41

(2):

167-

175.

Var

iabl

e

Bas

inS

urfa

ce A

rea

(ft2 )

Mem

bran

e C

over

ed S

tora

ge P

ond

217,

800

[1] D

ata

take

n fro

m 4

0 C

FR 9

8 S

ubpa

rt JJ

Tab

les

JJ-2

,JJ-

3, a

nd J

J-4.

Scr

ew p

ress

es fo

r sol

ids

sepa

ratio

n.

Figu

re A

-7H

omet

own

Bio

Ener

gyEn

gine

/Dry

er A

ir Fl

ow D

iagr

amJa

nuar

y 2

012

Exh

aust

flow

to E

ngin

e S

tack

72,9

14

Lb

s/hr

@ 8

43 F

Cum

min

s C

2000

N6C

2000

KW

Gen

set

Cum

min

s C

2000

N6C

2000

KW

Gen

set

Cum

min

s C

2000

N6C

2000

KW

Gen

set

27,7

71 lb

s/hr

@ 8

43 F

27,7

71 lb

s/hr

@ 8

43 F

27,7

71 lb

s/hr

@ 8

43 F

Total Exhaust Flow =111,084 lbs/hr @ 843 F

Exh

aust

to D

ryer

38

,170

lbs/

hr @

843

Amb Air 29,756 lbs/hr @ 60 F

Hea

ted

air t

o D

ryer

67,9

26 lb

/hr @

500

FD

iges

tate

Dry

er4,

213

lbs/

hr w

ater

re

mov

ed

Dry

er E

xhau

st72

,139

lbs/

hr @

149

F

Ava

nt E

nerg

y

Cum

min

s C

2000

N6C

2000

KW

Gen

set

Cum

min

s C

2000

N6C

2000

KW

Gen

set

27,7

71 lb

s/hr

@ 8

43 F

27,7

71 lb

s/hr

@ 8

43 F

Total Exhaust Flow =111,084 lbs/hr @ 843 F

Ava

nt E

nerg

y

Tabl

e A

-8H

omet

own

Bio

Ener

gyR

ecei

ving

and

Pla

nt A

rea

Vent

ilatio

n O

dor E

mis

sion

s Es

timat

eJa

nuar

y 2

012

Com

poun

ds w

hich

wer

e fo

und

with

GC-

MS

to e

xcee

d th

eir

OD

T by

the

grea

test

ord

er o

fm

agni

tude

wer

e, in

dec

reas

ing

orde

r: H

2S, D

MS,

but

anoi

c ac

id, m

etha

neth

iol a

nd tr

imet

hyla

min

e.Su

lphi

des

wer

e th

e m

ajor

com

pone

nts

cont

ribu

ting

tow

ards

the

odou

r. T

here

was

a c

lear

rela

tions

hip

betw

een

the

com

bine

d co

ncen

trat

ion

of H

2S a

nd D

MS

to th

e ol

fact

ory

resp

onse

.

Ass

umed

Cont

rolle

dCm

pdPr

ewet

(ug/

m3)

Phas

e I (

ug/m

3)ug

/m3

Flow

rate

(cfm

)lb

/hr

Unc

PTE

PTE

(90%

)**

Buta

noic

aci

d 48

1 (5

) 212

9(±3

271)

14.

4 ra

ncid

, sou

r48

150

000

0.09

0.39

0.04

Dim

ethy

l sul

phid

e 16

67(±

3290

)352

8(±6

921)

5.9

dec

ayed

veg

etab

le16

6750

000

0.31

1.37

0.14

Dim

ethy

l dis

ulph

ide

657(

±162

6)28

7(±8

96) 4

7.9

foul

657

5000

00.

120.

540.

05D

imet

hyl t

risu

lphi

de 8

3(±1

70)1

30(±

292)

8.7

8350

000

0.02

0.07

0.01

Hyd

roge

n su

lphi

de 7

30(±

1310

)436

2(±5

369)

25.

7 ro

tten

egg

730

5000

00.

140.

600.

06M

etha

neth

iol2

11(±

246)

126

(±16

5) 2

.1 r

otte

n ca

bbag

e21

150

000

0.04

0.17

0.02

Trim

ethy

lam

ine

435(

3) 5

82(±

924)

5.9

am

mon

ical

, fis

hy43

550

000

0.08

0.36

0.04

Tota

l:42

640.

803.

50.

3

† m

ean

and

± st

anda

rd d

evia

tion

of 1

1 co

mpo

stin

g si

te s

ampl

es; c

ompo

unds

with

out s

tand

ard

devi

atio

ns w

ere

iden

tifie

din

less

than

six

sam

ples

, num

ber

show

n in

ital

ics.

*mea

sure

d w

ith g

as d

etec

tion

tube

s.**

90%

Rem

oval

eff

icie

ncy

Sour

ce: O

dour

Con

trol

of F

ood

Proc

essi

ng O

pera

tions

by

Air

Cle

anin

g Te

chno

logi

es (B

iofil

trat

ion)

: ht

tp:/

/ww

w.c

ip.u

kcen

tre.

com

/sm

ell.h

tm: T

able

V

Qua

ntify

ing

Odo

ur E

mis

sion

from

Com

post

ing;

P. H

obbs

1, R

. Nob

le2,

J. W

illia

ms1

, A. D

obro

vin-

Penn

ingt

on2;

1In

stit

ute

of G

rass

land

and

En

viro

nmen

tal R

esea

rch,

Nor

th W

yke

Rese

arch

Sta

tion

, Oke

ham

pton

, D

evon

EX2

0 2S

B 2H

orti

cult

ure

Rese

arch

Inte

rnat

iona

l, W

elle

sbou

rne,

War

wic

k. C

V35

9EF

; Sus

tain

able

Org

anic

Was

te M

anag

emen

t for

Env

irom

enta

l Pro

tect

ion

and

Food

Saf

ety;

Tab

le 1

; Pag

e23

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Source�Type Point Point PointEmission�rate�(g/s) 1 1 1Stack�Height�(m) 15.2 15.2 15.2Stack�Inside�Diameter�(m) 0.9 0.9 0.9Stack�Inside�Velocity�(m/s) 43.7 28.9 14.9Stack�Gas�Exit�Temp�(K) 723.7 723.7 338.2Ambient�Air�Temp�(K) 293 293 293Receptor�Height 0 0 0Urban/Rural�Option Rural Rural RuralBuilding�Height�(m) 12.3 12.3 12.3Min�Horiz�Bldg�Dim�(m) 17.7 17.7 17.7Max�Horiz�Bldg�Dim�(m) 30.5 30.5 30.5Min�Receptor�Distance�(m) 61.0 61.0 42.7Max�Receptor�Distance�(m) 1000 1000 1000

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723 K with no engine diversion 2-14-12.txtScenario 1 - All flow through Engine Stack SV001

02/14/12 09:52:12 *** SCREEN3 MODEL RUN *** *** VERSION DATED 96043 ***

Scenario 1 - All Flow through Engine Stack SV001

SIMPLE TERRAIN INPUTS: SOURCE TYPE = POINT EMISSION RATE (G/S) = 1.00000 STACK HEIGHT (M) = 15.2000 STK INSIDE DIAM (M) = .9000 STK EXIT VELOCITY (M/S)= 43.7000 STK GAS EXIT TEMP (K) = 723.7000 AMBIENT AIR TEMP (K) = 293.0000 RECEPTOR HEIGHT (M) = .0000 URBAN/RURAL OPTION = RURAL BUILDING HEIGHT (M) = 12.3000 MIN HORIZ BLDG DIM (M) = 17.7000 MAX HORIZ BLDG DIM (M) = 30.5000

THE REGULATORY (DEFAULT) MIXING HEIGHT OPTION WAS SELECTED. THE REGULATORY (DEFAULT) ANEMOMETER HEIGHT OF 10.0 METERS WAS ENTERED.

BUOY. FLUX = 51.644 M**4/S**3; MOM. FLUX = 156.566 M**4/S**2.

*** FULL METEOROLOGY ***

********************************** *** SCREEN AUTOMATED DISTANCES *** **********************************

*** TERRAIN HEIGHT OF 0. M ABOVE STACK BASE USED FOR FOLLOWING DISTANCES ***

DIST CONC U10M USTK MIX HT PLUME SIGMA SIGMA (M) (UG/M**3) STAB (M/S) (M/S) (M) HT (M) Y (M) Z (M) DWASH ------- ---------- ---- ----- ----- ------ ------ ------ ------ ----- 61. 50.66 4 15.0 16.0 4800.0 15.52 5.19 7.14 SS 100. 54.79 4 15.0 16.0 4800.0 16.03 8.20 8.96 SS 200. 37.02 4 15.0 16.0 4800.0 18.08 15.56 12.85 SS 300. 23.86 4 15.0 16.0 4800.0 20.69 22.61 15.98 SS 400. 16.60 4 15.0 16.0 4800.0 23.47 29.45 18.98 SS 500. 12.26 4 15.0 16.0 4800.0 26.26 36.15 21.87 SS 600. 9.770 4 15.0 16.0 4800.0 28.36 42.72 24.68 SS 700. 8.656 4 15.0 16.0 4800.0 28.36 49.19 27.41 SS 800. 7.645 4 15.0 16.0 4800.0 28.36 55.57 30.08 SS 900. 6.846 4 15.0 16.0 4800.0 28.36 61.88 30.74 SS 1000. 6.124 4 15.0 16.0 4800.0 28.36 68.13 33.08 SS

MAXIMUM 1-HR CONCENTRATION AT OR BEYOND 61. M: 92. 55.00 4 15.0 16.0 4800.0 15.92 7.67 8.63 SS

Page 1

723 K with engine diversion 2-14-12.txtScenario 2 - 66% of engine flow through Engine Stack SV001


Scenario 2 - 66% of engine flow through Engine Stack SV001









Page 1

338 K with engine diversion to dryer stack 2-14-12.txtScenario 2 - 34% of the Engine Flow through Dryer Stack SV003


Scenario 2 - 34% of the Engine Flow through Dryer Stack SV003









Page 1

Attachment 3 - EPA Letter to Riverview LLC

Attachment 4 – Biofilter O&M Plan

C:\Documents and Settings\alenshe\Local Settings\Temporary Internet Files\Content.Outlook\498MES1I\Hometown BioEnergy - Biofilter OM Plan.docx

Hometown BioEnergy Biofilter O&M Plan

(January 2012)

1. Maintain manual of biofilter system design plans and recommended operation parameters

2. Perform and record monthly biofilter inspection results for:

a. biofilter containment integrity

b. gas stream connection to biofilter

c. biofilter temperature and moisture level

d. pressure drop across the media bed; replace media if pressure drop exceeds recommended range

e. presence of rodents/pests and possible short-circuiting of the media via tunnels in the media; treat for infestations and work the media to eliminate any channeling of the gas stream

f. presence of weeds

3. Conduct ongoing checks for excessive odor on a weekly basis. If excessive odor is detected, conduct a biofilter inspection. Record remedial actions taken to reestablish effective odor control.

Attachment 5 - CD-01 Forms and Facility Description

MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194 COMPLIANCE PLAN CD-01

Facility Name: Hometown BioEnergy


3 May, 2012 10:14Page 1 of 12

Subject Item: Total Facility

NC/CA

Type Citation Requirement

CD hdr SOURCE-SPECIFIC REQUIREMENTS1.0

CD Minn. R. 7007.0800, subp. 2 Permit Appendices: This permit contains two appendices as listed in the permitTable of Contents. The Permittee shall comply with all requirements contained inthe appendices.

2.0

CD Title I Condition: To avoid majorsource classification under 40CFR Section 70.2 and Minn. R.7007.0200




3.0





4.0

CD hdr OPERATIONAL REQUIREMENTS5.0

CD Minn. R. 7011.0020 Circumvention: Do not install or use a device or means that conceals or dilutesemissions, which would otherwise violate a federal or state air pollution control rule,without reducing the total amount of pollutant emitted.

6.0

CD Minn. R. 7007.0800, subp. 2;Minn. R. 7007.0800, subp. 16(J)

Air Pollution Control Equipment: Operate all pollution control equipment wheneverthe corresponding process equipment and emission units are operated.

7.0

CD Minn. R. 7007.0800, subps. 14and 16(J)

Operation and Maintenance Plan: Retain at the stationary source an operation andmaintenance plan for all air pollution control equipment. At a minimum, the O & Mplan shall identify all air pollution control equipment and control practices and shallinclude a preventative maintenance program for the equipment and practices, adescription of (the minimum but not necessarily the only) corrective actions to betaken to restore the equipment and practices to proper operation to meet applicablepermit conditions, a description of the employee training program for properoperation and maintenance of the control equipment and practices, and the recordskept to demonstrate plan implementation.

8.0

CD Minn. R. 7019.1000, subp. 4 Operation Changes: In any shutdown, breakdown, or deviation the Permittee shallimmediately take all practical steps to modify operations to reduce the emission ofany regulated air pollutant. The Commissioner may require feasible and practicalmodifications in the operation to reduce emissions of air pollutants. No emissionsunits that have an unreasonable shutdown or breakdown frequency of process orcontrol equipment shall be permitted to operate.

9.0

CD Minn. R. 7011.0150 Fugitive Emissions: Do not cause or permit the handling, use, transporting, orstorage of any material in a manner which may allow avoidable amounts ofparticulate matter to become airborne. Comply with all other requirements listed inMinn. R. 7011.0150.

10.0

CD Minn. R. 7030.0010 - 7030.0080 Noise: The Permittee shall comply with the noise standards set forth in Minn. R.7030.0010 to 7030.0080 at all times during the operation of any emission units.This is a state only requirement and is not enforceable by the EPA Administrator orcitizens under the Clean Air Act.

11.0

CD Minn. R. 7007.0800, subp. 9(A) Inspections: The Permittee shall comply with the inspection procedures andrequirements as found in Minn. R. 7007.0800, subp. 9(A).

12.0

CD Minn. R. 7007.0800, subp. 16 The Permittee shall comply with the General Conditions listed in Minn. R.7007.0800, subp. 16.

13.0




3 May, 2012 10:14Page 2 of 12

CD hdr PERFORMANCE TESTING14.0

CD Minn. R. ch. 7017 Performance Testing: Conduct all performance tests in accordance with Minn. R.ch. 7017 unless otherwise noted in Tables A, B, and/or C.

15.0

CD Minn. R. 7017.2018; Minn. R.7017.2030, subps. 1-4, Minn. R.7017.2035, subps. 1-2

Performance Test Notifications and Submittals:

Performance Tests are due as outlined in Table A of the permit.See Table B for additional testing requirements.

Performance Test Notification (written): due 30 days before each Performance TestPerformance Test Plan: due 30 days before each Performance TestPerformance Test Pre-test Meeting: due 7 days before each Performance TestPerformance Test Report: due 45 days after each Performance TestPerformance Test Report - Microfiche Copy: due 105 days after each PerformanceTest

The Notification, Test Plan, and Test Report may be submitted in an alternativeformat as allowed by Minn. R. 7017.2018.

16.0

CD Minn. R. 7017.2025, subp. 3 Limits set as a result of a performance test (conducted before or after permitissuance) apply until superseded as stated in the MPCA's Notice of Complianceletter granting preliminary approval. Preliminary approval is based on formal reviewof a subsequent performance test on the same unit as specified by Minn. R.7017.2025, subp. 3. The limit is final upon issuance of a permit amendmentincorporating the change.

17.0

CD hdr MONITORING REQUIREMENTS18.0

CD Minn. R. 7007.0800, subp. 4(D) Monitoring Equipment Calibration: The Permittee shall calibrate all requiredmonitoring equipment at least once every 12 months (any requirements applying tocontinuous emission monitors are listed separately in this permit).

19.0

CD Minn. R. 7007.0800, subp. 4(D) Operation of Monitoring Equipment: Unless otherwise noted in Tables A, B, and/orC, monitoring a process or control equipment connected to that process is notnecessary during periods when the process is shutdown, or during checks of themonitoring systems, such as calibration checks and zero and span adjustments. Ifmonitoring records are required, they should reflect any such periods of processshutdown or checks of the monitoring system.

20.0

CD hdr RECORDKEEPING21.0

CD Minn. R. 7007.0800, subp. 5(C) Recordkeeping: Retain all records at the stationary source, unless otherwisespecified within this permit, for a period of five (5) years from the date of monitoring,sample, measurement, or report. Records which must be retained at this locationinclude all calibration and maintenance records, all original recordings forcontinuous monitoring instrumentation, and copies of all reports required by thepermit. Records must conform to the requirements listed in Minn. R. 7007.0800,subp. 5(A).

22.0

CD Minn. R. 7007.0800, subp. 5(B) Recordkeeping: Maintain records describing any insignificant modifications (asrequired by Minn. R. 7007.1250, subp. 3) or changes contravening permit terms (asrequired by Minn. R. 7007.1350, subp. 2), including records of the emissionsresulting from those changes.

23.0

CD Minn. R. 7007.1200, subp. 4 If the Permittee determines that no permit amendment or notification is requiredprior to making a change, the Permittee must retain records of all calculationsrequired under Minn. R. 7007.1200. For nonexpiring permits, these records shall bekept for a period of five years from the date that the change was made. The recordsshall be kept at the stationary source for the current calendar year of operation andmay be kept at the stationary source or office of the stationary source for all otheryears. The records may be maintained in either electronic or paper format.

24.0

CD hdr REPORTING/SUBMITTALS25.0

CD Minn. R. 7019.1000, subp. 3 Shutdown Notifications: Notify the Commissioner at least 24 hours in advance of aplanned shutdown of any control equipment or process equipment if the shutdownwould cause any increase in the emissions of any regulated air pollutant. If theowner or operator does not have advance knowledge of the shutdown, notificationshall be made to the Commissioner as soon as possible after the shutdown.However, notification is not required in the circumstances outlined in Items A, Band C of Minn. R. 7019.1000, subp. 3.

At the time of notification, the owner or operator shall inform the Commissioner ofthe cause of the shutdown and the estimated duration. The owner or operator shallnotify the Commissioner when the shutdown is over.

26.0




3 May, 2012 10:14Page 3 of 12

CD Minn. R. 7019.1000, subp. 2 Breakdown Notifications: Notify the Commissioner within 24 hours of a breakdownof more than one hour duration of any control equipment or process equipment ifthe breakdown causes any increase in the emissions of any regulated air pollutant.The 24-hour time period starts when the breakdown was discovered or reasonablyshould have been discovered by the owner or operator. However, notification is notrequired in the circumstances outlined in Items A, B and C of Minn. R. 7019.1000,subp. 2.

At the time of notification or as soon as possible thereafter, the owner or operatorshall inform the Commissioner of the cause of the breakdown and the estimatedduration. The owner or operator shall notify the Commissioner when the breakdownis over.

27.0

CD Minn. R. 7019.1000, subp. 1 Notification of Deviations Endangering Human Health or the Environment: As soonas possible after discovery, notify the Commissioner or the state duty officer, eitherorally or by facsimile, of any deviation from permit conditions which could endangerhuman health or the environment.

28.0

CD Minn. R. 7019.1000, subp. 1 Notification of Deviations Endangering Human Health or the Environment Report:Within 2 working days of discovery, notify the Commissioner in writing of anydeviation from permit conditions which could endanger human health or theenvironment. Include the following information in this written description:1. the cause of the deviation;2. the exact dates of the period of the deviation, if the deviation has been corrected;3. whether or not the deviation has been corrected;4. the anticipated time by which the deviation is expected to be corrected, if not yetcorrected; and5. steps taken or planned to reduce, eliminate, and prevent reoccurrence of thedeviation.

29.0

S/A Minn. R. 7007.0800, subp. 6(A)(2) Semiannual Deviations Report: due 30 days after end of each calendar half-yearfollowing Permit Issuance. The first semiannual report submitted by the Permitteeshall cover the calendar half-year in which the permit is issued. The first report ofeach calendar year covers January 1 - June 30. The second report of eachcalendar year covers July 1 - December 31. If no deviations have occurred, thePermittee shall submit the report stating no deviations.

30.0

CD Minn. R. 7007.1150 - 7007.1500 Application for Permit Amendment: If a permit amendment is needed, submit anapplication in accordance with the requirements of Minn. R. 7007.1150 throughMinn. R. 7007.1500. Submittal dates vary, depending on the type of amendmentneeded.

31.0

CD Minn. R. 7007.1400, subp. 1(H) Extension Requests: The Permittee may apply for an Administrative Amendment toextend a deadline in a permit by no more than 120 days, provided the proposeddeadline extension meets the requirements of Minn. R. 7007.1400, subp. 1(H).Performance testing deadlines from the General Provisions of 40 CFR pt. 60 andpt. 63 are examples of deadlines for which the MPCA does not have authority togrant extensions and therefore do not meet the requirements of Minn. R.7007.1400, subp. 1(H).

32.0

S/A Minn. R. 7007.0800, subp. 6(C) Compliance Certification: due 31 days after end of each calendar year followingPermit Issuance (for the previous calendar year). The Permittee shall submit this tothe Commissioner on a form approved by the Commissioner. This report covers alldeviations experienced during the calendar year.

33.0

CD Minn. R. 7019.3000 - 7019.3100 Emission Inventory Report: due on or before April 1 of each calendar year followingpermit issuance, to be submitted on a form approved by the Commissioner.

34.0

CD Minn. R. 7002.0005 - 7002.0095 Emission Fees: due 60 days after receipt of an MPCA bill.35.0




3 May, 2012 10:14Page 4 of 12

Subject Item: GP 001 Generator Engines

Associated Items: EU 001 Generator Engine




NC/CA


CD hdr EMISSION LIMITS1.0

LIMIT Minn. R. 7011.2300, subp. 1 Opacity: less than or equal to 20 percent once operating temperatures have beenattained.

2.0

LIMIT Minn. R. 7011.2300, subp. 2 Sulfur Dioxide: less than or equal to 0.50 lbs/million Btu heat input . The potentialto emit from the unit is 0.21 lb/MMBtu due to equipment design and allowable fuels.

3.0

LIMIT Minn. R. 7005.0100, subp. 35a; 40CFR 241.3; Minn. R. 7011.2300,subp. 2; Minn. Stat. Section116.07, subds. 4a & 9; Minn. R.7007.0100, subp. 7(A), 7(L), &7(M); Minn. R. 7007.0800, subps.1, 2 & 4; Minn. R.7009.0010-7009.0080

Hydrogen Sulfide: less than or equal to 300 parts per million in conditioned biogas.4.0

LIMIT Title I Condition: To avoid majorsource classification under 40CFR Section 70.2 and Minn. R.7007.0200

Operating Hours: less than or equal to 31,000 hours/year total for the fourgenerator engines (EU 001, EU 002, EU 003, EU 004), calculated monthly by thelast day of each month. This limit may be revised through a major amendmentbased on results from CO emission factor testing required by this permit.

During the initial 12 months of operation, the applicable operating hours limit as ofmonth 'n' shall be the following:

month 1 = 2,976 hrsmonth 2 = 5,856 hrsmonth 3 = 8,832 hrsmonth 4 = 11,712 hrsmonth 5 = 14,688 hrsmonth 6 = 17,568 hrsmonth 7 = 20,544 hrsmonth 8 = 23,424 hrsmonth 9 = 26,400 hrsmonth 10 = 29,280 hrsmonth 11 = 30,140 hrsmonth 12 = 31,000 hrs

5.0

CD hdr OPERATING CONDITIONS6.0




7.0




8.0




3 May, 2012 10:14Page 5 of 12

CD Title I Condition: To avoid majorsource classification under 40CFR Section 70.2 and Minn. R.7007.0200; Minn. R. 7005.0100,subp. 35a

Fuel Usage: limited to biogas produced onsite through anaerobic digestion ofapproved feedstock material defined below.

9.0

CD 40 CFR Section 241 Materials authorized in this permit as feedstock:Agricultural material including: vegetable processing residuals, silage, manure,grasses, hays, snack foods, cereals, and cellulosic biomass.

10.0

CD Title I Condition: To avoidclassification as major sourceunder 40 CFR Section 70.2 andMinn. R. 7007.0200, Minn. R.7007.0800, subps. 2 and 14

The Permittee shall operate and maintain the catalysts (CE 001-004) any time thatany process equipment controlled by the engine catalyst is in operation. ThePermittee shall document periods of non-operation of the control equipment.See GP 002 for control equipment requirements.

11.0

CD Title I Condition: To avoid majorsource classification under 40CFR Section 70.2 and Minn. R.7007.0200; 40 CFR Section60.4243(a)(2)(iii)

The engines in this group (EU 001, EU 002, EU 003, EU 004) separately must beequipped with non-resettable hour meters.

12.0

CD hdr FUEL TESTING REQUIREMENTS13.0

S/A Minn. R. 7007.0800, subp. 4 Initial Fuel Analysis: due 30 days after Initial Startup. Analysis of conditionedbiogas for hydrogen sulfide (H2S) following ASTM Method D-5504 and EPAMethod 18.

Fuel sample must be obtained from the fuel feed pipe to the engines. For the initialfuel analysis only: laboratory sample analysis shall performed to confirm onsitesample analysis.

14.0

S/A Minn. R. 7007.0800, subp. 4 Fuel Analysis: due 30 days after Initial Fuel Analysis for H2S following ASTMMethod D-5504 and EPA Method 18. Fuel sample must be obtained from the fuelfeed pipe to the engines.

After a total of 12 sampling events, fuel sampling and analysis may be changed toquarterly sampling if the monthly data results are below 150 ppm.

15.0

CD Minn. R. 7007.0800, subp. 4 Additional Fuel Analysis for H2S when the digester feedstock makeup changes by30% or more on a dry weight basis following ASTM Method D-5504 and EPAMethod 18.

16.0

CD hdr PERFORMANCE TESTING17.0

S/A Minn. R. 7017.2020, subp. 1 Initial Performance Test: due 90 days after Initial Startup for formaldehyde.18.0

S/A Minn. R. 7017.2020, subp. 1 Performance Test: due 180 days after Initial Performance Test to test formaldehydeemissions, not to exceed 6 months between test dates. After a total of three tests,if the average of the results are below 0.40 lb/hr, the Permittee shall notify theMPCA in writing that testing for formaldehyde will be discontinued. If the average ofthe results are above 0.40 lb/hr, the Permittee shall submit a test frequency plan tothe MPCA.

If any results are over 0.60 lb/hr the Permittee shall submit an application for amajor amendment. The application shall propose a reduction of the 31,000 hr/yr GP001 operating limit to a level that will limit GP 001 formaldehyde emissions to nogreater than 9.0 tons per year.

19.0

S/A Minn. R. 7017.2020, subp. 1 Initial Performance Test: due 90 days after Initial Startup for arsenic20.0

S/A Minn. R. 7017.2020, subp. 1 Performance Test: due 180 days after Initial Performance Test for arsenicemissions, not to exceed 6 months between test dates. After a total of three tests, ifthe results are negligible, the Permittee shall notify the MPCA in writing that testingfor arsenic will be discontinued.

21.0

S/A Minn. R. 7017.2020, subp. 1 Initial Performance Test: due 90 days after Initial Startup for hydrochloric acid22.0

S/A Minn. R. 7017.2020, subp. 1 Performance Test: due 180 days after Initial Performance Test for HCl emissions,not to exceed 6 months between test dates. After a total of three tests, if theresults are negligible, the Permittee shall notify the MPCA in writing that testing forHCl will be discontinued.

23.0

CD hdr RECORDKEEPING REQUIREMENTS24.0




3 May, 2012 10:14Page 6 of 12

CD Title I Condition: To avoid majorsource classification under 40CFR Section 70.2 and Minn. R.7007.0200; Minn. R. 7007.0800,subp. 4 and 5

Monthly Calculations:By the last day of the month, the Permittee shall calculate and record the following:1) Total hours of operation for the month for all emission units in GP 001.2) The 12 month rolling sum of operating hours for the previous 12 month period bysumming the monthly operating hours for the previous 12 months.

25.0

CD hdr NSPS JJJJ REQUIREMENTS26.0

LIMIT 40 CFR Section 60.4233(e) Nitrogen Oxides: less than or equal to 1.0 grams/horsepower-hour or 82 ppmvd at15% oxygen.

27.0

LIMIT 40 CFR Section 60.4233(e) Carbon Monoxide: less than or equal to 2.0 grams/horsepower-hour or 270 ppmvdat 15% oxygen.

28.0

LIMIT 40 CFR Section 60.4233(e) Volatile Organic Compounds: less than or equal to 0.70 grams/horsepower-hour29.0

CD 40 CFR Section 60.4243(g) Air-to-fuel ratio controllers shall be used with the operation of three-waycatalysts/non-selective catalytic reduction. The AFR controller must be maintainedand operated appropriately in order to ensure proper operation of the engine andcontrol device to minimize emissions at all times.

30.0

CD 40 CFR Section 60.4243(a)(2), 40CFR Section 60.4243(a)(2)(iii)

A non-certified stationary SI internal combustion engine shall demonstratecompliance by:- keeping a maintenance plan and records of conducted maintenance- maintaining and operate the engine in a manner consistent with good air pollutioncontrol practice for minimizing emissions, to the extent practicable- conducting an initial performance test within 1 year of engine startup andconducting subsequent performance testing every 8,760 hours or 3 years,whichever comes first, thereafter.

31.0

S/A 40 CFR Section 60.4243(a)(2), 40CFR Section 60.4243(a)(2)(iii)

Initial Performance Test: due 365 days after Startup of each engine for NOx. Thisrequirement applies separately to each engine.


32.0


Initial Performance Test: due 365 days after Startup of each engine for CO. Thisrequirement applies separately to each engine.


33.0


Initial Performance Test: due 365 days after Initial Startup of each engine forVOCs. This requirement applies separately to each engine.


34.0


Performance Test: due before end of each 36 months following Initial PerformanceTest or 8,760 hours of operation, whichever comes first for NOx. This requirementapplies separately to each engine.


35.0


Performance Test: due before end of each 36 months following Initial PerformanceTest or 8,760 hours of operation, whichever comes first for CO. This requirementapplies separately to each engine.


36.0


Performance Test: due before end of each 36 months following Initial PerformanceTest or 8,760 hours of operation, whichever comes first for VOCs. This requirementapplies separately to each engine.


37.0




3 May, 2012 10:14Page 7 of 12

CD 40 CFR Section 60.4245(a) The Permittee shall keep records of the following:(1) All notifications submitted to comply with Subpart JJJJ and all documentationsupporting any notification;(2) Maintenance conducted on the engine;(3) If the engine is certified, documentation from the manufacturer that the engine iscertified to meet the emission standards and information as required in 40 CFRParts 90 and 1048; and(4) If the engine is non-certified or is certified but operating in a non-certifiedmanner and subject to 40 CFR Section 60.4243(a), documentation that the enginemeets the emission standards.

38.0

CD 40 CFR Section 60.4244 The Permittee shall follow the procedures in 40 CFR Section 60.4244(a) through (f)when conducting performance tests.

39.0

CD 40 CFR Section 60.4245(c) The Permittee must submit an initial notification as required in 40 CFR Section60.7(a)(1). The notification must include the following information:1) Name and address of the Permittee;2) The address of the affected source;3) Engine information including make, model, engine family, serial number, modelyear, maximum engine power, and engine displacement;4) Emission control equipment; and5) Fuel used.

40.0

CD 40 CFR Section 60.4245(d) The Permittee must submit a copy of each performance test as conducted in 40CFR Section 60.4244 within 60 days after the test has been completed.

41.0

CD hdr NESHAP ZZZZ REQUIREMENTS42.0

CD 40 CFR Section 63.6590(c); Minn.R. 7011.8150

EU 001, EU 002, EU 003, EU 004 are new affected sources as defined under 40CFR pt. 63, subp. ZZZZ, and the facility is an area source as defined at 40 CFRSection 63.2. The Permittee shall meet the requirements of 40 CFR pt. 63, subp.ZZZZ by meeting the requirements of 40 CFR pt. 60, subp. JJJJ. No furtherrequirements of 40 CFR pt. 63, subp. ZZZZ apply to EU 001, EU 002, EU 003, EU004.

43.0




3 May, 2012 10:14Page 8 of 12

Subject Item: GP 002 CO Catalysts

Associated Items: CE 001 Catalytic Oxidizer




NC/CA


CD hdr EMISSION AND OPERATIONAL LIMITS1.0


The Permittee shall operate and maintain the engine catalyst any time that anyprocess equipment controlled by the engine catalyst is in operation. The Permitteeshall document periods of non-operation of the control equipment.

2.0

LIMIT Title I Condition: To avoidclassification as major sourceunder 40 CFR Section 70.2 andMinn. R. 7007.0200, Minn. R.7007.0800, subps. 2 and 14

The Permittee shall operate and maintain the control equipment such that itachieves an overall control efficiency for Volatile Organic Compounds: greater thanor equal to 60 percent control efficiency

3.0


The Permittee shall operate and maintain the control equipment such that itachieves an overall control efficiency for Carbon Monoxide: greater than or equal to60 percent control efficiency

4.0


The Permittee shall operate and maintain the control equipment such that itachieves an overall control efficiency for HAPs - Total: greater than or equal to 60percent control efficiency

5.0


The Permittee shall operate and maintain the control equipment such that itachieves an overall control efficiency for Formaldehyde: greater than or equal to 60percent control efficiency

6.0


Temperature: greater than or equal to 550 degrees F and less than or equal to1250 degrees F using 3-hour Rolling Average unless a new limit is set pursuant toMinn. R. 7017.2025, subp. 3 based on the values recorded during the most recentMPCA-approved performance test where compliance was demonstrated. The newlimit shall be implemented upon receipt of the Notice of Compliance letter grantingpreliminary approval. The limit is final upon issuance of a permit amendmentincorporating the change. If the temperature is below the minimum inlettemperature limit, the CO, VOC and HAPs used during that time shall beconsidered uncontrolled until the inlet temperature is above the minimumtemperature limit. This shall be reported as a deviation.

7.0

CD hdr MONITORING AND RECORDKEEPING8.0

S/A Title I Condition: To avoidclassification as major sourceunder 40 CFR Section 70.2 andMinn. R. 7007.0200, Minn. R.7007.0800, subps. 2 and 14

Sample Analysis: due before end of each 24 months following Startup. ThePermittee shall send a representative sample of the catalyst to a laboratory to testthe catalyst's activity. If test results show a activity of less than 60%, the Permitteeshall follow the corrective actions contained in the Operation and MaintenancePlan.

9.0

CD Minn. R. 7007.0800, subps. 4 and5

Daily Monitoring: The Permittee shall physically verify the operation of thetemperature recording device at least once each operating day to verify that it isworking and recording properly. The Permittee shall maintain a written record of thedaily verifications.

10.0

CD Minn. R. 7007.0800, subp. 4 Monitoring Equipment: The Permittee shall install and maintain thermocouples formeasuring the temperatures as required by this permit. The monitoring equipmentmust be installed, in use, and properly maintained whenever the monitored controlequipment is required to be operated.

11.0




3 May, 2012 10:14Page 9 of 12

CD Minn. R. 7007.0800, subps. 4 and5

The Permittee shall maintain and operate a thermocouple monitoring device thatcontinuously indicates and records both the inlet and outlet temperatures of thecatalytic oxidizer. The monitoring device shall have a margin of error less than thegreater of +/- 0.75 percent of the temperature being measured or +/- 2.5 degreesCelsius. The recording device shall also calculate the three-hour rolling averageinlet temperature.

12.0

CD Title I Condition: To avoidclassification as a major sourceunder 40 CFR Section 70.2 andMinn. R. 7007.0200; Minn. R.7007.0800, subps. 4 and 5

The Permittee shall maintain a continuous hard copy readout or computer disk fileof the inlet and outlet temperatures and the calculated three-hour rolling averageinlet temperature.

13.0

CD Minn. R. 7007.0800, subps. 4, 5,and 14

Monthly Monitoring: At least once each month during normal operation, thePermittee shall record the temperature rise across the catalyst (outlet temp. - inlettemp.) while the process is running. If it is determined that the catalyst reactivityhas been impaired, by comparison of the observed temperature rise to the pasttemperature rise records, the Permittee shall follow the corrective actions in theOperation and Maintenance Plan. The Permittee shall maintain written records ofthe monitoring and any corrective actions taken.

14.0


Quarterly Inspections: At least once per calendar quarter, or more frequently ifrequired by the manufacturer specifications, the Permittee shall inspect the controlequipment internal and external system components, including but not limited to therefractory, heat exchanger, and electrical systems. The Permittee shall maintain awritten record of the inspection and any corrective actions taken resulting from theinspection.

15.0


Annual Calibration: The Permittee shall calibrate the temperature monitor at leastannually and shall maintain a written record of the calibration and any actionresulting from the calibration.

16.0


For periods when the catalytic oxidizer is operated above the minimum inlettemperature, the Permittee shall use either one of the following when completingcalculations as required elsewhere in this permit:a. The overall control efficiency limit specified in this permit for this equipment(60%); orb. The overall control efficiency determined during the most recent MPCA approvedperformance test. If the tested efficiency is less than the efficiency limit in thispermit, the Permittee must use the tested value in all calculations until theefficiency is demonstrated to be above the permit limit through a new test

17.0


Corrective Actions: If the temperature is below the minimum specified by this permitor if the catalytic oxidizer or any of its components are found during the inspectionsto need repair, the Permittee shall take corrective action as soon as possible.Corrective actions shall return the temperature to at least the permitted minimumand/or include completion of necessary repairs identified during the inspection, asapplicable. Corrective actions include, but are not limited to, those outlined in the O& M Plan for the catalytic oxidizer. The Permittee shall keep a record of the typeand date of any corrective action taken.

18.0

CD Minn. R. 7007.0800, subp. 14 The Permittee shall operate and maintain the CO Catalyst in accordance with theOperation and Maintenance (O & M) Plan. The Permittee shall keep copies of theO & M Plan available onsite for use by staff and MPCA staff.

19.0




3 May, 2012 10:14Page 10 of 12

Subject Item: EU 005 Boiler

Associated Items: SV 002 Hot Water Boiler

NC/CA


CD Minn. R. 7005.0100, subp. 35a Fuels allowed: propane, by equipment design.1.0

LIMIT Minn. R. 7011.0515, subp. 1 Total Particulate Matter: less than or equal to 0.40 lbs/million Btu heat input . Thepotential to emit from the unit is 0.008 lb/MMBtu due to equipment design andallowable fuels.

2.0

LIMIT Minn. R. 7011.0515, subp. 2 Opacity: less than or equal to 20 percent except for one six-minute period per hourof not more than 60 percent opacity.

3.0

CD 40 CFR Section 60.48c(g); Minn.R. 7011.0570

Recordkeeping: By the last day of each calendar month, the Permittee shall recordthe amount of propane combusted in the boiler during the previous calendar month.These records shall consist of purchase records, receipts, or fuel meter readings.

4.0




3 May, 2012 10:14Page 11 of 12

Subject Item: EU 006 Solid Fuel Drying and Prep

Associated Items: SV 003 Solid fuel drying and prep

NC/CA


LIMIT Minn. R. 7011.0715, subp. 1(A) Total Particulate Matter: less than or equal to 0.30 grains/dry standard cubic foot ofexhaust gas unless required to further reduce emissions to comply with the lessstringent limit of either Minn. R. 7011.0730 or Minn. R. 7011.0735.

1.0

LIMIT Minn. R. 7011.0715, subp. 1(B) Opacity: less than or equal to 20 percent2.0

S/A Minn. R. 7017.2020, subp. 1 Initial Performance Test: due 365 days after Initial Startup of EU 006 to verify theVOC emission factor (this is not a test for compliance determination).

The VOC emission factor for this unit is 2.90 lbs/hr.

3.0

S/A Minn. R. 7017.2020, subp. 1 Initial Performance Test: due 365 days after Initial Startup of EU 006 to verify thePM, PM10 and PM2.5 emission factor (this is not a test for compliancedetermination).

The PM, PM10 and PM2.5 emission factor for this unit is 0.00 lbs/hr.

4.0




3 May, 2012 10:14Page 12 of 12

Subject Item: EU 007 Flare

Associated Items: SV 004 Flare

NC/CA


LIMIT Title I Condition: To avoid majorsource classification under 40CFR Section 70.2 and Minn. R.7007.0200

Operating Hours: less than or equal to 200 hours/year using 12-month Rolling Sum. Calculated by the 15th of the month for the preceding month.

1.0

LIMIT Minn. R. 7011.0610, subp. 1(A)(1)and Minn. R. 7011.0735

Total Particulate Matter: less than or equal to 0.30 grains/dry standard cubic foot ofexhaust gas unless required to further reduce emissions to comply with the lessstringent limit of either Minn. R. 7011.0730 or Minn. R. 7011.0735.

2.0

LIMIT Minn. R. 7011.0610, subp. 1(A)(2) Opacity: less than or equal to 20 percent except for one six-minute period per hourof not more than 60 percent opacity.

3.0

CD Minn. R. 7007.0800, subp. 5 The Permittee shall keep records of hours of operation on a daily basis.4.0

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MINNESOTA POLLUTION CONTROL AGENCYAIR QUALITY520 LAFAYETTE ROADST. PAUL, MN 55155-4194

21 February, 2012 16:08

FACILITY DESCRIPTION: Potential-to-emit (by item)

Show: Active and Pending RecordsAQD Facility ID:Facility Name:

07900050Hometown BioEnergy

Item UnrestrictedPotential

(tons per yr)

LimitedPotential

(tons per yr)

ActualEmissions

(tons per yr)

Pollutant AddedBy

(Action)

RetiredBy

(Action)

HourlyPotential

(lbs per hr)

EU 001

Acetaldehyde PER 001 2.39E-011.54E-01 6.75E-01Acrolein PER 001 1.47E-019.48E-02 4.15E-01Benzene PER 001 1.26E-028.11E-03 3.55E-02Biphenyl PER 001 6.06E-033.91E-03 1.71E-021,3-Butadiene PER 001 7.63E-034.92E-03 2.16E-02Carbon tetrachloride PER 001 1.05E-036.77E-04 2.96E-03Carbon Dioxide Equivalent PER 001 9.52E+031.23E+03 1.08E+04Chlorobenzene PER 001 8.69E-045.61E-04 2.46E-03Chloroethane PER 001 5.34E-053.45E-05 1.51E-04Chloroform PER 001 8.15E-045.26E-04 2.30E-03Carbon Monoxide PER 001 2.12E+011.37E+01 6.00E+011,1-Dichloroethane PER 001 6.75E-044.35E-04 1.91E-031,2-Dichloroethane PER 001 6.75E-044.35E-04 1.91E-031,2-Dichloropropane PER 001 7.69E-044.96E-04 2.17E-031,3-Dichloropropene PER 001 7.55E-044.87E-04 2.13E-03Ethylbenzene PER 001 1.13E-037.32E-04 3.21E-03Formaldehyde PER 001 1.51E+009.74E-01 4.26E+00Hexane PER 001 3.17E-022.05E-02 8.97E-02Methanol PER 001 7.15E-024.61E-02 2.02E-01Naphthalene PER 001 2.13E-031.37E-03 6.01E-03HAPs - Total PER 001 8.26E+005.33E+00 2.33E+01Phenol PER 001 6.86E-044.43E-04 1.94E-03Styrene PER 001 6.75E-044.35E-04 1.91E-031,1,2,2-Tetrachloroethane PER 001 1.14E-037.38E-04 3.23E-03Tetrachloroethylene PER 001 7.09E-054.57E-05 2.00E-04Toluene PER 001 1.17E-027.52E-03 3.30E-021,1,2-Trichloroethane PER 001 9.09E-045.86E-04 2.57E-03Vinyl chloride PER 001 4.26E-042.75E-04 1.20E-03Xylenes (mixed isomers) PER 001 5.26E-033.39E-03 1.49E-022,2,4-trimethylpentane PER 001 7.15E-034.61E-03 2.02E-02Acenaphthene PER 001 3.57E-052.31E-05 1.01E-04Acenaphthylene PER 001 1.58E-041.02E-04 4.47E-04Benzo(a)pyrene PER 001 1.19E-057.65E-06 3.35E-05Benzo(b)fluoranthene PER 001 4.74E-063.06E-06 1.34E-05Benzo(ghi)perylene PER 001 1.18E-057.63E-06 3.34E-05Chrysene PER 001 1.98E-051.28E-05 5.60E-05Ethylene dibromide (dibromoeth PER 001 1.27E-038.17E-04 3.58E-03Fluoranthene PER 001 3.17E-052.05E-05 8.97E-05Fluorene PER 001 1.62E-041.05E-04 4.58E-04Methylene chloride (dichlorome PER 001 5.72E-043.69E-04 1.62E-03Phenanthrene PER 001 2.97E-041.92E-04 8.40E-04Pyrene PER 001 3.89E-052.51E-05 1.10E-04Nitrogen Oxides PER 001 1.21E+013.12E+00 1.36E+01PM < 2.5 micron PER 001 7.24E-011.87E-01 8.19E-01PM < 10 micron PER 001 7.24E-011.87E-01 8.19E-01Polycyclic organic matter PER 001 7.69E-044.96E-04 2.17E-03

Page 1 of 6


21 February, 2012 16:08





(tons per yr)

LimitedPotential

(tons per yr)

ActualEmissions

(tons per yr)

Pollutant AddedBy

(Action)

RetiredBy

(Action)

HourlyPotential

(lbs per hr)

EU 001

Total Particulate Matter PER 001 7.24E-011.87E-01 8.19E-01Sulfur Dioxide PER 001 1.95E+005.04E+00 2.21E+01Volatile Organic Compounds PER 001 2.22E+001.43E+00 6.28E+00

EU 002

Acetaldehyde PER 001 2.39E-011.54E-01 6.75E-01Acrolein PER 001 1.47E-019.48E-02 4.15E-01Benzene PER 001 1.26E-028.11E-03 3.55E-02Biphenyl PER 001 6.06E-033.91E-03 1.71E-021,3-Butadiene PER 001 7.63E-034.92E-03 2.16E-02Carbon tetrachloride PER 001 1.05E-036.77E-04 2.96E-03Carbon Dioxide Equivalent PER 001 9.52E+031.23E+03 1.08E+04Chlorobenzene PER 001 8.69E-045.61E-04 2.46E-03Chloroethane PER 001 5.34E-053.45E-05 1.51E-04Chloroform PER 001 8.15E-045.26E-04 2.30E-03Carbon Monoxide PER 001 2.12E+011.37E+01 6.00E+011,1-Dichloroethane PER 001 6.75E-044.35E-04 1.91E-031,2-Dichloroethane PER 001 6.75E-044.35E-04 1.91E-031,2-Dichloropropane PER 001 7.69E-044.96E-04 2.17E-031,3-Dichloropropene PER 001 7.55E-044.87E-04 2.13E-03Ethylbenzene PER 001 1.13E-037.32E-04 3.21E-03Formaldehyde PER 001 1.51E+009.74E-01 4.26E+00Hexane PER 001 3.17E-022.05E-02 8.97E-02Methanol PER 001 7.15E-024.61E-02 2.02E-01Naphthalene PER 001 2.13E-031.37E-03 6.01E-03HAPs - Total PER 001 8.26E+005.33E+00 2.33E+01Phenol PER 001 6.86E-044.43E-04 1.94E-03Styrene PER 001 6.75E-044.35E-04 1.91E-031,1,2,2-Tetrachloroethane PER 001 1.14E-037.38E-04 3.23E-03Tetrachloroethylene PER 001 7.09E-054.57E-05 2.00E-04Toluene PER 001 1.17E-027.52E-03 3.30E-021,1,2-Trichloroethane PER 001 9.09E-045.86E-04 2.57E-03Vinyl acetate PER 001 4.26E-042.75E-04 1.20E-03Xylenes (mixed isomers) PER 001 5.26E-033.39E-03 1.49E-022,2,4-trimethylpentane PER 001 7.15E-034.61E-03 2.02E-02Acenaphthene PER 001 3.57E-052.31E-05 1.01E-04Acenaphthylene PER 001 1.58E-041.02E-04 4.47E-04Benzo(a)pyrene PER 001 1.19E-057.65E-06 3.35E-05Benzo(b)fluoranthene PER 001 4.74E-063.06E-06 1.34E-05Benzo(ghi)perylene PER 001 1.18E-057.63E-06 3.34E-05Chrysene PER 001 1.98E-051.28E-05 5.60E-05Ethylene dibromide (dibromoeth PER 001 1.27E-038.17E-04 3.58E-03Fluoranthene PER 001 3.17E-052.05E-05 8.97E-05Fluorene PER 001 1.62E-041.05E-04 4.58E-04Methylene chloride (dichlorome PER 001 5.72E-043.69E-04 1.62E-03Phenanthrene PER 001 2.97E-041.92E-04 8.40E-04Pyrene PER 001 3.89E-052.51E-05 1.10E-04

Page 2 of 6


21 February, 2012 16:08





(tons per yr)

LimitedPotential

(tons per yr)

ActualEmissions

(tons per yr)

Pollutant AddedBy

(Action)

RetiredBy

(Action)

HourlyPotential

(lbs per hr)

EU 002

Nitrogen Oxides PER 001 1.21E+013.12E+00 1.36E+01PM < 2.5 micron PER 001 7.24E-011.87E-01 8.19E-01PM < 10 micron PER 001 7.24E-011.87E-01 8.19E-01Polycyclic organic matter PER 001 7.69E-044.96E-04 2.17E-03Total Particulate Matter PER 001 7.24E-011.87E-01 8.19E-01Sulfur Dioxide PER 001 1.95E+005.04E+00 2.21E+01Volatile Organic Compounds PER 001 2.22E+001.43E+00 6.28E+00

EU 003

Acetaldehyde PER 001 2.39E-011.54E-01 6.75E-01Acrolein PER 001 1.47E-019.48E-02 4.15E-01Benzene PER 001 1.26E-028.11E-03 3.55E-02Biphenyl PER 001 6.06E-033.91E-03 1.71E-021,3-Butadiene PER 001 7.63E-034.92E-03 2.16E-02Carbon tetrachloride PER 001 1.05E-036.77E-04 2.96E-03Carbon Dioxide Equivalent PER 001 9.52E+031.23E+03 1.08E+04Chlorobenzene PER 001 8.69E-045.61E-04 2.46E-03Chloroethane PER 001 5.34E-053.45E-05 1.51E-04Chloroform PER 001 8.15E-045.26E-04 2.30E-03Carbon Monoxide PER 001 2.12E+011.37E+01 6.00E+011,1-Dichloroethane PER 001 6.75E-044.35E-04 1.91E-031,2-Dichloroethane PER 001 6.75E-044.35E-04 1.91E-031,2-Dichloropropane PER 001 7.69E-044.96E-04 2.17E-031,3-Dichloropropene PER 001 7.55E-044.87E-04 2.13E-03Ethylbenzene PER 001 1.13E-037.32E-04 3.21E-03Formaldehyde PER 001 1.51E+009.74E-01 4.26E+00Hexane PER 001 3.17E-022.05E-02 8.97E-02Methanol PER 001 7.15E-024.61E-02 2.02E-01Naphthalene PER 001 2.13E-031.37E-03 6.01E-03HAPs - Total PER 001 8.26E+005.33E+00 2.33E+01Phenol PER 001 6.86E-044.43E-04 1.94E-03Styrene PER 001 6.75E-044.35E-04 1.91E-031,1,2,2-Tetrachloroethane PER 001 1.14E-037.38E-04 3.23E-03Tetrachloroethylene PER 001 7.09E-054.57E-05 2.00E-04Toluene PER 001 1.17E-027.52E-03 3.30E-021,1,2-Trichloroethane PER 001 9.09E-045.86E-04 2.57E-03Vinyl acetate PER 001 4.26E-042.75E-04 1.20E-03Xylenes (mixed isomers) PER 001 5.26E-033.39E-03 1.49E-022,2,4-trimethylpentane PER 001 7.15E-034.61E-03 2.02E-02Acenaphthene PER 001 3.57E-052.31E-05 1.01E-04Acenaphthylene PER 001 1.58E-041.02E-04 4.47E-04Benzo(a)pyrene PER 001 1.19E-057.65E-06 3.35E-05Benzo(b)fluoranthene PER 001 4.74E-063.06E-06 1.34E-05Benzo(ghi)perylene PER 001 1.18E-057.63E-06 3.34E-05Chrysene PER 001 1.98E-051.28E-05 5.60E-05Ethylene dibromide (dibromoeth PER 001 1.27E-038.17E-04 3.58E-03Fluoranthene PER 001 3.17E-052.05E-05 8.97E-05

Page 3 of 6


21 February, 2012 16:08





(tons per yr)

LimitedPotential

(tons per yr)

ActualEmissions

(tons per yr)

Pollutant AddedBy

(Action)

RetiredBy

(Action)

HourlyPotential

(lbs per hr)

EU 003

Fluorene PER 001 1.62E-041.05E-04 4.58E-04Methylene chloride (dichlorome PER 001 5.72E-043.69E-04 1.62E-03Phenanthrene PER 001 2.97E-041.92E-04 8.40E-04Pyrene PER 001 3.89E-052.51E-05 1.10E-04Nitrogen Oxides PER 001 1.21E+013.12E+00 1.36E+01PM < 2.5 micron PER 001 7.24E-011.87E-01 8.19E-01PM < 10 micron PER 001 7.24E-011.87E-01 8.19E-01Polycyclic organic matter PER 001 7.69E-044.96E-04 2.17E-03Total Particulate Matter PER 001 7.24E-011.87E-01 8.19E-01Sulfur Dioxide PER 001 1.95E+005.04E+00 2.21E+01Volatile Organic Compounds PER 001 2.22E+001.43E+00 6.28E+00

EU 004

Acetaldehyde PER 001 2.39E-011.54E-01 6.75E-01Acrolein PER 001 1.47E-019.48E-02 4.15E-01Benzene PER 001 1.26E-028.11E-03 3.55E-02Biphenyl PER 001 6.06E-033.91E-03 1.71E-021,3-Butadiene PER 001 7.63E-034.92E-03 2.16E-02Carbon tetrachloride PER 001 1.05E-036.77E-04 2.96E-03Carbon Dioxide Equivalent PER 001 9.52E+031.23E+03 1.08E+04Chlorobenzene PER 001 8.69E-045.61E-04 2.46E-03Chloroethane PER 001 5.34E-053.45E-05 1.51E-04Chloroform PER 001 8.15E-045.26E-04 2.30E-03Carbon Monoxide PER 001 2.12E+011.37E+01 6.00E+011,1-Dichloroethane PER 001 6.75E-044.35E-04 1.91E-031,2-Dichloroethane PER 001 6.75E-044.35E-04 1.91E-031,2-Dichloropropane PER 001 7.69E-044.96E-04 2.17E-031,3-Dichloropropene PER 001 7.55E-044.87E-04 2.13E-03Ethylbenzene PER 001 1.13E-037.32E-04 3.21E-03Formaldehyde PER 001 1.51E+009.74E-01 4.26E+00Hexane PER 001 3.17E-022.05E-02 8.97E-02Methanol PER 001 7.15E-024.61E-02 2.02E-01Naphthalene PER 001 2.13E-031.37E-03 6.01E-03HAPs - Total PER 001 8.26E+005.33E+00 2.33E+01Phenol PER 001 6.86E-044.43E-04 1.94E-03Styrene PER 001 6.75E-044.35E-04 1.91E-031,1,2,2-Tetrachloroethane PER 001 1.14E-037.38E-04 3.23E-03Tetrachloroethylene PER 001 7.09E-054.57E-05 2.00E-04Toluene PER 001 1.17E-027.52E-03 3.30E-021,1,2-Trichloroethane PER 001 9.09E-045.86E-04 2.57E-03Vinyl acetate PER 001 4.26E-042.75E-04 1.20E-03Xylenes (mixed isomers) PER 001 5.26E-033.39E-03 1.49E-022,2,4-trimethylpentane PER 001 7.15E-034.61E-03 2.02E-02Acenaphthene PER 001 3.57E-052.31E-05 1.01E-04Acenaphthylene PER 001 1.58E-041.02E-04 4.47E-04Benzo(a)pyrene PER 001 1.19E-057.65E-06 3.35E-05Benzo(b)fluoranthene PER 001 4.74E-063.06E-06 1.34E-05

Page 4 of 6


21 February, 2012 16:08





(tons per yr)

LimitedPotential

(tons per yr)

ActualEmissions

(tons per yr)

Pollutant AddedBy

(Action)

RetiredBy

(Action)

HourlyPotential

(lbs per hr)

EU 004

Benzo(ghi)perylene PER 001 1.18E-057.63E-06 3.34E-05Chrysene PER 001 1.98E-051.28E-05 5.60E-05Ethylene dibromide (dibromoeth PER 001 1.27E-038.17E-04 3.58E-03Fluoranthene PER 001 3.17E-052.05E-05 8.97E-05Fluorene PER 001 1.62E-041.05E-04 4.58E-04Methylene chloride (dichlorome PER 001 5.72E-043.69E-04 1.62E-03Phenanthrene PER 001 2.97E-041.92E-04 8.40E-04Pyrene PER 001 3.89E-052.51E-05 1.10E-04Nitrogen Oxides PER 001 1.21E+013.12E+00 1.36E+01PM < 2.5 micron PER 001 7.24E-011.87E-01 8.19E-01PM < 10 micron PER 001 7.24E-011.87E-01 8.19E-01Polycyclic organic matter PER 001 7.69E-044.96E-04 2.17E-03Total Particulate Matter PER 001 7.24E-011.87E-01 8.19E-01Sulfur Dioxide PER 001 1.95E+005.04E+00 2.21E+01Volatile Organic Compounds PER 001 2.22E+001.43E+00 6.28E+00

EU 005

Carbon Dioxide Equivalent PER 001 5.41E+036.17E+02 5.41E+03Carbon Monoxide PER 001 3.59E+008.20E-01 3.59E+00Nitrogen Oxides PER 001 6.22E+001.42E+00 6.22E+00PM < 2.5 micron PER 001 3.40E-018.00E-02 3.40E-01PM < 10 micron PER 001 3.40E-018.00E-02 3.40E-01Total Particulate Matter PER 001 3.40E-018.00E-02 3.40E-01Sulfur Dioxide PER 001 7.20E-011.60E-01 7.20E-01Volatile Organic Compounds PER 001 4.80E-011.10E-01 4.80E-01

EU 006

Volatile Organic Compounds PER 001 1.12E+012.90E+00 1.27E+01

EU 007

Benzene PER 001 1.52E-051.52E-04 6.65E-04Arsenic compounds PER 001 1.45E-061.45E-05 6.33E+05Beryllium Compounds PER 001 8.68E-088.68E-07 3.80E-06Carbon Dioxide Equivalent PER 001 4.11E+024.11E+03 3.60E+04Cadmium compounds PER 001 7.95E-067.95E-05 3.48E-04Carbon Monoxide PER 001 6.39E-014.10E-04 1.80E-03Cobalt compounds PER 001 6.07E-076.07E-06 2.66E-05Chromium compounds PER 001 1.01E-051.01E-04 4.43E-041,4-Dichlorobenzene PER 001 8.68E-068.68E-05 3.80E-04Formaldehyde PER 001 5.42E-045.42E-03 2.38E-02Hexane PER 001 1.30E-021.30E-01 5.70E-01Naphthalene PER 001 4.41E-064.41E-05 1.93E-04HAPs - Total PER 001 1.37E-021.37E-01 5.98E-01Mercury Compounds PER 001 1.88E-061.88E-05 8.24E-05Toluene PER 001 2.46E-052.46E-04 1.08E-03Manganese compounds PER 001 2.75E-062.75E-05 1.20E-04Benz(a)anthracene PER 001 1.30E-081.30E-07 5.70E-07Benzo(a)pyrene PER 001 8.70E-098.68E-08 3.80E-07Benzo(b)fluoranthene PER 001 1.30E-081.30E-07 5.70E-07

Page 5 of 6


21 February, 2012 16:08





(tons per yr)

LimitedPotential

(tons per yr)

ActualEmissions

(tons per yr)

Pollutant AddedBy

(Action)

RetiredBy

(Action)

HourlyPotential

(lbs per hr)

EU 007

Benzo(k)fluoranthene PER 001 1.30E-081.30E-07 5.70E-07Chrysene PER 001 1.30E-081.30E-07 5.70E-07Dibenz(a,h)anthracene PER 001 8.70E-098.68E-08 3.80E-07Indeno(1,2,3-cd)pyrene PER 001 1.30E-081.30E-07 5.70E-07Nickel compounds PER 001 1.52E-051.52E-04 6.65E-04Nitrogen Oxides PER 001 7.53E-017.11E-04 3.11E-03PM < 2.5 micron PER 001 5.72E-023.83E-05 1.68E-04PM < 10 micron PER 001 5.72E-023.83E-05 1.68E-04Polycyclic organic matter PER 001 6.38E-076.38E-06 2.79E-05Total Particulate Matter PER 001 5.72E-023.83E-05 1.68E-04Selenium compounds PER 001 1.74E-071.74E-06 7.60E-06Sulfur Dioxide PER 001 4.86E-038.20E-05 3.59E-04Volatile Organic Compounds PER 001 4.15E-025.46E-05 2.39E-04

FS 001

PM < 2.5 micron PER 001 6.00E-016.00E-01PM < 10 micron PER 001 2.80E+002.80E+00Total Particulate Matter PER 001 1.38E+011.38E+01

FS 002

Carbon Dioxide Equivalent PER 001 5.00E+025.00E+02Methane PER 001 2.24E+012.24E+01

Page 6 of 6

Attachment 6 – Points Calculator

Points Calculator

1) AQ Facility ID No.: 07900050 Total Points 1602) Facility Name: Hometown BioEnergy3) Small business? y/n? n ��4) DQ Numbers (including all rolled) : 3698 ��5) Date of each Application Received: 10/12/20116) Final Permit No. '07900050-0017) Permit Staff Adriane Lenshek8) "Work completed" in which .xls file (i.e. unit 2bNA

TotalApplication Type DQ No. Qty. Points Points DetailsAdministrative Amendment 1 0Minor Amendment 4 0Applicability Request 10 0Moderate Amendment 15 0Major Amendment 25 0Individual State Permit (not reissuance) 3698 1 50 50Individual Part 70 Permit (not reissuance) 75 0

Additional PointsModeling Review 15 0

BACT Review 15 0LAER Review 15 0CAIR/Part 75 CEM analysis 10 0NSPS Review 3698 2 10 20 NSPS JJJJ, NSPS DcNESHAP Review 3698 1 10 10 NESHAP ZZZZCase-by-case MACT Review 20 0Netting 10 0Limits to remain below threshold 3698 1 10 10 Part 70Plantwide Applicability Limit (PAL) 20 0AERA review 15 0Variance request under 7000.7000 35 0Confidentiality request under 7000.1300 2 0EAW reviewPart 4410.4300, subparts 18, item A; and 29 15 0Part 4410.4300, subparts 8, items A & B; 10, items A to C; 16, items A & D; 17, items A to C & E to G; and 18, items B & C

35 0

Part 4410.4300, subparts 4; 5 items A & B; 13; 15; 16, items B & C; and 17 item D

3698 1 70 70

Add'l Points 110

NOTES:Revised 3/21/2012 to include EAW review required by Minn. R. 4410.4300 Subp. 5A

(DQ 3698)

Attachment 7 – Public Comments

1

Lenshek, Adriane (MPCA)

From: Frank Ebert [[email protected]]Sent: Friday, March 09, 2012 11:01 PMTo: Lenshek, Adriane (MPCA)Cc: Bruce McKay Subject: Question about Home Town Bioenergy Air Permit VTM calculations

Hello Adriane,

I am analyzing the Home town Bioenergy support document emissions section Table A.1.

A quick question if I may on the VTM calculations related to calculating PM’s.

The document states 0.5 miles for both their feed stock and effluent in calculating the total VTM.

My question is, is the miles distance traveled based on only the site location, or does it include the total traffic distances? That is all I need to know.

When I use total traffic distances the PM’s are off of the roof. Therefore I need to know if I am missing something regarding VTMand miles traveled in the proper regulatory requriments.

No rush on this. Take your time. I would highly appreciate a response if this is part of the formal permit summary communicationprocess. Thank you.

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MinnesotaPollutionControlAgency

Hometown BioEnergy ProposalAir Quality Permit Comments

\

Your CommentsPlease take this opportunity to provide comments on the air quality permit for the proposed HometownBioEnergy facility in Le Sueur. The MPCA will consider public comments when establishing final permitconditions.

o In order to assure that we receive and understand your comments, please submit them in writing.o When you comment on the permit, you will be most clear and will best help us understand your

concerns if you can give us the permit section and page number that contain the issue you areaddressing in your comment.

o Plan your comment so you can make the points you want to make as briefly and effectively as possible.Long and rambling comments run the risk of your key points getting lost and diluting the effectivenessof your comments.

o The MPCA responds by letter to all written comments.

Written comments should be addressed to: Adrianc LenshekMinnesota Pollution Control Agency520 Lafayette Road NorthSt. Paul, Minnesota 55 I55651-757-2526 (voice); 651-297-8683 (fax)[email protected]

Written comments on the draft permit must be received at the MPCA Office by 4:30 p.m. on March 27,2012.

Name (Required, please print)Street Address (Required, please print)City, State, Zip (Required, please print)PhoneEmail

@.'\ (Make comments on the back of this sheet):.J ? W t-/A"- T '1'P '" (>F 1"",-14 ,J "L-c~'( !-JUt... ex V;:'t<D ~

- • _l-IyP~"" S\J~I"",{ lZ€t-<'A•..•••L- I\N\)-'5\ LoX ,p>lG ~"""A L-

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Minnesota Pollution Control Agency, 520 Lafayette Road North, Sl. Paul, Minnesota 55155-4194(651) 296-6300, toll-free (800) 657-3864, TTY (651) 282.5332 or (800) 657-3864

This material can be made available in allernative formats for people with disabilities. c:>V~@ Printed on recycled paper containing at least 30 percent fibers from paper recycled by consumers.

Section Permit page # __

<1.'2.-) tAl \ LL.. -11;} \31<': L-IH 11"'5 "Sf:: 'F'U'\u<D nJ .L~

"'ft. \" '> 't1~AN,~IN ~ -l-\'t'D~,.j 5VWtDtf, 5 \\..0 I/'tLN ~ 7

Minnesota Pollution Control Agency, 520 Lafayette Road North, Sl. Paul, Minnesota 55155-4194(651) 296-6300, toll-free (800) 657-3864, TTY (651) 282-5332 or (800) 657-3864

This material can be made available in alternative formats for people with disabilities.

@ Printed on recycled paper containing at least 30 percent fibers from paper recycled by consumers.

MinnesotaPollutionControlAgency

BV: _

Hometown BioEnergy ProposalAir Quality Permit Comments

Your CommentsPlease take this opportunity to provide comments on the air quality permit for the proposed HometownBioEnergy facility in Le Sueur. The MPCA will consider public comments when establishing final pennitconditions.

o In order to assure that we receive and understand your comments, please submit them in writing.o When you comment on the permit, you will be most clear and will best help us understand your

concerns if you can give us the permit section and page number that contain the issue you areaddressing in your comment.

o Plan your comment so you can make the points you want to make as briefly and effectively as possible.Long and rambling comments run the risk of your key points getting lost and diluting the effectivenessof your comments.

o The MPCA responds by letter to all written comments.

Written comments should be addressed to: Adriane LenshekMinnesota Pollution Control Agency520 Lafayette Road NorthSt. Paul, Milmesota 55155651-757-2526 (voice); 651-297-8683 (fax)adriane.l [email protected]

Written comments on the draft permit must be received at the MI'CA Office by 4:30 p.m. on March 27,2012. -

Name (Required, please print)Street Address (Required, please print)City, State, Zip (Required, please print)PhoneEmail

(Make comments on the back of this sheet) atlMn07tAr {{f(!JTt,.{ cl)J 4/.,'ftu!/'fcf fDWttkrr;flatil&/ t(i1(jJ\£rJS/

Minnesota Pollution Control Agency, 520 Lafayette Road North, 51. Paul, Minnesota 55155-4194(651) 296-6300, toll-free (800) 657-3864, TTY (651) 282.5332 or (800) 657.3864


@ Printed on recyded paper containing at least 30 percent fibers from paper recyded by consumers.

Section Permit page # __

Minnesota Pollution Control Agency, 520 Lafayette Road North, 51. Paul, Minnesota 55155-4194(651) 296-6300, toll-free (800) 657-3864, TTY (651) 282-5332 or (800) 657-3864


Printed on recycled paper containing at least 30 percent fibers from paper recycled by consumers.

March 22, 2012

Thank you so much for taking the time and so kindly conducting this meeting in ourcommunity. You did a great job in professionally managing a session where there is a lot ofemotion and strong feelings. I think it all boils down to the fact that people are fearful that ourquality of life will be negatively impacted by this project. Your objective and fact basedanalysis can aid us in better understanding the impact of the project on our land, water andnoise. It is disappointing to know that you do not regulate odor as I think your objectiveassessment would be valuable, however, you did a good job of providing an overview ofintended material handling. The following are my questions remaining or resulting fromattendance of the Minnesota Pollution Control Agency meeting conducted in Le Sueur, March20,2012.

1. Community resident Frank Ebert has invested a significant amount of his time andenergy researching the impact of this project on our community. He has significantlymore scientific knowledge, training and experience then most community members. Itappears that he has pointed out concerns based on his research, yet we do not know ifhis calculations have received review and consideration. This increases the fear anddistrust in the project by those without the scientific knowledge and training. Who willrespond to his research?

2. What would the Department of Agriculture requirements for storing and handling ofthe liquid by product be if it was called fertilizer versus the requirements for handlingand storage when termed soil amendment? Does one agencies handling of "a rose byany other name" result in more or less protection for the environment and thecommunity? Are there requirements to define the by-product based on its intendeduse or its chemical makeup? We don't want a play of words to result in less protectionfor the precious gift of our states water.

3. Why is the well located on Karen Voss's property (32066 360th Street, Le Sueur, MN56058) not being commented on in terms of the impact of this project? There wouldbe more confidence in the project if there was assurance specifically and scientificallythat her well would not be negatively impacted.

~ Alul&2~.KlL- --__7~tSO&%4th

LeSueur, MN 56058

[email protected]

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From: Dave Graff [[email protected]]Sent: Tuesday, March 27, 2012 3:08 PMTo: Lenshek, Adriane (MPCA)Cc: Lynott, William (MPCA)Subject: Proposed Le Sueur Hometown BioEnergy Proposal

I am writing in regard to air quality concerns due to stored sweet corn silage. I am from Springfield, MN, and won’t have to deal with the air quality concerns that the residents of Le Sueur will. I have worked with sweet corn silage for many years – stacking it in a commercial silage company bunker during the harvest season as well as removing it during the off season. If Ilived any where near a proposed project such as the one at Le Sueur, I would oppose it with the most vigorous efforts. In spiteof the planned filtering and reverse ventilation THERE IS NO GUARANTEE that there won’t be any unpleasant odors or smell from the facility, especially the outside silage storage area or the lagoons. I have experienced the extremely unpleasant and Ibelieve harmful odors and smells when temperatures are 90 degree’s plus with strong winds – particularly in August and September but also at any other unpredicted time as well. The smell permeates clothing, buildings and vehicles and the stench stays with them.

I was at the March 20th meeting and when the question was asked “what if the facility smells”, the answer was that they (BioEnergy) would have to build an enclosed storage facility for the silage to contain the smell. My response, knowing what I do - for the benefit of the residents in the area as well as being a good will gesture to them – is then include the cost for andbuild the storage structure now as a preventative measure. Covered bunkers will not contain the smell and there are no other storage facilities of this type available to compare it with. The same is true of the potential smell from the ponds or lagoons in having no other ones to compare it to.

Would the mayor and other supporters of the project build it next to their homes, or the golf course, or hospital or church? I’llbet they wouldn’t – for the same or similar reasons Mr. Lynott is opposed to a mining company operating near his lake home.

Its evident that the MPCA staff has put significant time into the EAW, to the point that those of us that attended the meeting from Springfield felt Mr. Lynott’s presentation bordered on promoting the project rather than being unbiased. The good sized crowd that attended the meeting plus the presence of on duty law enforcement are indications of more than minor opposition to the project. It isn’t fair to area residents to have their children’s birthday party, graduation party, wedding, funeral or other event ruined because of this project. Again, THERE IS NO GUARANTEE that the outlined preventative measures will work. The lights will not go out in Le Sueur without this project. Due to the many concerns, I would request an EIS before the project isapproved. Thank you.

David Graff 17349 420th Ave Springfield, MN 56087 [email protected]

Attachment 8 – Response to Comments

Minnesota Pollution Control Agency Hometown BioEnergy LLC

and Minnesota Municipal Power Agency

Air Emission Permit NO. 07900050-001

RESPONSES TOCOMMENTS ON THE DRAFT PERMIT

1. Comment by Frank Ebert. Email received March 9, 2012

Comment 1-1: Concerning the vehicle miles traveled, is the miles distance traveled based on only the site location, or does it include the total traffic distances?

Response: Emissions from truck traffic are calculated by the distance the vehicle is driven onsite. Air quality permits do not regulate the truck emissions when the trucks are offsite. Each truck is estimated to drive 0.5 miles on the property during each trip to the facility.

2. Comment by Frank Ebert. Email received March 19, 2012 letter received March 21, 2012. The electronic version contained calculations by Frank Ebert that are referenced in his comments.

Comment 2-1: Stack Height: Several complex model systems are used to determine stack height. My challenge is the validity of existing stack height noted in the EAW indicating two stack heights listed at 54 feet and 50 feet. Three anaerobic digesters are listed at 75 feet in height exceeding the stack heights. Because of this design I question the effectiveness and efficiency of the air dispersion model. Furthermore, I refer to this formula, where: Hg= 2.5 X H. Hg = good engineering practice stack height, measured from the ground-level elevation at the base of the stack; and H = height of nearby structure(s) measured from the ground-level elevation at the base of the stack; (b) For all other stacks, the stack height calculated by the following formula: Hg= H + 1.5 L. Where: Hg = good engineering practice stack height, measured from the ground-level elevation at the base of the stack; H = height of nearby structure(s) measured from the ground-level elevation at the base of the stack; and L = height or projected width, whichever is less, of nearby structure(s); If the same Stack Height Regulation parameters are in force in Minnesota, it seems probable that the 75 ft digesters would be close enough to the stacks to result in 2.5 x 75 = 187.5 ft stack height, but that the "greater of" clause from this information might require a minimum stack height up to 213.25 ft.

Response: The commenter is likely referring to part of Section 123 of the Clean Air Act that describes good engineering practice (GEP) of stack height to “not exceed two and one-half times the height of the source unless a demonstration is performed justifying a higher stack.” Note that GEP applies to maximum height, not minimum height. One purpose of this GEP is to discourage a source from simply building a taller stack to achieve satisfactory air dispersion modeling. This GEP would encourage a source to install controls or to take measures to reduce the amount of pollutant emitted. This information can be found in EPA document titled Guideline for Determination of Good Engineering Practice Stack Height (Technical Support Document For the Stack Height Regulations) (Revised) dated June 1985. Because the Facility has demonstrated modeled compliance with the National Ambient Air

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Responses to Comments on Draft Air Emission Permit No. 07900050-001 2 of 18

Quality Standards (NAAQS) by completing SCREEN3 modeling, the MPCA has assurance that the stack height, as proposed, is sufficient.

Comment 2-2: Stack Height and Plumes: Essential information is lacking on plumes from this facility. Analysis stating the approximate distance of 200 ft. of the plumes from the facility should be better clarified. I request a formal A.E.R.A. (Air Emissions Risk Analysis) be completed by a certified Agency and this included in an E.I.S.

Response: The commenter is likely referring to the following statement from the EAW, “Under certain atmospheric conditions, there will be a visible water vapor plume from the exhaust stacks. These plumes will be relatively small and will dissipate within approximately 200 feet from the facility.” The visible vapor plumes from the Hometown BioEnergy facility would be the result of condensation of water that is generated in the combustion of the biogas or driven off during solids drying. The Hometown BioEnergy plumes are expected to behave similar to the exhaust from a car or truck during the winter where a small plume is visible but dissipates within a short distance.

Comment 2-3: Appendix III. Screen 3 modeling Input and Outputs: Explain how CO target levels are more at 1 hour (35,000 ug/cu. meter) than at 8 hours? (10,000 ug/cu. meter). Is this simply reflecting dispersion over periods of time?

Response: The CO target levels are the NAAQS for one-hour exposure and for eight-hour exposure. The target for the one-hour exposure is higher because the exposure time is shorter. A higher level of pollution is acceptable for a shorter amount of time, and over a longer period of time, the acceptable level is lower.

Comment 2-4: Appendix III. Screen 3 modeling Input and Outputs: The screen 3 Model run Scenario 1 indicates rural. The proposed location of this site is Urban. The scenario should be corrected based on this conflict.

Response: The SCREEN3 model requires an input of urban or rural; the following text is excerpted from EPA’s SCREEN3 Model User’s Guide. “Determination of the applicability of urban or rural dispersion is based upon land use or population density. In general, if 50 percent or more of an area 3 km around the source satisfies the urban criteria (Auer, 1978), the site is deemed in an urban setting. Of the two methods, the land use procedure is considered more definitive.” The land use procedure is summarized as follows: if 50 percent or more of the land use within 3 kilometers of the source is heavy industrial, light-moderate industrial, commercial, or compact residential, then the area is classified urban.

Comment 2-5: Appendix III. Screen 3 modeling Input and Outputs: Note in the Screen 3 models the elevation of the surrounding terrain is higher than the elevation of the base of the stacks by about 10 meters.

Response: The SCREEN3 model does not take elevation changes into account, but because SCREEN3 is a conservative model, the MPCA has assurance that the emissions from the facility would be in compliance with the NAAQS.

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Comment 2-6: Appendix III. Screen 3 modeling Input and Outputs: Based on this entire section on Screen 3 modeling outputs this entire section must be better defined and explained. Because of lack of clarity and of these calculations it be requested a formal MPCA (A.E.R.A.) Air Emission Risk Analysis be conducted.

Response: The SCREEN3 model was completed properly, and the MPCA has reasonably assurance that the facility would comply with NAAQS.

Comment 2-7: Facility Description. Fugitive sources: Carbon monoxide emissions from traffic were requested in the EAW and if they are in the air permit I do not see them. Is this a requirement?

Response: CO emissions from traffic are not required in the air permit. The emissions created by mobile sources, such as truck engines, are not regulated by the air permit. The air permit addresses stationary sources.

Comment 2-8: Facility Description. Fugitive sources: Table A.1 Air Emissions Inventory. The number of truck trips conflict with our analysis upon evaluating the EAW. This increases the Fugitive emissions in the VMT section and should be further evaluated and confirmed since these inconsistencies affect emission calculations.

Response: The spreadsheet submitted by the commenter calculates a total of 13,800 trucks, which is consistent with the information provided by the facility. While the bulk of the particulate emissions at the facility would be fugitive emissions caused by truck traffic, the calculated emissions are less than a quarter of the allowable particulate emissions.

Comment 2-9: Biofilter: The overall performance of this system presents concerns. Is this an acceptable MPCA process? Has this type of system been used in other various applications successfully? What is the longevity of performance of these units? Will they over time accumulate materials that may concentrate and add various contaminations to the ground water or soil? Over time, will the biofilter material have to be replaced due to natural decomposition?

Response: The biofilter is not in the air permit because none of the emission calculations depend on the performance of the biofilter. However, the MPCA is familiar with the technology of biofilters. Biofilters have been used in similar and other applications successfully. The maintenance of the biofilter would be the facility’s responsibility. The filter media may need replacement or addition, just as any pollutioncontrol equipment would need maintenance.

Comment 2-10: Biofilter: Regarding the biofilter (EU008): The document states 100% absorption with an expected destruction efficiency of 70 to 90%. This does not guarantee fully efficient odor control.

Response: The commenter is possibly referencing this statement from the EAW, “The biofilter will have a capture efficiency of 100 % and an expected destruction efficiency of 70-90%.” The commenter might also be citing a previous version of the permit or the EAW because the biofilter was incorrectly included as an emission unit by the project proposer describing it as EU 008; however, the biofilter is not an

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emission unit. The facility does not guarantee full odor control; however, the use of the biofilter will decrease the odorous emissions.

Comment 2-11: Biofilter: The proposed air permit actually indicates a 10% allowance of odors due to the design of this device. This is not acceptable for proper and ensured odor control. At 70% destruction, odor release will be 30%, exceeding the 10% allowance. They need something better.

Response: The air permit does not have a 10% allowance for odor; odor is not a regulated pollutant.

Comment 2-12: Bioscrubber: Little if any information is provided on the Bioscrubber. All prior information provided contained only a publication but nothing of the type of bioscubber that will be used, how it will operated, or if this is an approved efficient system. This needs more in depth study.

Response: Bioscrubber and biofilter are synonymous, however in this application the bioscrubber does not vent to the atmosphere as the biofilter does. Instead, the bioscrubber prepares the biogas for combustion in the engines. The operating details of the bioscrubber are not included in the permit because that information is not necessary to assure compliance with air quality standards.

Comment 2-13: Bioscrubber: The bioscrubber is a biological bacterial process. Bacteria are highly depended on temperature, pH, and nutrient balances. How can this process be ensured to be effective and reliable? What provisions are incorporated to maintain proper temperatures that might affect the performance of this device? Please confirm.

Response: The air quality permit contains conditions to ensure compliance with air quality standards; the operating details of the bioscrubber are not necessary to ensure compliance with air quality standards.

Comment 2-14: Bioscrubber: I see nothing in the Air permit that has a compliance plan CD-01 for this process. It is highly recommended these be addressed and added to the air permit.

Response: See Response to Comment 2-13.

Comment 2-15: Bioscrubber: The Operations & Maintenance for this unit is substandard. Although it requires odor inspections it does not include proper cleaning, inspection of the light source required to allow proper performance, temperature monitoring to ensure proper performance, possible pH monitoring, ensuring the unit does not get clogged. This must be included and addressed in the Air Permit.


Comment 2-16: Bioscrubber: How is it designed from a biological perspective to function specifically to absorb and react with hydrogen sulfide gas?


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Comment 2-17: Bioscrubber: It is noted some bacterial growth will collect in the bioreactor and will be transferred to the liquid byproduct storage ponds. This transfer adds to potential ongoing biological reactions in the effluent holding ponds, generating the potential for more odor and hydrogen sulfide gas.

Response: There is potential for the ponds to produce gas; the ponds will be covered control odor.

Comment 2-18: Bioscrubber: Will this material contain reduced forms of hydrogen sulfide such as sulfur, or will it be in oxidized forms such as sulfates? Either way, upon this material entering the effluent holding ponds, it has a high potential to add various chemical components that might continue to generate more hydrogen sulfide gas. This requires additional evaluation to ensure effective performance for controlling odors.

Response: The gas bioscrubber will remove moisture and hydrogen sulfide from the biogas. The bioscrubber will use autotrophic, sulfur-oxidizing bacteria to convert sulfide to either sulfate or elemental sulfur. The discharge stream from the bioscrubber would flow to the liquid industrial byproduct ponds. The small amount of sulfur, relative to the expected volume of the liquid industrial byproduct, is desirable for land application as some farmers apply supplemental sulfur as part of their fertilizer application program. Also see Response to Comment 2-13.

Comment 2-19: Carbon Monoxide Catalyst: Does this device require any chemical materials or generate any hazardous waste specifically under RCRA?

Response: The air permit does not regulate RCRA materials.

Comment 2-20: Carbon Monoxide Catalyst: My understanding is these types of Oxidative catalytic converter are designed to be used in only stationary combustion turbines. Will this device perform properly with reciprocating internal combustion engines? I note specific requirements to address this in the air permit. However, the concern is the performance of this unit with reciprocating internal combustion engines.

Response: Carbon monoxide catalysts are used in many applications, including reciprocating internal combustion engines. As stated in the comment, the air quality permit has requirements to assure compliance with air quality standards.

Comment 2-21: Carbon Monoxide Catalyst: Carbon monoxide catalyst and Siloxanes: Silage and chicken manure have significant levels of siloxanes. Siloxanes are known to foul oxidative catalytic converters. Has this concern and potential impact been evaluated for this application?

Response: Silage and chicken manure are not expected to have significant levels of siloxanes; therefore, the biogas created at this facility is not expected to contain siloxanes. Siloxanes are an additive in cosmetics and used in other applications. Siloxanes are common in biogas created at wastewater treatment plants because the wastewater contains soap, shampoo, and other cosmetics. When combusted, siloxanes turn into silicon dioxide which has the potential to foul pollution control

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equipment. The air quality permit has requirements to monitor the catalyst and periodically test its activity.

Comment 2-22: Exhaust Drying System (SV003): Information obtained from the EAW noted that genset exhaust uses two outlets. EU006 is used for fuel drying and preparation. It appears to have no control emission unit (CE) and is expelled through SV003. It is not fully clear how this system is designed and operates. Is the digestate drying process a closed system to specifically vent the exhaust released into the air upon emission out of this stack and does not flow through the digestate material?

Response: The exhaust from the gensets can be discharged from two stacks: directly to the atmosphere or first passing through the digestate solids then to the atmosphere.

Comment 2-23: Exhaust Drying System (SV003): If the heated exhaust gas makes contact with the digestate vapors, what effects would that have on collecting extensive moisture and emission sources from the digestate to affect the stack performance? If it is a closed system this question does not apply.

Response: This is not a closed system; see the response to 2-22. Dispersion from the stack has been modeled satisfactorily.

Comment 2-24: Exhaust Drying System (SV003): More information should be provided to determine if EU006 should be treated with a Control Emission Device before exhausting out through SV003 depending on my questions above.

Response: Requirements to conduct a performance tests on EU 006 have been added to the permit to confirm the emission factor used in calculations. The method used to calculate emissions from this source appear to be reasonable. However, because this is not a common emission source, it is pertinent to test.

Comment 2-25: Digestate VOC and PM calculations affecting Air Permit calculations: References, testing procedures, and information on VOC’s generated from the digestate drying process are not accurately available and must be included. The proposer is only providing an estimate with no references.


Comment 2-26: Digestate VOC and PM calculations affecting Air Permit calculations: How is the proposer identifying VOC’s? VOC’s in EPA Article 61. Land Applications of Biosolid, Industrial Waste Product, and Pollutant Bearing Water. 327 I.A.C. 6.1-2-60: volatile solids means the amount of percent total solids lost when the material is combusted at five hundred degrees Celsius in the presence of oxygen. To determine VOC’s from this process/unit I am requesting a formal VOC test be conducted to ensure more reliable VOC values, specifically for the digestate. The information should then be properly applied in this VOC data. The proposer at several public meetings announced they were conducting various pilot studies. Either that material or digestate from similar operations should be obtained and VOC testing conducted on similar product materials.


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Comment 2-27: Digestate VOC and PM calculations affecting Air Permit calculations: This digestate has been suggested as a fuel to supply energy for boilers. The digestate may contain considerable levels of silica containing products and other minerals that may be detrimental to the boiler process by generating excess slag build up during combustion that might result in major issues. Has this potential issue been evaluated and considered?

Response: The user of the dried digestate solid is responsible for complying with applicable regulations. Also see Response to Comment 2-21.

Comment 2-28: Digestate VOC and PM calculations affecting Air Permit calculations: The biodigesters operate continuously 24 hours/day. However, it is stated the general production hours consist of 16 hours. What procedures and storage of the material consistently coming out of the digesters are provided to address the overnight accumulation of this material including generation of odors?

Response: The digestion process will continuously create biogas which will be directed through the bioscrubber to the storage tanks. The liquid industrial byproduct digester residuals will be removed from the digestion process in batches, not continuously.

Comment 2-29: Digestate VOC and PM calculations affecting Air Permit calculations: Monitoring. Particulate Matter: EU006, Solid fuel drying states it is “unlikely the stated PM will exceed 0.30 grains/dscf.” This claim of unlikeliness needs to be validated with calculations or conducted studies to backup this statement.


Comment 2-30: Fuel values: Based on the biogas BTU ratings, the fuel must have heating value to comparable traditional fuels. Does this biogas stated at 500 BTU/scf. meet these requirements?

Response: Biogas typically has a heating value greater than 500 Btu/scf.

Comment 2-31: Traffic Regarding emissions: It is our consensus that the impact of traffic remains another primary issue and should be further studied. It is recommended a traffic impact study be conducted.

Response: The air permit does not regulate emissions from mobile sources, such as truck traffic. However, fugitive emissions from paved roads are addressed in the air permit at FS 001.

Comment 2-32: Traffic Regarding emissions: Traffic flow will not only affect Highway 112 and County Rd. 115 near Le Sueur, it is expected much traffic will have to pass through the town of Le Sueur to gain access to highway 112. This would cause annoyances, safety issues, and potential odor issues.


Comment 2-33: Traffic Regarding emissions: Traffic for the hauling of digestate has not been included in this air permit study. Why is the digestate not included when Effluent and Raw feedstock materials are?

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Is the provider using their own trucks and drivers for the raw feedstock and effluent transport? Why is digestate not included in traffic analysis and related emissions?

Response: The vehicle miles traveled onsite for removing liquid industrial byproduct are included in the emission calculations; the effluent truck traffic is synonymous with liquid industrial byproduct or digestate removal. See also Response 2-32.

Comment 2-34: Traffic Regarding emissions: In addition this will add to the concern of noise generation and safety concerns.


Comment 2-35: Traffic Regarding emissions: It was requested in the EAW that carbon monoxide emissions be included for traffic. I do not see this anywhere in the Air Permit data calculations.


Comment 2-36: Traffic Regarding emissions: Are vehicle (Truck and tractor) emissions required other than PM? Example CO, NOx, VOC’s. If so why are they not included in the emission report? If they are these should be included before the permit is approved.

Response: See Response to Comment 2-7 and 2-31.

Comment 2-37: Traffic Emissions calculations at the end of Table A.1. The VMT values listed in Table A.1. do not appear accurate and conflicts with my calculations. The number of trips for feedstock to calculate the VMT are higher based on an in-depth study of data provided in the EAW. Our data indicates 17,520 or more trips per year, or 1460 or more trips per month, or an average of 48 or more trips per day. This should be re-evaluated and corrected.

Response: The calculations submitted by the commenter uses the same number of trucks in the calculations the facility submitted. However, the facility is still well below permit limits using the truck numbers used in this comment.

Comment 2-38: Traffic Emissions calculations at the end of Table A.1. Digestate trips are not included in the VTM and I expect should be.


Comment 2-39: Traffic Emissions calculations at the end of Table A.1. The emission values in the note section, the emission units in Lb/Unit, and tons/yr. are difficult to decipher because of legibility issues and difficulty identifying decimal points. This section has to be improved in structure, style, and clear information available to enable accurate calculations.

Response: The commenter has been provided with the full emissions calculation excel file with calculation to address legibility issue and the spreadsheet as been reformatted for easier reading in the final permit.

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Comment 2-40: Traffic Emissions calculations at the end of Table A.1. What are those emission units in Table A.1. on the notes section for traffic emissions? The units are not defined. In attempting to correlate those values with the traffic emission data in the Emission Table. A.1 they are difficult to compare and decipher. Have the proposer improve this data system so it can be properly evaluated.


Comment 2-41: From the Air Permit Specifically. Appendix II. Best Management Practices Plan. Odor Prevention: Odor conditions need to be defined for this project through the various state and local permits. Well-defined parameters and monitoring requirements need to be included that utilize compliance determining criteria, annoyance criteria, ambient odor criteria (threshold or intensity), ambient odorant criteria (mass concentration), episode duration-frequency criteria, source emission criteria (threshold or mass concentration) and best available control technology criteria (i.e. industry standards).

Response: The type of odor emitted is helpful to know for certain circumstances related to exposure; however, for control purposes, the specific odorant is not a requirement as the control technology is considered to be effective for all pollutants, whether regulated or not.

Comment 2-42: From the Air Permit Specifically. Appendix II. Best Management Practices Plan. Odor Prevention: A standard practice for determining odor intensity similar to ATM E679-91, ASTM E544-75,88 or a program utilizing a scentometer or similar program should be referenced. What governing body will regulate, field complaints, and ensure compliance for this project? Please detail the complaint criteria and method to file complaints.

Response: If a citizen has observed an incident that may either negatively impact the environment or be in violation of environmental regulations, they may contact the MPCA by calling 651-296-6300 or 1-800-657-3864 in Greater Minnesota or by filling out an online form at this web address: http://www.pca.state.mn.us/index.php/view-document.html?gid=17383

Comment 2-43: From the Air Permit Specifically. Appendix II. Best Management Practices Plan. Odor Prevention: Refer to Air Permit Receiving and Plant Area Ventilation Odor Emissions Estimate. Table A-8. (Using vegetable compost) Does not include biofilter or digestate areas.

Response: The biofilter would be at the facility to reduce odor from the receiving building, and the liquid industrial byproduct ponds would be covered to prevent odors. The pond covers are part of SDS permit.

Comment 2-44: From the Air Permit Specifically. Appendix II. Best Management Practices Plan. Odor Prevention: Odor components should be more accurately studied to ensure the exact odor species.


Comment 2-45: Odors Produced During Transport (Traffic-related odors). Regarding traffic and transportation of feedstock and effluent, upon roadways and through the city of Le Sueur, what odor

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control measurements will be applied for these vehicles to ensure meeting the Air Permit Control requirements?


Comment 2-46: Effluent Storage Ponds and Odors: The processes for controlling odors from the effluent holding pond are still not clear. There are comments on the possible use of a flaring system. I do not see a flaring system illustrated anywhere. Please provide this information if a flaring system will be used. If so, the flaring emissions should be added to the air permit.

Response: The liquid industrial byproduct ponds will be covered to reduce odor. The flare (EU 007) at the site is planned to be located to the west of the tanks. Emissions from the flare have been accounted for in the calculations the facility submitted. The Odor Management Plan submitted by the facility states that gas generation in the ponds is not expected from normal operation, but if it does occur, the gas may be routed to the flare or bioscrubber.

Comment 2-47: Effluent Storage Ponds and Odors: To properly control effluent pond odors I am requesting the need of a wet scrubber or other more efficient odor treatment device such as a catalytic burner.

Response: The odor from the ponds will be controlled with a cover.

Comment 2-48: Effluent Storage Ponds and Odors: This is a covered system, therefore basically anaerobic, and supposedly tightly sealed to prevent odor. So odors will be stored and building up inside that holding pond like a balloon. Eventually that gas has to go somewhere. Were will this go?

Response: The gas will be released as necessary. The facility has stated, though not expected, if a significant amount of gas is created it will be routed to the engines or the flare.

Comment 2-49: Effluent Storage Ponds and Odors: The cover system is not explained in detail of how it will perform. The EAW and other sources of information describes this as a floating cover. More detailed information is required to explain the expected efficiency of this system. How will it be sealed to prevent escape of emission gases and odor generating gases?

Response: The covers would be anchored in place around the perimeter of the ponds; a trench would be dug around the crests of the ponds’ berms and the edges of the cover are set into the trenches to cover the entire pond. The trenches are backfilled to secure the cover in place and prevent it from pulling free.

Comment 2-50: Effluent Storage Ponds and Odors: How will these odors be treated to control the odors. What if the odors generated will not burn through a flaring system? A properly designed digester with proper holding time should not generate butyric, propionic acids since these are highly digestible materials for a digester process. Many of the acid odor generating compounds are heavy non-combustible acids and partially soluble in water.


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Comment 2-51: Effluent Storage Ponds and Odors: Guaranteed odor control from the effluent holding ponds are lacking and have to be further addressed and a better odor system guaranteed. Stating that odor control must be complied with in the Air Permit is one thing, but presenting an efficient odor control system by the proposer is another. Since odor is a primary concern in this project it is requested this process be better explained and further studies to ensure proper odor control based upon the inferior information and design of this system.


Comment 2-52: Effluent Storage Ponds and Odors: H2S and ammonia gases cannot be ruled out as being generated in the effluent pond. How will these gases be treated?


Comment 2-53: Effluent Storage Ponds and Odors: Flaring may not be an effective control process if emission odorous gases are not at high enough concentrations to flare or if they are not combustible. Flaring may not be an effective odor controlling process for certain compounds if they are not combustible or if there is no carrier gas to enter them into the flaring process. How can flaring be an effective guarantee to control odors under the potential conditions?

Response: The draft permit does not require a flare to control odors. The facility has submitted an Odor Management Plan that describes how odors would be controlled and managed which includes an option to route gas from the pond to the flare.

Comment 2-54: Effluent Storage Ponds and Odors: Why will methane be generated in the effluent? Where did this information and calculations come from? If the feedstock is efficiently digested I would expect no analogs to generate methane in the effluent holding pond. So by this concept the proposer is stating the biodigester is an inefficient process. Please explain and confirm this contradiction.

Response: The purpose of the anaerobic digestion process is to create biogas, which is primarily methane. It is in the facility’s best interests to create as much biogas as possible from the feedstock; however, some methane forming components may remain in very small quantities in the liquid industrial byproduct that is stored in the ponds onsite.

Comment 2-55: Effluent Storage Ponds and Odors: What types of VOC’s and other gases that may present a health hazard will be generated from the effluent ponds? How and what studies were conducted on the mechanism to generated these VOC’s and to identify them? If they have to flare, how will that process be implemented? So far I see no design for the cover to be fitted with a flare. But it is indicated a flare system might be used. In other words, are they going to use a flare at the effluent holding ponds? Yes or no? If yes, this design must be included in the permit. If no, how will these VOC’s affect odor and other emission concerns?


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Comment 2-56: Effluent Storage Ponds and Odors: Previously stated, depending on the performance and balance of the digester, and the effluent composition which is supposed to have ample nitrogen fertilizer material, high levels of ammonia gas could be generated in the effluent holding ponds. How will odor control be applied for these kinds of odor-generating compounds?


Comment 2-57: Effluent Storage Ponds and Odors: It is mentioned that some silage juice under certain conditions may be diverted to the byproduct storage ponds. Silage juice has a BOD level of approximately 20,000 PPM. If silage juice is diverted to the holding ponds it will continue to create massive amounts of various odor components.


Comment 2-58: Effluent Storage Ponds and Odors: It is stated that the bioscrubber that removes hydrogen sulfide from the biogas will be cleaned and purged and that material will be sent to the effluent holding ponds. What effect will this have for the potential of generating odors? Will this material contain reduced forms of hydrogen sulfide such as sulfur, or will it be in oxidized forms such as sulfates? Either way, upon this material entering the effluent holding ponds will it add various chemical components that might continue to generate more hydrogen sulfide gas? This is a very important question regarding odor control and possible health issues under OSHA guidelines.


Comment 2-59: Effluent Storage Ponds and Odors: Since the proposer of this project has stated conducting laboratory pilot studies, and is contracting with Xergi, these effluent gases should be able to be some what replicated and odors therefore be conducted by a certified laboratory using GC/Mass Spec applications. The permit should not be approved until this information is available for a second review process.

Response: The MPCA has reasonable assurance that the proposed facility will not violate air quality standards.

Comment 2-60: Silage storage areas: To control odor in the silage bunkers, they are fitted with covers to cover silage and removed to gain access? That will not prevent odors.

Response: The covers would help control odor but would not eliminate it.

Comment 2-61: Silage storage areas: Bunkers storage should be fully enclosed in a building and have their own biofilter or reasonable odor control system. Using covers which are repeatedly removed is notgoing to control odor, since they will continue to be generated by silage decomposition.


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Comment 2-62: Silage storage areas: Drainage of silage juice by a trench drain is stated. Is this a closed or open system? Silage juice has a strong pungent odor and if the trench drain is not designed properly it is obvious odors will be released.

Response: The trenches would only be covered by a grate; the trenches flow to the sump where they will be pumped to the process or, in the case of high flows, will be pumped to the liquid industrial byproduct ponds. The trenches would be collection devices, not storage devices, they would not contain standing pools of liquid industrial byproduct.

Comment 2-63: Silage storage areas: The trench drain must be fully enclosed to prevent odors or access form water sources that can occur from heavy rain fall or complicate maintenance issues during wintertime.


Comment 2-64: Silage storage areas: It is mentioned that some silage juice under certain conditions may be diverted to the byproduct storage ponds. Silage juice has a BOD level of approximately 20,000 PPM. If silage juice is diverted to the holding ponds it will continue to create massive amounts of various odor components.


Comment 2-66: Silage storage areas: Filling of silage storage bins, and continuous removal of the covers are bound to generate extensive odors. This is not an acceptable odor control system.

Response: Comment noted.

Comment 2-67: Digestate Odor Control: Odor evaluations have not been conducted for the digestate drying process area.

Response: The Odor Management Plan submitted by the facility addresses this issue. Dryer velocity and solid retention time in the anaerobic digester are two areas that will be monitored to manage odor from the drying process.

Comment 2-68: Digestate Odor Control: Proper VOC or odor analysis has not been conducted on the digestate. This should be conducted.

Response: Requirements to conduct a VOC performance tests on EU 006 (the digester solids dryer) have been added to the permit to confirm the emission factor used in calculations.

Comment 2-69: Digestate Odor Control: The proposer of this project stated in public some pilot lab studies were conducted. Also, they stated they are using Xergi for the digester project. Since Xergi is supposed to be some what replicating this process it is requested to provide samples or certified data on the VOC content from drying digestate and the odor components.


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Comment 2-70: Digestate Odor Control: How is this system designed with the belt dryer and incoming heating exhaust? Is this an enclosed system to contain fugitive and other emissions? Is heat from the exhaust transferred by convection to the drying belt? Otherwise, by lack of detailed diagrams it appears odor emissions generated by the digestate drying process appears to go directly into a stack vent which means these odors will simply be discharged directly into the air. Has there been a blueprint of this system to be properly evaluated by the MPCA?

Response: The digester solids will be dried on a belt drier with the exhaust from the engines. The emissions from drying the digestate solids will be discharged directly to the atmosphere. Also see Response to Comment 2-68.

Comment 2-71: Other Odors In General: If the digestion process is inefficient, as implied by the proposer, above, there will be undigested volatile fatty acids remaining after the methanogenic step of the digestion process. These FA’s will be a source of odors.

Response: The MPCA does not have reason to believe that the proposer believes that the process is inefficient. The majority of volatile fatty acids will be consumed by anaerobic digestion to create biogas.

Comment 2-72: Other Odors In General: The proposed biofilter is only 70 to 90% efficient. This does not ensure adequate odor control and is not an acceptable process.

Response: See Response to Comment 2-9, 2-10 and 2-11.

Comment 2-73: Air Permit Technical Support Document: Major issues with PTE Emission calculations. Table A1. The table is extremely difficult to interpret the way the data is displayed. Periods are missing to accurately determine the units. This is especially true for the gensets. That table has to be re-done to allow reviewers and engineers to intelligently compare against their own calculations for accuracy.

Response: See Response to Comment 2-39. The calculation spreadsheet will be reformatted to improve readability.

Comment 2-74: Air Permit Technical Support Document: Major issues with PTE Emission calculations. Table A1. The data for using various emission and other calculations are inconsistent and unorganized making it is difficult to evaluate what is being used where or how.


Comment 2-75: Air Permit Technical Support Document: Major issues with PTE Emission calculations. Table A1. It appears this table is an exact duplicate from the applicant’s previous EAW for a different project (Le Sueur Energy Park, dated November 2010).


Comment 2-76: Air Permit Technical Support Document: Table A.5. Mass Balance and EU006 Solid Fuel Drying. VOC Calculations: Is the proposer stating VOC as VOC gas emissions or are they expressing the

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data as VOC Solids? It appears they are calling these solid VOC emissions. Should this be categorized as VOC’s or Particulates?

Response: As a conservative estimate, the proposer is assuming all solid VOCs are emitted to the atmosphere as VOC emissions. The proposer has calculated the emissions in a conservative manner. See also Response 2-24.

Comment 2-77: Air Permit Technical Support Document: Table A.6 Potential to Emit Green House Gas Calculations: Why are these gases being generated in the (basin) or effluent storage pond? This usually indicates an inferior or incomplete digestion process. However, since this is documented this further magnifies the need of a flare on the pond cover.

Response: The facility has submitted worst-case calculations. While significant gas production is not expected from the liquid industrial byproduct storage pond, it is possible and must be taken into consideration.

Comment 2-78: Air Permit Technical Support Document: Table A.6 Potential to Emit Green House Gas Calculations: In addition, how will odors be controlled if the odor gases will not combine with the methane gas, or the CO2 is too high to support combustion, or if the odor gases are not flammable. Most of the odor components are somewhat water soluble compounds and also do not combust. Therefore, it is recommended an odor filter, gas scrubber, or other efficient device to control odor be included on this system.


Comment 2-79: Air Permit Technical Support Document: TableA-8. Receiving and plant area ventilation odor estimates. “Quantifying odor Emissions from Composting”: This data is not acceptable. Vegetative feedstock arriving in the facility will not have been treated through a composting process. Odor components of silage are well documented in the literature. This clearly indicates inaccuracy in this data. It is well-established that one of the highest components produced during silage decomposition is acetic acid.

Response: The feedstock arriving daily by truck is food processing residuals, not corn silage. Composting odors from uncomposted material are a reasonable comparison to the feedstock odors.

Comment 2-80: Air Permit Technical Support Document: TableA-8. Receiving and plant area ventilation odor estimates. “Quantifying odor Emissions from Composting”: In addition, silage and the other feedstock materials are in abundance to conduct proper odor tests. I requested that further testing be conducted by a certified laboratory and the results shared before this permit is approved.

Response: The MPCA has reasonable assurance that the proposed facility will not violate air permit standards.

Comment 2-81: Air Permit Technical Support Document: Regarding Emission concerns: I will include a copy of my excel spread sheet that is a watered down basic means of how I calculated and tracked air

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emissions while at General Mills. Please evaluate this and respond to me if you find errors in my calculations to provide fairness to this project. The only section of the spreadsheet you have to focus on is the “emissions” section. Note g/hp. x 1 lb./454 g. x 2826 (hp) x 8760 hr./yr x 1 ton/2000 are the calculation method I am using in calculating PTE. The Emissions Input section is only used to finalize the data and use for charting applications. The tracking hours are only to apply for tracking actual emissions and that can be ignored. The Traffic section are notes on calculating VMT # trucks and distance. The charts may interest you and these are reflections of the emissions. Actual emissions are using the emission units x hp. x CE units x hrs. of operation through the tracking section in units per month.

Response: Commenter has been provided with the excel spreadsheet used to draft the in order to compare his calculations.

Comment 2-82: Overall, the Air Permit itself is excellent in assuring actions for compliance. The big issue is the substandard issues to ensure this facility can construct this project effectively and have the skills to both make the system operate successfully and to comply to the Air Permit requirements. I thank the MPCA for such a tremendous effort and a good final product.


3. Comment by Bruce McKay. Email received March 21, 2012. Letter received March 21, 2012.

Comment 3-1: In the Air Permit Document, if any GP 001 CO emission factor verification test measures at 0.88 g/hp-hr or greater or formaldehyde emission factor verification test measures at 0.60 lb/hr or greater, the Permittee shall submit an application for a major amendment. The application shall propose a reduction of the 31,000 hr/yr GP 001 operating limit to a level that will limit GP 001 CO emissions to no greater than 85.0 tons per year and formaldehyde to less than 9.0 tons/year.

Response: This requirement will be split into two separate requirements for clarity.

Comment 3-2: In the Air Permit Document and in the Support Document, stack height has not been fully and properly addressed taking into account the urban setting, the height of neighboring structures, and the relative elevation of surrounding terrain. Is an Air Emissions Risk Analysis or an Environmental Impact Statement needed to complete the stack height assessment?

Response: Please see comment 2-1.

Comment 3-3: In the Support Document, Table 2 should clearly describe the categories “Uncontrolled PTE (Entire Facility)” (8760 hours runtime per generator per year (35,040 hr/yr total)), “Controlled PTE (Entire Facility)” (7750 hours runtime per generator per year (31,000 hr/yr total)), and “LimitedControlled PTE (Entire Facility)” (5840 hours runtime per generator per year (23,360 hr/yr total)) and the role and necessity of the control elements in the emissions mitigation process that allow reduction of the Uncontrolled PTE numbers to the lower PTE numbers.

Response: The “uncontrolled PTE” is based on 8,760 hours of operation annually with no control equipment; the “controlled PTE” is based on 8,760 hours operation with control equipment (catalytic oxidizers); and the “limited controlled PTE” is based on 7,750 hours of operation with control

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equipment. The calculations that were submitted based on 5,840 hours annually are necessary for the MPCA emissions inventory. The facility has estimated the actual operating hours will be 5,840 hours.

Comment 3-4: In the Support Document, the EAW should be correctly described as mandatory and any related topics, such as Permit Fee Assessment, should be dealt with accordingly.

Response: This has been corrected.

Comment 3-5: In the Support Document, there are estimates for the Receiving and Plant Area Ventilation Odor Emissions (Table A-8), but there are no estimates for odor from digestate drying, silage storage area, trench drain system, or holding ponds. These other odor sources should be fully defined and more complete mitigation plans and operating and maintenance procedures designed and described for them.

Response: The odor estimates are not necessary to draft the air permit because the air permit does not regulate odor that is not a health issue. The MPCA has reasonable assurance that the facility will not violate air standards.

4. Comment by Kevin Skelly. Comments received in writing at public meeting March 20, 2012

Comment 4-1: What type of technology will be used for hydrogen sulfide removal and siloxane removal? In the waste air stream to the gensets and will there be back up air controls emissions fro these components?

Response: Hydrogen sulfide will be removed with a bioscrubber. Siloxanes are not expected to be present in significant amounts. Siloxanes are typically present in gas created at wastewater treatment plants and landfills because the feedstock at those sources contain cosmetic products which contain siloxanes. Cosmetic products are not part of the feedstock at this facility.

Comment 4-2: Will there be limits placed on hydrogen sulfide and siloxanes?

Response: The draft permit contains a limit of 300 ppm of hydrogen sulfide in the gas combusted in the gensets in order to limit SO2 emissions. There is no limit on siloxanes because it is not a regulated pollutant. There are requirements to test the catalysts’ activity periodically; if the catalyst is fouled the facility would be required to replace or recondition the catalyst.

5. Comment by Mary Scott Riviere. Received by mail March 26, 2012

Comment 5-1: Community resident Frank Ebert has invested a significant amount of his time and energy researching the impact of this project on our community. He has significantly more scientific knowledge, training and experience then most community members. It appears that he has pointed out concerns based on his research, yet we do not know if his calculations have received review and consideration. This increases the fear and distrust in the project by those without the scientific knowledge and training. Who will respond to his research?

Response: The air permit engineer will respond to his comments. Please see the responses to Frank Ebert’s letter previously in this document.

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7. Comment by Dave Graff. Email received March 27, 2012

Comment 7-1: Due to the many concerns, I would request an EIS before the project is approved.

Response: The decision to require an environmental impact statement (EIS) is not a matter for the air quality permit; that question to conduct and EIS was brought before the MPCA Citizen's Board and the Board made a decision not to order an EIS.