Air Emission Permit No. 03700011-010 Is Issued to Flint Hills ......21 GP 037 IFR tank/basin subject...

Table A: Limits and Other Requirements 1 Total Facility A‐1 2 GP 002 Cooling Towers (#1, #3, #4, #5, #6 and #7) and associated Heat Exchange Systems A‐15 3 GP 003 ULSD Project CO Emissions A‐18 4 GP 004 ULSD Project VOC Emissions A‐19 5 GP 007 Tanks subject to NSPS UU (each tank) A‐20 6 GP 008 External Floating Tanks NSPS Kb > 39,890 gallons A‐22 7 GP 009 Tanks subject to VOC Limit (CFP) A‐23 8 GP 010 Tanks/Basins subject to NESHAP FF w/vapor recovery & control device A‐25 9 GP 011 Diesel Engines with SIP Conditions and 39,890 (0.75‐11.1 psi) A‐32 14 GP 023 NSPS K Tanks w/fixed roof > 40,000 gals without CVS/CD A‐37 15 GP 024 NSPS Ka Tanks w/fixed roof > 40,000 gals A‐38 16 GP 025 NSPS Kb Tanks w/fixed roof > 39,890 gals A‐39 17 GP 026 NSPS Kb Tanks w/fixed roof & CVS/CD 19,813‐39,890 gals (vp > 4.0 psi) A‐41 18 GP 027 NSPS Kb Tanks w/fixed roof between 19,813 and 39,890 gals A‐44 19 GP 032 NSPS K Tanks w/fixed roof & CVS/CD & > 40,000 gals A‐45 20 GP 034 NSPS Kb Tanks w/fixed roof & CVS/CD > 39,890 and tvp > 0.75 A‐46 21 GP 037 IFR tank/basin subject to NESHAPs FF following the requirements of Kb A‐49 22 GP 038 NSPS Kb Tanks w/internal floating roof > 39,890 gallons A‐50 23 GP 039 NSPS Kb Tanks w/internal floating > 39,890 gals & tvp (0.75‐11.1 psi) A‐51 24 GP 042 MACT CC Group 1 Tank Requirements, satisfied by NSPS Kb A‐56 25 GP 044 Tanks MN R 1969‐73 and > 65,000 gals A‐58 26 GP 045 Tanks MN R 1969‐73 and 2,000 ‐ 65,000 gals A‐59 27 GP 046 Tanks MN R post 1973 and > 40,000 gals A‐60 28 GP 047 Tanks MN R post 1973 and 2,000 ‐ 40,000 gals A‐62 29 GP 052 Tanks NSPS QQQ A‐63 30 GP 053 EFR tank/basin subject to NESHAPs FF following the requirements of Kb A‐64 31 GP 054 Storage Tank Heaters built before June 11, 1973 A‐65 32 GP 055 Emission Units subject to Minn. R. built before June 11, 1973 A‐66 33 GP 056 Storage Tank Heaters built after June 11, 1973 A‐67 34 GP 057 Emission Units subject to Minn. R. built after June 11, 1973 A‐68 35 GP 058 Equipment subject to both NESH FF controls and NSPS QQQ A‐69 36 GP 059 Containers subject to NESH FF; w/vac trucks to haul NESH FF waste A‐70 37 GP 060 Oil/water separators w/floating roof subject to NSPS QQQ and NESHAP FF A‐72 38 GP 062 Oil/water separators w/fixed roof subject to NSPS QQQ and NESH FF w/CVS &

control device A‐74 39 GP 065 Treatment Processes to meet destruction req. NESH FF A‐76 40 GP 067 All equipment included in individual drain system subject to NSPS QQQ or

NESHAPs FF A‐78 41 GP 068 Drains subject to NESH FF equipped with plugs A‐80 42 GP 069 Drains subject to NESH FF and also subject to NSPS QQQ (water seal; lube oil or

equivalent) A‐82 43 GP 071 Drains subject to NSPS QQQ (sealed w/plug) A‐84 44 GP 072 Drains subject to NSPS QQQ active (water seal, lube oil or equivalent) A‐85 45 GP 075 Drains subject to NSPS QQQ inactive (equipped with plugs water seal or A‐86

equivalent) 46 GP 076 Junction Boxes subject to NESH FF when equipped with carbon canisters A‐87 47 GP 077 Junction Boxes receiving Wastewater from NSPS QQQ units not subject to

NESHAPs FF A‐89 48 GP 079 Non‐contact Cooling Water Systems A‐90 49 GP 080 Stormwater Sewers A‐91 50 GP 081 Fugitive Compressors Exempt from LDAR Requirements A‐92 51 GP 082 Fugitive Compressors LDAR Requirements A‐93 52 GP 087 Fugitive LDAR All Equipment in VOC or HAP Service A‐94 53 GP 088 Fugitive LDAR in Vacuum Service A‐98 54 GP 089 Fugitive LDAR Emission Sources not in VOC or HAP Service A‐99 55 GP 090 Fugitive LDAR Equipment Designated Non‐detectable emissions (NDE) A‐100 56 GP 091 Fugitive LDAR Open‐ended Lines A‐103 57 GP 093 Fugitive LDAR PSV to Atmosphere in Gas/Vapor Service A‐105 58 GP 094 Fugitive LDAR PSV with Upstream Rupture Disks A‐107 59 GP 095 Fugitive LDAR Pumps in Heavy Liquid Service A‐108 60 GP 096 Fugitive LDAR Light Liquid Pumps A‐110 61 GP 099 Fugitive LDAR Sample Stations A‐112 62 GP 100 Fugitive LDAR Heavy Liquid Valves and PSVs (in LL/HL Service) A‐114 63 GP 101 Fugitive LDAR Valves in Light Liquid Service A‐116 64 GP 102 Units where carbon canisters may be used to meet NESHAP FF Requirements A‐120 65 GP 104 Refinery Emergency Flares and Flare System (for Consent Decree Flare Policy) A‐123 66 GP 106 Control Equipment Used to Meet Requirements of MACT CC A‐126 67 GP 111 Fuel Gas Supply Systems A‐127 68 GP 112 Sulfur Recovery Units A‐129 69 GP 114 Fugitive LDAR Connectors, Misc. All FS numbers are included in this group A‐131 70 GP 115 Sulfur Degassing System A‐132 71 GP 116 Refinery Fuel Gas SO2 Emissions A‐133 72 GP 117 Limit that Applies to Gas Oil HDS Heaters (EU084 and EU085) A‐134 73 74

GP 118 Temporary Portable Coke Crushers GP 122 Liquid Butane Storage Facility

A‐135 A‐136

75 76 77 78 79 80

GP 123 Equipment subject to NSPS NNN GP 124 Drains subject to NESH FF only and equipped w/water seal or equivalent GP 125 Drains Subject to NESH FF and NSPS QQQ sealed with plugs GP 126 Affected Sources at the refinery under MACT GGGGG GP 127 Stationary Diesels (Compression Ignition) Subject to MACT ZZZZ GP 128 Stationary Diesels (Spark Ignition 4SRB) Subject to MACT ZZZZ

A‐138 A‐139 A‐141 A‐143 A‐144 A‐146

81 GP 131 Vapor Combustion Unit A‐147 82 GP 132 Fugitive Equipment in Natural Gas (non‐VOC) Service A‐150 83 SV 042 #5 SRU 26 Unit Stack A‐151 84 SV 066 32H5 6 7 Stack A‐154 85 SV 082 37H1 2 6 Stack A‐156 86 SV 083 37H3 4 5 Stack A‐157 87 SV 093 45H61 Stack A‐159 88 SV 094 45H6 Stack A‐162 89 SV 165 Hydrocracker Feed Heater and Reboiler A‐164 90 EU 004 Truck Bottom Loading (gas, distillate) including the trucks A‐165 91 EU 005 #1 Crude Heater atmospheric distillation A‐167 92 EU 006 #1 Crude Heater crude preflash A‐169 93 EU 016 Vacuum Pre‐Strip Heater A‐170

94 EU 019 #2 Vac Heater A‐172 95 EU 026 #1 Vac Heater A‐174 96 EU 028 #1 Coker Heater A‐176 97 EU 030 #2 Coker Heater A‐178 98 EU 032 Steam/Air Heater Decoking ‐ 21H‐1 A‐180 99 EU 033 Steam/Air Heater Decoking ‐ 21H‐2 A‐181

100 EU 034 #3 Coker Heater A‐182 101 EU 035 #3 Coker Heater A‐184 102 EU 037 Steam/Air Heater Decoking 23H‐1 A‐186 103 EU 038 Steam/Air Heater Decoking 23H‐2 A‐187 104 EU 040 #3 Crude Unit Charge Heater A‐188 105 EU 041 #3 Crude Unit Vac Pre‐Fractionator Heater A‐191 106 EU 050 Distillate HDS Recycle Hydrogen Charge Heater A‐194 107 EU 051 Distillate Hydrotreater Fractionator Heater A‐196 108 EU 052 #2 H2 Plant Reformer Heater A‐198 109 EU 053 Naphtha Hydrotreater Reactor Charge Heater A‐201 110 EU 055 #2 HDS Fractionation Heater (31H2) A‐203 111 EU 056 HDS Heater (hot oil system) A‐205 112 EU 058 #5 HSD Charge Heater (naphtha) A‐206 113 EU 060 #1 HDS Fractionation Heater A‐207 114 EU 077 Powerformer Catalyst Regeneration A‐208 115 EU 084 Gas Oil HDS Charge Heater A‐210 116 EU 085 Gas Oil HDS Fractionation Charge Heater A‐212 117 EU 099 Platformer Catalyst Regeneration Vent A‐214 118 EU 102 Unit 38 Gasoil HDS A‐Train Heater A‐216 119 EU 103 Unit 38 Gasoil HDS B‐Train Heater A‐217 120 EU 104 Unit 38 Gasoil HDS Fractionation Charge Heater A‐218 121 EU 126 Steam Boiler No. 6 at Boilerhouse A‐219 122 EU 127 Plant Air Compressor Diesel Engine A‐221 123 124

EU 204 Steam Boiler #8 EU 209 Track 8 Rail Loading

A‐222 A‐224

125 EU 212 11H‐6 A‐225 126 EU 213 #3 H2 Heater A‐232 127 EU 228 FCCU A‐235 128 EU 241 #1 H2 Plant Reformer/Heater A‐241 129 EU 245 Merox Off Gas Incinerator (old SRU 1/2 incinerator) A‐243 130 EU 254 Unit 94H3 Thermal Oxidizer Back‐up A‐245 131 EU 276 Central Buffer Zone Offgas (86H41) A‐246 132 EU 277 West Buffer Zone Offgas (88H2) A‐247 133 EU 282 OSWTP ‐ Thermal Oxidizer A‐248 134 EU 296 No. 4 Hydrogen Plant Reformer A‐252 135 EU 312 No. 6 Cooling Tower Diesel Pump A‐254 136 EU 313 Steam Boiler No. 9 A‐256 137 EU 324 #3 Crude Unit Vacuum Heater A‐259 138 EU 336 Coke Drum System E and F A‐260 139 EU 337 Boiler B‐10 (Not Approved for Construction) A‐261 140 EU 352 23H3 Heater A‐262 141 EU 353 25H2 Heater A‐271 142 CE 002 Direct Flame Afterburner 101H1 A‐279 143 CE 003 Activated Carbon Adsorption A‐282

144 CE 006 Electrostatic Precipitator ‐ Medium Efficiency A‐285 145 CE 028 Direct Flame Afterburner (94H1) A‐287 146 CE 029 Direct Flame Afterburner (94H3) A‐290 147 148 149

CE 050 Flaring (102H1‐VCU) CE 056 Direct Flame Afterburner (88H2) CE 057 Direct Flame Afterburner (86H41)

A‐291 A‐293 A‐297

150 FS 001 Unburied Sewer Lines subject to NESHAP FF or NSPS QQQ A‐301 151 FS 009 Coke Pile A‐302 152 FS 027 15‐Coker Gasoline A‐303 153 154

FS 045 23‐Delayed Coker & Gasoline Plant FS 136 25 Unit Drains Requiring Emission Controls

A‐304 A‐305

155 MR 027 23H‐2 O2 Analyzer A‐306 156 MR 069 31H2 SO2 Analyzer A‐307 157 MR 152 NOx Monitor at 25H4 A‐308 158 MR 153 CO Monitor at 25H4 A‐309 159 MR 154 O2 Monitor at 25H4 A‐310 160 MR 156 41 Unit Fuel Gas Mix Drum Total Sulfur A‐311 161 MR 161 45 Mix Drum Fuel Gas Combustion SO2 Monitor at 25H3 A‐312 162 MR 162 45 SO2 Monitor at 29H1/2 A‐313 163 MR 166 45 Mix Drum Fuel Gas Combustion O2 Monitor at 29H1/2 A‐314 164 MR 167 27H‐101 CO Monitor A‐315 165 MR 168 27H‐101 NOx Monitor A‐316 166 MR 170 71B6 NOx Monitor A‐317 167 MR 171 71B6 CO Monitor A‐318 168 MR 179 29H‐1/2 NOx Monitor A‐319 169 MR 180 29H‐1/2 CO Monitor A‐320 170 MR 181 29H‐1/2 O2 Monitor A‐321 171 MR 182 27H‐101 O2 Monitor A‐322 172 MR 196 45 Unit Fuel Gas Mix Drum Total Sulfur

A‐323

TABLE A: LIMITS AND OTHER REQUIREMENTSFlint Hills Resources Pine Bend LLC

03700011 - 010

Facility Name:

Permit Number:

09/09/13A-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 itThe Permittee is authorized to construct and modify equipment associated with the#3 Crude/Coker Improvements Permit and as described in Air Emission Permit No.03700011-010. The Permittee must commence construction within 18 months ofissuance of Air Emission Permit No. 03700011-010.

40 CFR Section 52.21(r)(2) and Minn. R. 7007.3000

STATE IMPLEMENTATION PLAN (SIP) REQUIREMENTS hdr

Sulfur Dioxide: less than or equal to 3770 tons/year using 365-day Rolling Average Title I Condition: SIP for SO2 NAAQS, 40 CFR pt. 50;40 CFR pt. 52, subp. Y, MN SIP

Refinery Fuel Oil Restrictions: The owner or operator shall not burn refinery fuel oilat any Refinery location.

Title I Condition: SIP for SO2 NAAQS, 40 CFR pt. 50;40 CFR pt. 52, subp. Y, MN SIP

CHANGES NOT REQUIRING A MODIFICATION OF THE SIP:The owner or operator is authorized to begin construction of the activities listedbelow at the Refinery without a modification of the SIP. The Permittee may conductactivities not listed below without a modification of the SIP, if the activities do notemit sulfur dioxide, do not affect the modeling parameters assumed in Appendix C,and do not affect the continuous emission monitors (CEMs) or continuousmonitoring systems (CMSs) used to demonstrate compliance with SIP. ThePermittee shall, however, obtain an air emission permit prior to commencing anynew activity or facility modification if one is required by Minnesota statutes,Minnesota rules or federal statutes and regulations.(continued below)


(continued from above)After obtaining the appropriate air emission permit (if required) but prior to amodification of the SIP, the Permittee may begin construction of a new unit ormodification to an existing unit. However, the Permittee shall not operate a newemission unit and shall not operate a modified unit in a manner contrary to themodeling parameters in Appendix C for that unit until the modification to theSIP is obtained and approved by EPA.

A. The Permittee may install and operate any new SO2 process and controlequipment with a maximum potential SO2 emissions rate that does not exceed2.28 lbs/hr, except as expressly allowed elsewhere in the permit.

The Permittee may modify and operate any existing SO2 process or controlequipment to increase the SO2 emission rate up to 2.28 lbs/hr over the modeledemission rate for that emission unit in Appendix C.(continued below)


(continued from above)B. The Permittee may physically and operationally modify process and controlequipment if the modification do not increase the modeled sulfur dioxide emissionsrate above the amount allowed in Appendix C, decrease the modeled stackemissions exit velocity, or decrease the modeled heat content of the stack exitemissions, at the emission source where the modification occurs and all otherpotentially affected emission points assumed in the modeling presented inAppendix C.

C. The Permittee may modify or replace and operate an existing sulfur dioxideemissions stack with a new stack if the height of the modified or replacement stackis not less than that of the stack assumed in the modeling presented in Appendix C,and if the exit diameter of the modified or replacement stack is not greater than thatof the stack assumed in the modeling presented in Appendix C.(continued below)



03700011 - 010

Facility Name:

Permit Number:

09/09/13A-2

(continued from above)D. The Permittee may install and operate new structures, or modify and operateexisting structures if the new or modified structures do not increase the effectivestructural dimensions assumed in the modeling presented in Appendix C.

E. The Permittee may replace and operate replacement SIP CEMs and CMSscovered by this permit or the Permittee may install and operate additional CEMsand CMSs, so long as the new or replacement SIP CEMs and CMSs are properlycertified, comply with this permit and are operated and tested as required by thispermit.(continued from below)


(continued from above)F. The Permittee may add additional CEMs or CMSs as needed to provideredundancy, providing the Permittee notifies the Commissioner in writing at least 30days prior to conducting any CEM or CMS certification test. The Company maymodify the fuel gas delivery system if the following conditions are met: 1) fuel gasflow and hydrogen sulfide content must be continuously measured for all heaters,either by measuring the hydrogen sulfide level in the main Refinery fuel gas systemand feeding the heater directly from the system, or by separately monitoring the fuelgas to or sulfur dioxide emissions from the heater; and 2) any new fuel gasmonitors added to the system must be certified within 60 days of startup, mustmeet 40 CFR pt. 60, Appendix F QA/QC requirements, must have a QA/QC planprepared and implemented within 60 days of startup, and operate in accordancewith Minn. R. 7017.1090 within two quarters of startup.(continued below)


(continued from above)G. The boundaries of the Permittee owned property may be extended and existingfencing removed provided that the property excluded from the definition of ambientair, as shown in Appendix C, continues to meet the requirements in the permit.

H. The Permittee may modify its refinery in order to install a new boiler as modeledin Appendix C, to improve energy efficiency of EU 283 (94H-1), to decommissionEU 245 (34H-3) and re-route process gases to the existing EU 055 (31H-2)furnace. EU 245 (34H-3) may continue to operate if Merox off-gas is not routed toEU 055 (31H-2).


Company Property and Access Restrictions:

A. Access ControlThe owner shall have enclosed the boundaries of the property with a continuousfence, excluding access points, and shall have installed gates at each access point.The Permittee shall therefore keep the gates closed unless: 1) a guard or otherFHR employee or contractor patrols and monitors access at a gate or 2) authorizedpersons are entering or leaving the property through a gate.

B. Inspection, Maintenance, and RepairThe Permittee shall inspect the fencing and gates installed to ensure compliancewith access control at least annually.(continued below)


(continued from above)The owner or operator shall maintain and repair the fencing and gates to maintaincontinuous compliance. The Permitte shall complete all repairs and maintenance tothe fencing and gates as soon as possible, but no later than 30 days after the datethe Permittee observes the need for repair or maintenance, or after the MPCAnotifies the Permittee of the need for repair or maintenance.


GENERAL MONITORING REQUIREMENTS FOR THE SIP EMISSION UNITS Title I Condition: SIP for SO2 NAAQS, 40 CFR pt. 50;40 CFR pt. 52, subp. Y, MN SIP

A. Accurate Measurements Required1. The Permittee shall install, certify, calibrate, operate and maintain each SIP CEMand CMS, and shall conduct all non-continuous sampling and analysis as requiredby the permit to ensure accurate measurements of the parameters to be monitored.

2. The Permittee shall measure the stack sulfur dioxide concentration (ppm), stackvelocity and stack temperature and compute the sulfur dioxide emission rate in lb/hrto determine compliance with the emission limitations listed ifor EU245 (Merox TO),EU055 (31H-2), SV093 (SRU 3/4), SV042 (SRU 5), and SV019 (FCCU). TheCompany shall measure the Refinery fuel gas hydrogen sulfide concentration andfuel gas flow rate to determine compliance with the emission limit for sulfur dioxideemissions from Refinery fuel gas combustion.(continued below)



03700011 - 010

Facility Name:

Permit Number:

09/09/13A-3

B. Continuous Monitoring Requirements1. Generala) Compliance with Minnesota Rules and Federal Regulations. The Permittee shallmeet the requirements of Minn. Rs. 7017.1002 to 7017.1020 and 40 CFR Section60.13 with each CEM and CMS. If the requirements of Minn. Rs. 7017.1002 to7017.1020 and 40 CFR Section 60.13 differ, the more stringent regulation shallapply.

b) Continuous Operation of CMS and CEM Systems. The Permittee shall atall times properly operate and maintain each CMS and CEM system to providecontinuous, accurate, real time monitoring data for the determination ofcompliance with the terms and requirements of SIP requirements. In thosesituations where a CMS or CEM system becomes incapable of meeting therequirement of providing continuous, accurate, real time monitoring data, theCompany shall expeditiously replace or repair the CMS or CEM system and take allother measures as necessary to meet the requirement as soon as possible.(continued below)


(continued from above)2. Monitor Certificationa) Sulfur Dioxide CEMs. The Permittee shall certify each sulfur dioxide CEMas required by 40 CFR pt. 60, Appendix B, Performance Specification 2.

b) Emission Rate CMSs. The Permittee shall certify each continuous monitoringsystem as required by 40 CFR pt. 60, Appendix B, Performance Specification 6,except that the Company need not meet calibration drift requirements for those flowmonitors that are not designed for conducting calibration drift tests (pitot tube orventuri type).

c) Hydrogen Sulfide CMSs for Fuel Gas Monitoring. The Company shallcertify each hydrogen sulfide CMS as required by 40 CFR pt. 60, Appendix B, byusing the procedures specified in Performance Specification 7.(continued below)


(continued from above)d) Total Reduced Sulfur CMSs for Fuel Gas Monitoring. The Company shallcertify each total reduced sulfur CMS as required by 40 CFR pt. 60, Appendix B, byusing the procedures specified in Performance Specification 5.

e) All CEMs and CMS. All CEMs and CMS certification shall be conducted incompliance with Minn. Rs. 7017.1050- 7017.1080.


(continued from above)3. Quality AssuranceThe Permittee shall conduct a quality assurance and quality control (QA/QC)program as required by 40 CFR pt. 60, Appendix F, to properly maintain andcalibrate each CEM and CMS. The Permittee shall develop and follow the masterQA/QC Plans for each CEM and CMS.(continued below)


(continued from above)4. Monitoring System Uptimea) Mass Sulfur Dioxide CEM Systems.The Permittee shall operate and maintain each mass sulfur dioxide CEM system inaccordance with Minn. R. 7017.1090 so that compliance with each emissionlimitation determined from real time certified CEM monitoring.

b) Refinery Fuel Gas Sulfur Monitoring.The Permittee shall install, calibrate, maintain and operate a CMS for thehydrogen sulfide content of the refinery fuel gas at each of the inputs to therefinery fuel gas distribution loop. The CMS shall provide a continuous record ofthe hydrogen sulfide content in ppm.

The Permittee shall maintain an SO2 CMS at a representative heaterwhich combusts 45 unit mix drum fuel gas. The CMS shall provide a continuousrecord of the sulfur dioxide content of the heater exhaust in ppm.(continued below)



03700011 - 010

Facility Name:

Permit Number:

09/09/13A-4

(continued from above)The Permittee shall maintain a CMS which measures reduced sulfur in the 41 unitmix drum fuel gas stream. The CMS shall provide a continuous record of thereduced sulfur content of the fuel gas in ppm.

For heaters receiving refinery fuel gas that is neither inherently low in sulfur, norcategorically exempt in accordance with NSPS J (or Ja version) 40 CFR Sections60.104 and/or 60.105 (40 CFR 60.102a and/or 60.107a) from sources other thanthe main refinery fuel gas distribution loop , the Company shall continuouslymeasure the hydrogen sulfide content of the refinery fuel gas or monitor inaccordance with an EPA-approved Alternative Monitoring Plan (AMP) at arepresentative point in the line supplying the heater. For heaters receivingcommercial grade fuels directly, (e.g., commercial grade natural gas and propane),contract guarantees for hydrogen sulfide and heat content shall be utilized forcompliance demonstration purposes.(continued below)


(continued from above)c) Each CEM or CMS must be operated and data recorded during all periods ofemission unit operation including periods of emission unit startup, shutdown, ormalfunction. This requirement to operate the monitor applies whether or not anemission limit applies during these periods.

CEM or CMS downtime is unacceptable except for reasonable periods ofmonitor downtime due to the following causes:(1) damage to the CEM or CMS due to acts of God such as lightning strikes,tornadoes, or floods that render the CMS inoperative;(2) sudden and not reasonably preventable CEM or CMS breakdowns;(3) scheduled maintenance based on equipment manufacturer's recommendedschedule which cannot be reasonably conducted when the emission unit is notoperating; or(4) unavoidable CEM or CMS downtime to conduct required checks and audits.


C. Non-Continuous Monitoring Requirements1. The Permittee shall perform non-continuous monitoring as required by the permit;

2. The Permittee shall conduct performance stack tests to determine compliancewith the SIP emission limitations and fuel restrictions as required by theCommissioner pursuant to Minn. Rs.7017.2001 to 7017.2060. Stack tests can alsobe required by authorized EPA personnel. All performance tests shall be conductedin accordance with the requirements of Minn. Rs. 7017.2001 to 7017.2060. ThePermittee shall submit to the MPCA performance stack test plans, protocols andschedules at least 15 days prior to the pretest meeting requirements listed below.


Recordkeeping Requirements:The Permittee is required to keep specified records so that EPA and the MPCA canevaluate the Permittee's compliance SIP requirements for the following.1. the Permittee must keep records on maintenance of property access controls.

2. the Permittee must keep records on the Refinery control plans and complianceschedules.

3. the Permittee must keep records in the form and with the accessibility neededfor EPA and MPCA staff inspection.


Recordkeeping for Property Boundary Fencing and Gates:The Permittee shall maintain records of each inspection of the fencing and gates asrequired . In addition, the Permittee shall maintain records of each maintenanceactivity and each repair activity as required. The Permittee shall retain eachinspection, maintenance and repair record for a minimum of five years from thedate the record was generated, despite any Permittee document retention policy tothe contrary. These records shall be kept at the Refinery.

1. The inspection records shall include: the date of inspection; name of the personconducting the inspection; identification of each section of fence and each gateinspected; and identification of each location where repair or maintenance isrequired. The inspection report shall be certified as accurate in writing by theperson conducting each inspection.(continued below)


(continued from above)2. The maintenance and repair records shall include: the dates of the repairs ormaintenance; a description of the repair and maintenance conducted; and thelocations where they occurred. The maintenance and repair records shall becertified as accurate by the person(s) overseeing each maintenance or repairaction.



03700011 - 010

Facility Name:

Permit Number:

09/09/13A-5

RECORDKEEPING REQUIREMENTS FOR SIPThe Permittee shall maintain for the Refinery a copy of the records requiredpursuant to the SIP. Records shall be retained at the Refinery.

1. Permanent RecordsThe Permittee shall permanently maintain the following information together with allamendments, revisions, and modifications to this information.a) Design, Construction and Operation Information. The Permittee shall maintaininformation on the design, construction and operation of each emission facility,emission source, fuel system, stack, structures pertinent to modeling for downwashin Appendix C, and any other information required to conduct sulfur dioxide ambientair quality modeling of emissions from the Refinery.(continued below)


(continued from above)These records shall also include all information required to demonstrate that theequipment identified in Appendix C is installed as described in that Appendix C.Where an activity has been undertaken for changes not requiring a SIPmodification, the records shall include a description of each activity and allinformation required to demonstrate that the activity complies with each applicablerequirement pursuant to changes not requiring a SIP modification. The recordsshall also identify and provide information on the design, construction and operationof each modification or new installation at the Refinery as required by the SIP.

b) Information on Sulfur Dioxide Emission Limits, Operational Requirements, andModeling Parameters. The Permittee shall maintain records at the Refinery. Theserecords include all applicable SIP requirements.


(continued from above)2. Non-Permanent RecordsThe Permittee shall retain the information identified below for a minimum of fiveyears following the date on which the information was obtained, despite anydocument retention policy to the contrary. This retention period shall beautomatically extended upon the Commissioner's written request.(continued below)


(continued from above)a) Monitoring, Testing, and Other Records. The Permittee shall maintain records ofall measurements, including: all continuous monitoring system and continuousmonitoring device measurements; all performance stack testing measurements andoperating conditions during the performance stack tests; all continuous monitoringsystem performance evaluations; all continuous monitoring system or monitoringdevice calibration checks; all adjustments and maintenance performed on thesesystems or devices; and all other information required or applicable to verifycompliance with the SIP. The Permittee shall prepare and maintain records of theone-hour averages for stack sulfur dioxide concentration (ppm); stack diameter,stack velocity and stack temperature; and the sulfur dioxide emission rate in lb/hr todetermine compliance with refinery fuel gas SIP emission limitations listed in thisPermit.(continued below)


(continued from above)The Permittee shall prepare and maintain records of the one-hour averages of therefinery fuel gas hydrogen sulfide concentration and fuel gas flow rate todetermine compliance with the refinery fuel gas SIP emission limit. Using theone-hour averages, FHR shall calculate the three-hour, twenty four-hour, andannual rolling averages corresponding to the SIP emission limits referenced in thepermit.

b) Sulfur Dioxide Emissions, Fuel Records and Operations Records. The Permitteeshall maintain records to demonstrate compliance with the sulfur dioxide emissionslimitations, and fuel use and quality restrictions and operational requirements.These records shall be designed, and the information shall be maintained in a formsuitable for the Commissioner to quickly determine compliance with each of theemission limitations, fuel restrictions, and operational requirements of the SIP.(continued above)



03700011 - 010

Facility Name:

Permit Number:

09/09/13A-6

(continued from above)c) Startup, Shutdown, Bypass, and Breakdown Records. The Permittee shallmaintain records for each startup, shutdown, bypass and breakdown for eachpiece of process equipment, control equipment, fuel supply system, emissionstack, monitoring system and any other piece of equipment as applicable. Theserecords shall include the date and time of the start and stop of each event.

d) Excess Emissions, Exceedances of Fuel Usage and Quality Restrictions andNon-Compliance with Operational Requirements Records. The Permittee shallmaintain a record of each exceedance of an emission limitation, fuel use restrictionand fuel quality requirement, and operational requirement at the Refinery for eachemission point and fuel system subject to the emission limitations, fuel restrictions,and operational requirements of the SIP.(continued below)


(continued from above)The record shall include for each period of exceedance a description of theexceedance, its cause, the magnitude of the exceedance, and the date and timeof commencement and cessation of the exceedance.

e) Operations Records for CEMs and CMSs. The Permittee shall maintain anoperations record for each CEM and CMS used to establish compliance with theterms and conditions of this Order. The operations record shall specify each dateand time the CEM or CMS was inoperative and the nature of the CEM or CMSrepairs or adjustments. The operations record shall include for each calendarquarter, the percent of time the CEM or CMS was operating and the percent of timethe CEM or CMS was not operating. The Company shall also record for eachcalendar quarter, the amount of time the process associated with the CEM or CMSwas operated.(continued below)


(continued from above)C. Record MaintenanceThe Permittee shall maintain all required documents, records, reports and plans in aformat suitable for determination of FHR's compliance with SIP requirements byEPA or MPCA staff. The Permittee shall maintain the information in a form that iseasily accessible for inspection by EPA or MPCA staff, and that is available forinspection at all reasonable times.


REPORTING REQUIREMENTS FOR SIPA. Notifications for SIP Requirements1. Notification of Process or Control Equipment Shutdown:The Permittee shall notify the Commissioner of shutdown of any control equipmentor process equipment governed SIP in accordance with Minn. R. 7019.1000, subp3.

2. Notification of Process or Control Equipment Breakdown:The Permitt shall notify the Commissioner of breakdowns of control equipment orprocess equipment governed SIP in accordance with Minn. R. 7019.1000, subp. 2.(continued below)


(continued from above)3. Notification of CEM or CMS Breakdown:The Company shall notify the Commissioner of a breakdown or malfunction ofany CEM or CMS used to demonstrate compliance with the terms and conditions ofthis Permit in the next air quality quarterly report (NSPS excess emissions and1989 Stipulation Agreement quarterly report) following the breakdown ormalfunction. The Company shall include the information identified in Minn. R.7017.1110, subp. 2(B).(continued below)


(continued from above)4. Notification of CEM or CMS Certification Test and Quality Assurance Audit Test:The Permittee shall notify the Commissioner in writing at least 30 days prior toconducting any CEM or CMS certification test for any CEM or CMS required to becertified pursuant to SIP requirements. The Permittee may request a pretestmeeting with the MPCA staff by making the request at least seven days prior toconducting any CEM or CMS certification test for the CEMs or CMS requiredpursuant to the SIP requirements. The Permittee shall notify the Commissioner inwriting at least seven days prior to conducting calendar quarter quality assuranceaudit test procedures for those CEMs or CMSs required. Exceptions to thesedeadlines may be approved by MPCA on a case-by-case basis.(continued below)



03700011 - 010

Facility Name:

Permit Number:

09/09/13A-7

(continued from above)5. Notification of Performance Tests:The Company shall notify the Commissioner of its intent to conduct performancestack tests required pursuant to this Order not less than 30 days prior to conductingeach performance stack test as required by Minn. R. 7017.2030. The Companymay request a pretest meeting with the MPCA staff by making the request at leastseven days prior to conducting a performance stack test. The test date is subject tothe Commissioner's approval and shall be approved by the Commissioner at least15 days before the planned test date. Exceptions to these deadlines may beapproved by MPCA on a case-by-case basis.

6. Notification of Regularly Scheduled Turnaround on any Tail Gas Treating (TGTU)Unit:The Company shall notify the Commissioner in writing 30 days prior to performingregularly scheduled turnaround (scheduled unit shutdown for maintenance)on any TGTU Unit.


B. Quarterly ReportsThe Permittee shall submit to the Commissioner each calendar quarter, a reportthat contains the following information: sulfur dioxide emissions limits,refinery fuelgas hydrogen sulfide content (in a form that allows direct comparison with the SIPrequirements) on hard copy or electronic copy; 45 mix drum fuel gas total reducedsulfur content, or equivalent stack gas SO2 concentration (in a form that allowsdirect comparison with the SIP requirements); a record of data used in calculating,and calculations of the sulfur dioxide emissions, refinery fuel gas hydrogen sulfidecontent; a record of each steam-air decoke event; a record of each startup,shutdown, bypass and breakdown of process and control equipment;(continued below)


(continued from above)a summary record of excess sulfur dioxide emissions, exceedances of fuel usageand quality requirements and noncompliance with operational requirements, or thePermittee shall state if no exceedances or noncompliance conditions occurred inthe quarter; a summary of CEM and CMS operation records including the amountof time the process equipment was operated; and, any quality assurance testresults that do not meet the requirements of 40 CFR pt. 60, Appendix F (2010).Quarterly reports shall be postmarked within 30 days following the end of eachcalendar quarter. Upon written notification by the Commissioner, the Company maycease including sulfur dioxide emissions, fuel usage and quality, records of dataused in calculating, and calculations of sulfur dioxide emissions, and fuel usageand quality in the quarterly reports. However, the Permittee shall submit this datawithin 30 days of receipt of a written request by the Commissioner.(continued below)


(continued from above)C. Performance Stack Tests ReportsThe Permittee shall submit to the Commissioner, reports of each performancestack test conducted pursuant to this order. Performance stack test reports shall bepostmarked no later than 45 days following completion of the performance stacktest, unless otherwise approved by the MPCA.

D. CEM Certification Test ResultsThe Permittee shall submit to the Commissioner, the results of each CEMcertification test required pursuant to the SIP. Certification test reports shall bepostmarked no later than 45 days after the CEM certification test date, unlessotherwise approved by the MPCA.

E. CEM and CMS Audit Test ResultsThe Permittee shall submit to the Commissioner, the results of quarterly cylindergas audits and annual relative accuracy tests. Submitted results of quarterly auditsand annual relative accuracy tests shall be included in the quarterly report for thequarter in which they were conducted.


GENERAL CONDITIONS FOR SIP REQUIREMENTS

A. Before the Permittee begins operation of new or modified equipment notspecifically allowed by the SIP and which results in additional sulfur dioxideemissions, or changes to sulfur dioxide emission patterns assumed in the modelingpresented in Appendix C, the Permittee shall obtain a modification to this Permit;

B. The SIP is meant to delineate Minnesota's strategy for attainment in the PineBend area from the present into the future, and is not an admission that therestrictions in 40 CFR Sections 52.24 (a) and (b) (1991) previously applied orcurrently apply to the Pine Bend area.(continued below)



03700011 - 010

Facility Name:

Permit Number:

09/09/13A-8

(continued from above)C. This permit does not relieve FHR of the obligation in undertaking all actionsrequired by the SIP provisions, to comply with all applicable local, State andFederal laws and regulations, including, but not limited to, federal new sourceperformance standards, and laws and regulations related to occupational safetyand health. In the event there is a conflict in applicable federal or state of local lawsor regulations, the more stringent of the conflicting provisions shall apply.(continued below)


(continued from above)D. The MPCA, EPA or their authorized representatives shall have authority to enterall property of the Company in Rosemount, Minnesota, at all reasonable times forthe purposes of inspecting records, operating logs and contracts related to thePermittee's compliance with SIP Conditions; reviewing the progress of thePermittee in implementing of the SIP Conditions; conducting such tests as the EPAor MPCA deem necessary to determine compliance with SIP; and verifying the datasubmitted to the EPA and MPCA by the Permittee. The Permittee shall honor allreasonable requests for such access by the EPA or MPCA staff, conditioned onlyupon presentation of proper credentials. This section does not limit any other rightof entry and inspection held by the EPA and MPCA pursuant to applicable federalor state laws, rules or permits.(continued below)


(continued from above)E. The Title I SIP Conditions in this Permit shall be binding upon the Permittee andits respective officers, employees, successors and assigns. FHR shall provide acopy of this Permit to any successor in interest prior to transfer of that interest, andshall simultaneously inform the MPCA that this notice has been given. Should thePermittee sell or otherwise convey or assign any of its right, title or interest inthe Refinery, such conveyance shall not release the Permittee from any obligationimposed SIP Conditions, unless the party to whom the right, title or interest hasbeen transferred or assigned agrees in writing to fulfill the obligations of this Permitand the MPCA finds that the new owner has the ability to fulfill the obligations ofthis Permit, and approves such transfer or assignment.(continued below)


(continued from above)F. The SIP mandates actions and establishes limits necessary to attain, maintainand verify compliance with the federal sulfur dioxide NAAQS by FHR. To the extentthat any federal or state statute, rule, permit, order, stipulation agreement, consentdecree or schedule of compliance now in force or subsequently issued imposeslimits and requires actions additional to or more stringent than those required in thePermit, FHR shall also comply with the requirements of the federal or state statute,rule, permit, order, stipulation agreement, consent decree or schedule ofcompliance.

G. Once US EPA approves this Permit as part of the Minnesota SIP, this Permitshall supersedes the requirements of all previous SIP revisions, as they apply toFHR.


SOURCE-SPECIFIC REQUIREMENTS hdr

Permit Appendices: This permit contains appendices as listed in the permit Table ofContents. The Permittee shall comply with all requirements contained in theappendices.

Notwithstanding the previous paragraph, SO2 modeling parameters in Appendix Care included in the appendices for reference only and compliance with theseparameters is achieved through meeting the above SIP requirements listed insubject item "Total Facility" of this permit.

Notwithstanding the previous paragraph, PM10 modeling parameters in Appendix Eare included in the appendices for reference only.

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

List of Insignificant Activities Required to be Listed: Appendix B includes activitiesand sources at the facility that have been determined to be insignificant activitiesunder Minn. R. 7007.1300. This list is subject to change.

Minn. R. 7007.0800, subp. 2; Minn. R. 7007.1300

Recordkeeping for Non-Contact Cooling Water: Maintain plans and specificationsshowing non-contact cooling water does not contact hydrocarbons or oily water andis not recirculated through a cooling tower if excluding cooling water system from40 CFR pt. 60, subp. QQQ requirements.

40 CFR Section 60.692-1(d)(2-4); Minn. R. 7011.1435.C

Fuel Restriction: The Permittee shall not combust refinery fuel oil in any processheater or boiler located at the refinery.

Title I Condition: To avoid classification as a majormodification under 40 CFR Section 52.21 & Minn. R.7007.3000


03700011 - 010

Facility Name:

Permit Number:

09/09/13A-9

Storage Tank Recordkeeping: The Permittee shall record all the tank groups andidentify all the tanks associated with that group. The Permittee is allowed to moveexisting tanks into any effective identified groups in this Title V permit and maintaina record of the change. The Permittee shall apply for the appropriate permit if thePermittee wants to install and operate a new tank.

Minn. R. 7007.0800, subp. 5

MINNESOTA AMBIENT AIR QUALITY STANDARD (MAAQS) REQUIREMENTSFOR HYDROGEN SULFIDE (H2S)

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MAAQS Compliance: by June 1, 2014, the Permittee shall complete engineeringstudy for steam-air heater decoking and coker drum depressurization ventmitigation mesaures. This is a state only requirement and is not enforceable by theEPA Administrator or citizens under the Clean Air Act.

Minn. Stat. Sec. 116.07, subds. 4a and 9; Minn. R.7007.0100, subps. 7A, 7L and 7M; Minn. R.7007.0800, subps. 1, 2, and 4; Minn. R.7009.0010-7009.0080

MAAQS Compliance: The Permittee shall maintain or support ambient air H2S orTRS monitoring near the facility to demonstrate compliance with the H2S MAAQS.Investigate and report any potential deviations from the H2S standard along withany needed changes to the H2S Management plan in the quarterly report that isdue 3 months after receipt of qualified data. If the Permittee elects to discontinueambient air monitoring for H2S, the Permittee shall submit a dispersiion model thatdemonstrates complaince with the MAAQS. This is a state only requirement and isnot enforceable by the EPA Administrator or citizens under the Clean Air Act.


MAAQS Compliance: As soon as possible following good project managementguidelines to ensure safe and reliable operation but no later than December 31,2015, contingent upon timely receipt of any required environmental permits or SIPorders, the Permittee shall complete construction and commence operation ofmeasures to mitigate the potential H2S impacts to the ambient air of steam-airdecoking of coker heaters and coker drum depressurization vents. This is a stateonly requirement and is not enforceable by the EPA Administrator or citizens underthe Clean Air Act.


MAAQS Compliance: No later than 9 months following completion of coker H2Smitigation measures, the Permittee shall submit to the MPCA a final report thatsummarizes the actions taken to mitigate coker H2S sources and provides a reviewof the pre and post project ambient monitoring results. This is a state onlyrequirement and is not enforceable by the EPA Administrator or citizens under theClean Air Act.


OPERATIONAL REQUIREMENTS hdr

The Permittee shall comply with National Primary and Secondary Ambient AirQuality Standards, 40 CFR pt. 50, and the Minnesota Ambient Air QualityStandards, Minn. R. 7009.0010 to 7009.0080. Compliance shall be demonstratedupon written request by the MPCA.

40 CFR pt. 50; Minn. Stat. Sec. 116.07, subds. 4a and9; Minn. R. 7007.0100, subps. 7A, 7L and 7M; Minn. R.7007.0800, subps. 1, 2, and 4; Minn. R.7009.0010-7009.0080

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, unlessotherwise noted in this permit.

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.

The O & M plan may be maintained electronically as part of a task and proceduremanagement system. O & M plans developed pursuant to MACT requirementssatisfy this requirement for those units.

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


03700011 - 010

Facility Name:

Permit Number:

09/09/13A-10

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)

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

Minn. R. 7007.0800, subp. 16

Malfunction: Any sudden, infrequent, and not reasonably preventable failure of airpollution control equipment, process equipment, or a process to operate in anormal or usual manner. Failures that are caused in part by poor maintenance orcareless operation are not malfunctions.

40 CFR Section 60.2

Operation requirement for NSPS Sources: at all times, including periods of startup,shutdown, and malfunction, owners shall maintain and operate any affected facilityin a manner consistent with good air pollution control practice for minimizingemissions. Determination of whether acceptable operating and maintenanceprocedures are being used will be based on information, which may include, but isnot limited to, monitoring results, opacity observations, review of operating andmaintenance procedures, and inspection of the source.

40 CFR Section 60.11(d)

Operation requirement for NESHAP FF Sources: at all times, including startup,shutdown, and malfunction, maintain and operate the source, including associatedequipment for air pollution control, in a manner consistent with good air pollutioncontrol practice for minimizing emissions. Determination of whether acceptableoperating and maintenance procedures are being used will be based on informationavailable to the Administrator which may include, but is not limited to, monitoringresults, review of operating and maintenance procedures, and inspection of thesource.

40 CFR Section 61.12(c)

Air Pollution Control Equipment: The following control equipment downtime of CE004, CE 005, CE 012, CE 019, CE 068, CE 015, CE 035, CE 036, CE 037, CE 038,CE 039, CE 040, CE 041, CE 042, CE 043, CE 044, CE 045 and CE 055 is notitself a deviation during downtime if the applicable permit limit requirement is met.The Permittee shall keep a record of the duration of downtime.

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

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 Tables A and B of the permit. See TableB 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 alternative formatas allowed by Minn. R. 7017.2018.

Minn. Rs. 7017.2030, subp. 1-4,7017.2018 and Minn. R.7017.2035, subp. 1-2

Limits set as a result of a performance test (conducted before or after permitissuance) apply until superseded as specified by Minn. R. 7017.2025 followingwritten approval of a subsequent performance test on the same unit.

Minn. R. 7017.2025

Opacity Performance Testing: As provided in Minn. R. 7017.2020, subp. 2, thePermittee may conduct performance testing required by this permit as included inan approved performance test plan. The Permittee shall be certified in Method 9.The number of tests shall be determined by the Permittee and MPCA.

Minn. R. ch. 7017

Visible Emission Monitoring: The Permittee shall submit to the MPCA a 30-daynotification if the Permittee has to perform a Method 9 test based on periodic visibleemission monitoring unless more immediate testing is required by this permit. TheMethod 9 test shall be conducted for a minimum of 1-hour.

Minn. R. 7007.0800, subp. 6

MONITORING REQUIREMENTS hdr


03700011 - 010

Facility Name:

Permit Number:

09/09/13A-11

The Permittee is authorized to install a CEM on any emission unit subject to thispermit, and, once certified, utilize that CEM to demonstrate compliance with anyapplicable limit. Once the CEM is installed and certified, any duty limits establishedpursuant to stack tests utilized to demonstrate compliance with a relevant limit shallno longer apply. For any such CEM, the Permittee shall follow the CEMrequirements at Minn. Rs. 7017.1010, 7017.1090 and 7017.1160, and shall submitan administrative permit amendment to incorporate such requirements for theparticular emission unit where the CEM is being utilized.

Minn. R. 7017.1006

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 for a period of five (5)years from the date of monitoring, sample, measurement, or report. Records whichmust be retained at this location include all calibration and maintenance records, alloriginal recordings for continuous monitoring instrumentation, and copies of allreports required by the permit. Records must conform to the requirements listed inMinn. R. 7007.0800, subp. 5(A).

The records may be maintained in either electronic or paper format, unless it isexpressly prohibited.

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

When the Permittee determines that no permit amendment or notification isrequired prior to making a change, the Permittee must retain records of allcalculations required under Minn. R. 7007.1200. For expiring permits, theserecords shall be kept for a period of five years from the date the change was madeor until permit reissuance, whichever is longer. For nonexpiring permits, theserecords shall be kept for a period of five years from the date that the change wasmade. The records shall be kept at the stationary source for the current calendaryear of operation and may be kept at the stationary source or office of thestationary source for all other years. The records may be maintained in eitherelectronic or paper format.

Minn. R. 7007.1200, subp. 4

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.

The records may be maintained in either electronic or paper format, unless it isexpressly prohibited.

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

REPORTING/SUBMITTALS hdr

Excess Emissions/Downtime Reports (EERs): due 30 days after end of eachcalendar quarter following Initial Startup of the Monitor. (Submit DeviationsReporting Form DRF-1, as amended). The EER shall indicate all periods ofmonitor bypass and all periods of exceedances of a limit including exceedancesallowed by an applicable standard, i.e. during start-up, shutdown, and malfunctions.The EER must be submitted even if there were no excess emissions, downtime orbypasses during the quarter (where applicable).

Minn. R. 7017.1110, subps. 1 and 2

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


03700011 - 010

Facility Name:

Permit Number:

09/09/13A-12

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 thebreakdown is 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. Rs. 7007.1150 to7007.1500. Submittal dates vary, depending on the type of amendment needed.

Minn. R. 7007.1150 through Minn. R. 7007.1500

Extension Requests: The Permittee may apply for an Administrative Amendmentextend a deadline in a permit by no more than 120 days, provided that the agencymay only extend a deadline established by an applicable requirement described inMinn. R. 7007.0100, subp. 7, items A to K, if the agency has been delegatedauthority to make such extensions by the administrator. Notwithstanding theprevious sentence, the agency may do an administrative amendment to extend atesting deadline in a permit up to 365 days if the agency finds that the extension isneeded to allow the permittee to test at worst case conditions as required by Minn.R. 7017.2025, subp. 2.

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

Emission Inventory Report: due on or before April 1 of each calendar year followingpermit issuance. Submit the report on a form approved by the Commissioner.

Minn. R. 7019.3000 through Minn. R. 7019.3100

Permits: All prior Air Quality Emission Permits are rescinded and replaced by theTitle V permit upon issuance.

Minn. R. 7007.1800 A(1) through (2)

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

Risk Management Plan: The Permittee is required to submit a Risk ManagementPlan (RMP) under the federal rule, 40 CFR pt. 68. Each owner or operator of astationary source, at which a regulated substance is present above a thresholdquantity in a process, shall design and implement an accidental release preventionprogram. An initial RMP must be submitted no later than the latest of the followingdates: (1) June 21, 1999; (2) Three years after the date on which a regulatedsubstance is first listed under 40 CFR Section 68.130; or (3) The date on which aregulated substance is first present above a threshold quantity in a process. A fullupdate and resubmission of the RMP is required at least once every five years. Thefive-year anniversary date is reset whenever your facility fully updates andresubmits their RMP.

Risk Management Plan: 40 CFR pt. 68

NATIONAL EMISSION STANDARDS FOR HAZARDOUS AIR POLLUTANTSUNDER PART 63

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The Permittee shall comply with the requirements of National Emission Standardsfor Hazardous Air Pollutants for Industrial, Commercial, and Institutional Boilersand Process Heaters, 40 CFR pt. 63, subp. DDDDD, if applicable, as specifiedunder 40 CFR Section 63.7490, by the applicable deadlines as specified under 40CFR Section 63.7495. Compliance date for existing sources is January 31, 2016 oras subsequently modified by applicable regulatory amendment or judicial order.

40 CFR pt. 63, subp. DDDDD


03700011 - 010

Facility Name:

Permit Number:

09/09/13A-13

Equipment subject to National Emission Standards for Hazardous Air Pollutants forSite Remediation, 40 CFR pt. 63, subp. GGGGG following 40 CFR pt. 61, subp. FFfor compliance is required to follow the general provisions of 40 CFR pt. 61, subp.A, not 40 CFR pt. 63, subp. A. Such equipment is therefore exempt from Startup,Shutdown and Malfunction plans and related documentation and reportingrequirements. ( See 10/31/2006 email from Mr. Greg Nizich USEPA referenced inMACT GGGGG NOCS report dated 11/3/2006.)

40 CFR pt. 63, subp. GGGGG

When transferring remediation material off-site you must transfer to a facility thatmeets the requirements in 40 CFR Section 63.7936(b).

40 CFR Section 63.7936 (a) and (b)

Each shipment of remediation material that is being transferred off-site mustinclude a notice with each shipment that states the remediation material containsorganic HAP that are to be treated according to the provisions of this subpart.Receiving facility must have submitted to the EPA a written certification that thefacility will manage remediation material according to the requirements of 40 CFRSections 63.7885 through 63.7957.

40 CFR Section 63.7936 (b)(3)

For changes that do not require a permit amendment but are subject to section112(j) of the Clean Air Act:

1. The Permittee shall submit a Part 1 MACT application within 30 days of startupof any 112(j) affected source. The application shall meet the requirements of 40CFR Section 63.53(a).2. The Permittee shall submit a Part 2 MACT application within 90 days of startupof any 112(j) affected source. The application shall meet the requirements of 40CFR Section 63.53(b).

The definition of a 112(j) affected source is found at 40 CFR Section 63.51. As ofpermit issuance, 112(j) affected sources include the following:

a. brick and structural clay products manufacturing; andb. clay ceramics manufacturing.

40 CFR Section 63.52(b)(1) and 63.52(e)(1)

NATIONAL EMISSION STANDARDS FOR HAZARDOUS AIR POLLUTANTSUNDER PART 61

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Benzene Waste Streams: The Permittee shall control benzene waste streams per40 CFR pt. 61, subp. FF standards and install, operate, and maintain a treatmentprocess to remove or destroy benzene to less than 10 ppmw.

40 CFR Section 61.342(c); 40 CFR Section61.348(b)(1); 40 CFR Section 63.655(a); Minn. R.7011.9930(E)

The Permittee must determine flow-weighted annual average benzeneconcentration in the stream by collecting samples and analyzing waste streams orutilizing knowledge of the waste per 40 CFR Section 61.355(c).

40 CFR Section 61.355(c); 40 CFR Section 61.356(b);Minn. R. 7011.9930(E)

Records: The Permittee shall maintain records for NESHAP, Subpart FFequipment.

40 CFR Section 61.342(g); 40 CFR Section 61.356;Minn. R. 7011.9930(E)

Under 40 CFR pt. 61, subp. FF, the affected source is the entire facility. ThePermittee may modify equipment within the facility and add/remove/modify controlequipment without additional prior approval consistent with 40 CFR pt. 61, subp.FF. Note, Subpart FF does not require that all benzene waste streams becontrolled as long as they are accounted for properly under the rule.

40 CFR Section 61.05; 40 CFR Section 61.15

NESHAP, Subpart FF Quarterly Reports: The Permittee shall prepare and submitquarterly NESHAP inspection and certification report due 30 days after end of eachcalendar quarter.

40 CFR Section 61.357; 40 CFR Section 63.655; Minn.R. 7011.7280; Minn. R. 7011.9930(E)

NESHAP, Subpart FF Annual Corrective Report- due by April 7th of each year. 40 CFR Section 61.357(d)(8); Minn. R 7011.7280;Minn. R. 7011.9930(E)

Notification: The Permittee shall notify the Administrator within 30 days of achange in the information submitted in the initial notification of applicability of 40CFR pt. 61, subp. FF if change would affect determination of applicability.

40 CFR Section 61.10(a) to 61.10(d)

The owner or operator shall notify the Administrator of intent to conduct a requiredperformance test at least 30 days before the performance test is scheduled.


A final determination to deny any request for a waiver will be in writing and will setforth the specific grounds on which the denial is based. The final determination willbe made within 60 days after presentation of additional information or argument; orwithin 60 days after the final date specified for the presentation if no presentation ismade.

40 CFR Section 60.11(e)(6); 40 CFR Section60.11(e)(7); 40 CFR Section 60.11(e)(8); 40 CFRSection 60.4(a); 40 CFR Section 60.4(b)(Y)

Unless otherwise specified in an applicable subpart, samples shall be analyzed andemissions determined within 30 days after each emission test has been completed.The owner or operator shall report the determinations of the emission test to theAdministrator by a registered letter sent before the close of business on the 31stday following the completion of the emission test.

40 CFR Section 61.13(f)


03700011 - 010

Facility Name:

Permit Number:

09/09/13A-14

Leaks into Cooling Towers: The Permittee shall follow the requirements set forth inParagraphs 69 (b) and 74 (e) of the Consent Decree between FHR, EPA andMPCA (United States and State of Minnesota v. Koch Petroleum Group, L.P. (nowFlint Hills Resources LP), Civil Action No. 00-2756, United States District Court forthe District of Minnesota), as amended and as applicable to the Pine Bend refinery,for addressing any benzene associated with leaks of process fluids into coolingtower systems for the purpose of compliance with the Benzene Waste NESHAP.Consequently, the point of waste generation under 40 CFR Section 61.341 of anycooling tower subject to these requirements shall be the point where the water isblown down to a sewer drain or other wastewater conveyance. See Appendix D.

40 CFR pt. 61, subp. FF

DETERMINING IF A PROJECT/MODIFICATION IS SUBJECT TO NEW SOURCEREVIEW (NSR)

hdr

These requirements apply if a reasonable possibility (RP) as defined in 40 CFRSection 52.21(r)(6)(vi) exists that a proposed project, analyzed using theactual-to-projected-actual (ATPA) test (either by itself or as part of the hybrid test atSection 52.21(a)(2)(iv)(f)) and found to not be part of a major modification, mayresult in a significant emissions increase (SEI). If the ATPA test is not used for theproject, or if there is no RP that the proposed project could result in a SEI, theserequirements do not apply to that project. The Permittee is only subject to thePreconstruction Documentation requirement for a project where a RP occurs onlywithin the meaning of Section 52.2(r)(6)(vi)(a).

Even though a particular modification is not subject to NSR, or where there isn't aRP that a proposed project could result in a SEI, a permit amendment,recordkeeping, or notification may still be required by Minn. R. 7007.1150 -7007.1500.

Title I Condition: 40 CFR Section 52.21(r)(6); Minn. R.7007.3000; Minn. R. 7007.0800, subp. 2

Preconstruction Documentation -- Before beginning actual construction on aproject, the Permittee shall document the following information:

1. A description of the project2. Identification of the emission unit(s) whose emissions of an NSR pollutant couldbe affected3. The potential emissions of any existing or new emission units affected by theproject.4. A description of the applicability test used to determine that the project is not amajor modification for any regulated NSR pollutant, including the baseline actualemissions, the projected actual emissions, the amount of emissions excluded dueto increases not associated with the modification and that the unit(s) could haveaccommodated during the baseline period, an explanation of why the amountswere excluded, and any creditable contemporaneous increases and decreases thatwere considered in the determination.

The Permittee shall maintain records of this documentation.

Title I Condition: 40 CFR Section 52.21(r)(6); Minn. R.7007.3000; Minn. R. 7007.0800, subps. 4 & 5

The Permittee shall monitor the actual emissions of any regulated NSR pollutantthat could increase as a result of the project and that were analyzed using theATPA test, and the potential emissions of any regulated NSR pollutant that couldincrease as a result of the project and that were analyzed using potential emissionsin the hybrid test. The Permittee shall calculate and maintain a record of the sumof the actual and potential (if the hybrid test was used in the analysis) emissions ofthe regulated pollutant, in tons per year on a calendar year basis, for a period of 5years following resumption of regular operations after the change, or for a period of10 years following resumption of regular operations after the change if the projectincreases the design capacity of or potential to emit of any unit associated with theproject.


The Permittee must submit a report to the Agency if the annual summed (actual,plus potential if used in hybrid test) emissions differ from the preconstructionprojection and exceed the baseline actual emissions by a significant amount aslisted at 40 CFR Section 52.21(b)(23). Such report shall be submitted to theAgency within 60 days after the end of the year in which the exceedances occur.The report shall contain:

a. The name and ID number of the facility, and the name and telephone number ofthe facility contact personb. The annual emissions (actual, plus potential if any part of the project wasanalyzed using the hybrid test) for each pollutant for which the preconstructionprojection and significant emissions increase are exceeded.c. Any other information, such as an explanation as to why the summed emissionsdiffer from the preconstruction projection.



03700011 - 010

Facility Name:

Permit Number:

09/09/13A-15

Subject Item: GP 002 Cooling Towers (#1, #3, #4, #5, #6 and #7) and associated Heat Exchange Systems

Associated Items: EU 268 No 1 Cooling Tower

EU 269 No 3 Cooling Tower





What to do Why to do itEMISSION LIMITS hdr

Total Particulate Matter: less than or equal to 5.5 tons/year using 365-day RollingSum for EU 269.

Title I Condition: To avoid classification as majorsource and modification under 40 CFR Section 52.21& Minn. R. 7007.3000

PM < 10 micron: less than or equal to 2.4 tons/year using 365-day Rolling Sum forEU 269.


Total Particulate Matter: less than or equal to 4.3 tons/year using 365-day RollingSum for EU 270. This limit becomes effective upon startup of EU 296.


PM < 10 micron: less than or equal to 1.9 tons/year using 365-day Rolling Sum forEU 270. This limit becomes effective upon startup of EU 296.










Volatile Organic Compounds: less than or equal to 11.96 tons/year using 365-dayRolling Sum for EU 272, if modified as part of the #3 Crude/Coker Improvementspermit. This limit is effective upon startup of EU 272 following modifications madeas part of the #3 Crude/Coker Improvements permit.

Minn. R. 7007.0800, subp. 2

Volatile Organic Compounds: less than or equal to 7.36 tons/year using 365-dayRolling Sum for EU 354, upon startup.

Minn. R. 7007.0800, subp. 2

RECORDKEEPING AND REPORTING REQUIREMENTS hdr

PM and PM10 Emission Calculations: For EU268, EU269, EU270, EU271 andEU272, the Permittee shall use the following to calculate PM and PM10 emissions,unless an alternative calculation method is proposed by the Permittee andapproved by the MPCA in accordance with Minn. R. 7019.3100:

PM Emissions (tons/day) = [PRR x D x TDS x 60 min/hr x 8.3 lb/gal x (1 part/1,000,000 parts) x (24 hr/day)]/ (2000 lb/ton)where

PRR = Average daily pump recirculation rate (gallons/minute)D = Drift specification in percent drift (maximum of 0.001%)TDS = Total dissolved solids concentration in cooling water in parts per million

PM10 Emissions (tons/day) = PM Emissions (tons/day) x 0.47


PM and PM10 Recordkeeping: For EU 268, EU 269, EU 270, EU 271 and EU 272,the Permittee shall calculate and record the daily and 365-day rolling sumPM/PM10 emissions from each cooling tower. The records may be maintained ineither electronic or paper format, unless electronic or paper records are expresslyprohibited.


For heat exchange systems submit Periodic Reports that include the informationfound in 40 CFR Section 63.655(g)(9)(i) through (vi).

40 CFR Section 63.655(g)(9); Minn. R. 7011.7280(A)


03700011 - 010

Facility Name:

Permit Number:

09/09/13A-16

The owner operator of a heat exchange system shall comply with recordkeepingrequirements of paragraphs (i)(4)(i) through (vi) of 40 CFR Section 63.655.

40 CFR Section 63.655; Minn. R. 7011.7280(A)

The Permittee shall determine compliance with the VOC limits for EU272 andEU354 if actual emissions, as calculated using the "Air Stripping Method (ModifiedEl Paso Method) for Determination of Volatile Organic Compound Emissions fromWater Sources (January 2003)", and calculation basis from MACT CC and length oftime to repair from the time of sampling, are at or below these limits. Specifically,FHR shall apply the emission rate (calculated from the sampling results and coolingtower recirculation rate) from the time sampled until the next sample that changesthe Modified El Paso based emission rate. Samples shall be taken at least monthly,but may be taken more frequently at the discretion of FHR.

Minn. R. 7007.0800, subps. 2 and 4

Recordkeeping: The Permittee shall calculate and record the daily and 365-dayRolling Sum of VOC emissions at EU272 and EU354 by the 28th day of eachmonth for the 365-day Rolling Sum periods ending on the last day of the precedingmonth. These records shall be maintained for at least five (5) years. Thisrequirement is effective for EU272 upon startup following the modifications madeas part of the #3 Crude/Coker Improvements permit and for EU354 upon startup.

Minn. R. 7007.0800, subp. 5

Reporting: The Permittee shall report, in its Quarterly Air Quality and ExcessEmissions Report, the rolling 365-day average of VOC emissions at EU272 andEU354, for each day in the reporting period. This requirement is effective for EU272upon startup following modifications made as part of the #3 Crude/CokerImprovements permit and for EU354 upon startup.

Minn. R. 7007.0800, subp. 6

OTHER REQUIREMENTS hdr

The Permittee shall analyze cooling tower water for chromium if requested by theAdministrator or the MPCA.

40 CFR Section 63.404; Minn. R. 7011.7160

The Permittee shall retain copy of Initial Notification and Notification of Compliancestatus on-site for a minimum of 5 years.

40 CFR Section 63.10; 40 CFR Section 63.405; 40CFR Section 63.406; 40 CFR Section 63.9; Minn. R.7011.7160; Minn. R. 7011.7280

Perform monthly monitoring to identify leaks of total strippable volatile organiccompound (VOC) from each heat exchange system subject to the requirements of40 CFR Section 63.654 according to the procedures in 63.654 (c)(1) and (2).


If a leak is detected, the owner or operator must repair the leak to reduce themeasured concentration to below the applicable action level as soon aspracticable, but no later than 45 days after identifying the leak, except as specifiedin 40 CFR Section 63.645 (e) and (f). Alternatively the leaking exchanger may beisolated, bypassed, or otherwise removed from service until it is otherwise repaired.

40 CFR Section 63.654(d), (d)(1)-(5)

If a leak is detected when monitoring a cooling tower return line, additionalmonitoring may be conducted to identify leaks of total strippable VOC emissionsusing Modified El Paso Method from each heat exchanger or group of heatexchangers in organic HAP service associated with the heat exchange system forwhich the leak was detected. If the additional monitoring shows that the totalstrippable VOC concentration in the stripped air at the heat exchanger exit line foreach heat exchanger in organic HAP service is less than 6.2 ppmv for existingsources or less than 3.1 ppmv for new sources, the heat exchange system isexcluded from repair requirements.

40 CFR Section 63.654(e)

Delay of Repair: a leaking heat exchanger may be placed on delay of repair within45 days of leak identification if the repair is technically infeasible without ashutdown and the total strippable VOC concentration (as methane) is initially andremains less than 62 ppmv for all monthly monitoring periods during the delay ofrepair. Repair must be conducted during the next scheduled shutdown of the heatexchange system and within 30 days of the monitoring event in which the leak was62 ppmv or greater total strippable VOC (as methane).

40 CFR Section 63.654(f)(1)

Delay of Repair: a leaking heat exchanger may be placed on delay of repair within45 days of leak identification if the necessary equipment, parts, or personnel arenot available and the total strippable VOC concentration (as methane) is initiallyand remains less than 62 ppmv for all monthly monitoring periods during the delayof repair. Repair must occur within 120 calendar days of being placed on Delay ofRepair and within 30 days of a monitoring event in which the leak was 62 ppmv orgreater total strippable VOC (as methane).

40 CFR Section 63.654(f)(1)

For heat exchange systems placed on Delay of Repair: Record: the reasons fordelaying repair, a schedule for completing the repair as soon as practical, the date

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Air Emission Permit No. 03700011-010 Is Issued to Flint Hills ......21 GP 037 IFR tank/basin subject...

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