AIR EMISSION PERMIT NO. 03700011-006 Major ......25 GP 037 NSPS IFR Tank/Basin subject to NESHAPs FF...

TDD (for hearing and speech impaired only): (651) 282-5332 Printed on recycled paper containing at least 10% fibers from paper recycled by consumers

AIR EMISSION PERMIT NO. 03700011-006 Major Amendment

IS ISSUED TO

Flint Hills Resources LP

FLINT HILLS RESOURCES LP - PINE BEND REFINERY

12555 Clark Road Rosemount, Dakota County, MN 55068

The emission units, control equipment and emission stacks at the stationary source authorized in this permit amendment are as described in the Permit Applications Table.

This permit amendment supersedes Air Emission Permit No. 03700011-005 and authorizes the Permittee to operate and construct the stationary source at the address listed above unless otherwise noted in Table A. The Permittee must comply with all the conditions of the permit. Any changes or modifications to the stationary source must be performed in compliance with Minn. R. 7007.1150 to 7007.1500, and any additions or changes to conditions incorporated into Minnesota’s State Implementation Plan (SIP) under 40 CFR Section 52.1220, designated “Title I: SIP for Sulfur Dioxide (SO2)” must go through the federal SIP approval process before becoming effective. Terms used in the permit are as defined in the state air pollution control rules unless the term is explicitly defined in the permit.

Unless otherwise indicated, all the Minnesota rules cited as the origin of the permit terms are incorporated into the SIP under 40 CFR Section 52.1220 and as such as are enforceable by U.S. Environmental Protection Agency (EPA) Administrator or citizens under the Clean Air Act.

Permit Type: Federal; Pt 70/Incorporates Existing NSR Conditions; Title I SIP Conditions SO2 Operating Permit Issue Date: October 31, 2005 Major Amendment Issue Date: January 21, 2009 Expiration Date: October 31, 2010 – Title I Conditions do not expire. Each new or revised condition designated “Title I Condition: SIP for SO2” is not effective or enforceable until approved by EPA as a SIP revision under Title I of the Clean Air Act. Don Smith, P.E., Manager Air Quality Permits Section Industrial Division for Paul Eger Temporary Commissioner Minnesota Pollution Control Agency

Permit and Amendment History

Permit Type Application Date Issuance Date Permit No. 02/17/1995 (original) Total Facility Operating

Permit 11/19/2002 (revised) 10/31/2005 03700011-001

10/11/2005 (original) Major Amendment 05/09/2006 (revised)

Minor Amendment 09/28/2005 Administrative Amendment 03/27/2006

07/13/2006 03700011-002

Major Amendment 05/09/2006 11/07/2006 03700011-003 08/18/2006 (original) Major Amendment 05/01/2007 (revised)

Administrative Amendment 09/29/2006 Administrative Amendment 12/22/2006

10/18/2007 03700011-004

Administrative Amendment 04/17/2007

Major Amendment 12/10/2007 08/19/2008 03700011-005

Major Amendment Major Amendment Minor Amendment Major Amendment

Administrative Amendment

03/18/2008 05/21/2008 06/13/2008 07/24/2008 10/06/2008

See Cover 03700011-006

TABLE OF CONTENTS Notice to the Permittee

Permit Shield

Facility Description

Permit Action 002 Description





Table A: Limits and Other Requirements

1 Total Facility A-12 GP 001 Boiler Nos 1, 2, 3, and 4 A-73 GP 002 Cooling Towers (3, 4, 5, and 6) A-84 GP 003 ULSD Project CO Emissions A-95 GP 004 ULSD Project VOC Emissions A-106 GP 007 Tanks subject to NSPS UU (each tank) A-117 GP 008 External Floating Tanks NSPS Kb > 39,890 gallons A-128 GP 009 Tanks subject to VOC Limit (CFP) A-139 GP 010 Tanks/Basins subject to NESHAP FF w/vapor recovery & control device A-15

10 GP 011 Diesel Engines with SIP Conditions and < 833 hr/mon A-1711 GP 012 Portable Diesel Engines NonExempt A-1812 GP 014 Portable Diesel Engines which are Exempt A-1913 GP 015 FCC Spent Catalyst Transfers A-2014 GP 017 Loading Rack Activities in CFP group limit A-2115 GP 019 External Floating Tanks NSPS Kb > 39, 890 (075-111 psi) A-2216 GP 023 NSPS K Tanks w/fixed roof > 40,000 gals without CVS/CD A-2617 GP 024 NSPS Ka Tanks w/fixed roof > 40, 000 gals A-2718 GP 025 NSPS Kb Tanks w/fixed roof > 39,389 gals A-2819 GP 026 NSPS Kb Tanks w/fixed roof & CVS/CD 19,813-39,890 gals (vp > 40 psi) A-3020 GP 027 NSPS Kb w/fixed roof between 19,813 and 39,389 gals A-3321 GP 032 NSPS K Tanks w/fixed roof & CVS/CD & 40,000 gals A-3422 GP 033 NSPS Kb Tanks w/fixed roof and CVS/CD & > 39,890 gals A-3523 GP 034 NSPS Kb Tanks w/fixed roof & CVS/CD > 39,890 and tvp > 075 A-3624 GP 035 NSPS Kb Tanks w/fixed roof & CVS/CD & > 19,813 and < 39,890 gals A-3925 GP 037 NSPS IFR Tank/Basin subject to NESHAPs FF following the req of Kb A-4026 GP 038 NSPS Kb Tanks w/internal floating roof > 39,890 gallons A-4127 GP 039 NSPS Kb tanks w/internal floating > 39,890 gals & tvp (075-111 psia) A-4228 GP 042 MACT CC Requirements, satisfied by NSPS Kb A-4629 GP 043 MACT CC Group 2 Tanks (not subject to NSPS Ka or Kb) A-48

30 GP 044 Tanks MN R 1969-73 and > 65, 000 gals A-4931 GP 045 Tanks MN R 1969-73 and 2,000- 65,000 gals A-5032 GP 046 Tanks MN R post 1973 and > 40,000 gals A-5133 GP 047 Tanks MN R post 1973 and 2,000 – 40,000 gals A-5334 GP 052 Tanks NSPS QQQ A-5535 GP 053 EFR tank/basin subject to NESHAPs FF following the req of Kb A-5636 GP 054 Storage Tank Heaters built before June 11, 1973 A-5737 GP 055 Emission Units subject to Minn R built before June 11, 1973 A-5838 GP 056 Storage Tank Heaters built after June 11, 1973 A-5939 GP 057 Emission Units subject to Minn R built after June 11, 1973 A-6040 GP 058 Equipment subject to both NESH FF controls and NSPS QQQ A-6141 GP 059 Containers subject to NESH FF; w/vac trucks to haul NESH FF waste A-6242 GP 060 Oil/water separators w/floating roof subject to NSPS QQQ A-6443 GP 061 Oil/water separators w/fixed roof subject to NSPS QQQ A-6644 GP 062 Oil/water sep subject to NESH FF w/CVS & control device; no dilution air

opening A-6745 GP 063 Oil/water sep w/closed vent sys and control device subject to NSPS QQQ A-6946 GP 065 Treatment Processes to meet destruction req NESH FF A-7047 GP 066 VOC Emissions from WWTP A-7048 GP 067 All equipment included in individual drain system, including drains and

junction boxes subject to NESHAPs FF A-7349 GP 068 Type I Drains receiving NESH FF Wastewater and equipped with plugs A-7550 GP 069 Type II Drains subject to NESH FF and also subject to NSPS QQQ A-7651 GP 071 Type I Drains subject to NSPS QQQ (sealed w/plug) A-7852 GP 072 Type II Drains subject to NSPS QQQ active (water seal) A-7953 GP 075 Type II Drains subject to NSPS inactive (water seal) A-8054 GP 076 Junction Boxes subject to NESH FF when equipped with carbon canisters A-8155 GP 077 Junction Boxes receiving Wastewater from NSPS QQQ units not subject to

NESHAPs FF A-8356 GP 079 Non-contact Cooling Water Drains A-8457 GP 080 Stormwater Sewers A-8558 GP 081 Fugitive Compressors Exempt from LDAR Requirements A-8659 GP 082 Fugitive Compressors LDAR Requirements A-8760 GP 087 Fugitive LDAR ALL Equipment in VOC or HAP Service A-8861 GP 088 Fugitive LDAR in Vacuum Service A-9262 GP 089 Fugitive LDAR Emission Sources not in VOC or HAP Service A-9363 GP 090 Fugitive LDAR Equipment Designated Non-detectable emissions (NDE) A-9464 GP 091 Fugitive LDAR Open-ended Lines A-9665 GP 093 Fugitive LDAR PSV to Atmosphere A-9866 GP 094 Fugitive LDAR PSV with Upstream Rupture Disks A-10067 GP 095 Fugitive LDAR Pumps in Heavy Liquid Service A-10168 GP 096 Fugitive LDAR Light Liquid Pumps A-10369 GP 099 Fugitive LDAR Sample Stations A-10570 GP 100 Fugitive LDAR Heavy Liquid Valves A-10771 GP 101 Fugitive LDAR Valves in Light Liquid Service A-10972 GP 102 Units where carbon canisters may be used to meet NESHAP FF Req A-11373 GP 104 Refinery Emergency Flares and Flare System (for Consent Decree Flare

Policy) A-11674 GP 106 Control Equipment Used to Meet Requirements of MACT CC A-11975 GP 108 Control Device Required by NESH FF; Doesn’t include CVS or CC or

Refinery Flares A-120

76 GP 109 Closed Vent System for NESH FF Equipment A-12377 GP 111 Fuel Gas Supply Systems A-12678 GP 112 Sulfur Recovery Units A-12879 GP 113 NSPS Kb tanks with fixed roof subject to NESHAP FF following the

requirements of Kb A-13080 GP 114 Fugitive LDAR Connectors; Misc All FS Numbers are included in this group A-13181 GP 115 Sulfur Degassing System A-13282 GP 116 Refinery Fuel Gas SO2 Emissions A-13383 SV 042 26H21 Stack A-13484 SV 066 32H5 6 7 Stack A-13785 SV 082 37H1 2 6 Stack A-13986 SV 083 37H3 4 5 Stack A-14087 SV 093 45H61 Stack A-14388 SV 095 Common Boilerhouse Stack A-14689 SV 165 New Hydrocracker Feed Heater and Reboiler A-14790 EU 004 New Truck Bottom Loading (gas, distillate) A-14891 EU 005 #1 Crude Heater Atmospheric Distillation A-14992 EU 006 # 1 Crude Heater Crude Preflash A-15093 EU 016 Vacuum Pre-Strip Heater A-15194 EU 019 #2 Vac Heater A-15395 EU 026 #1 Vac Heater A-15596 EU 028 #1 Coker Heater A-15797 EU 030 #2 Coker Heater A-15998 EU 032 Steam/Air Heater Decoking 21H-1 A-16199 EU 033 Steam/Air Heater Decoking 21H-2 A-162

100 EU 034 #3 Coker Heater A-163101 EU 035 #3 Coker Heater A-165102 EU 037 Steam/Air Heater Decoking 23H-1 A-167103 EU 038 Steam/Air Heater Decoking 23H-2 A-168104 EU 040 #3 Crude Unit Charge Heater A-169105 EU 041 #3 Crude Unit Vac Pre-Fractionator Heater A-172106 EU 050 Distillate HDS Recycle Hydrogen Charge Heater A-175107 EU 051 Distillate Hydrotreater Fractionator Heater A-177108 EU 052 #2 H2 Plant Reformer Heater A-179109 EU 053 Naphtha Hydrotreater Reactor Charge Heater A-181110 EU 056 HDS Heater (hot oil system) A-183111 EU 058 #5 HSD Charge Heater (naphtha) A-184112 EU 060 #1 HDS Fractionation Heater A-185113 EU 077 Powerformer Catalyst Regeneration A-186114 EU 084 Gas Oil HDS Charge Heater A-187115 EU 085 Gas Oil HDS Fractionation Charge Heater A-189116 EU 099 Platformer Catalyst Regeneration Vent A-191117 EU 102 Unit 38 Gasoil HDS A-Train Heater A-192118 EU 103 Unit 38 Gasoil HDS B-Train Heater A-193119 EU 104 Unit 38 Gasoil HDS Fractionation Charge Heater A-194120 EU 126 Steam Boiler No 6 at Boilerhouse A-195121 EU 127 Plant Air Compressor Diesel Engine A-197122 EU 185 OSWTP- Enhanced Biological Treatment Basin 94B3C A-198123 EU 197 OSWTP- Oily Sludge Dewatering (Centrifuge) A-199124 EU 204 Steam Boiler #8 A-200125 EU 212 11H-6 A-202

126 EU 213 #3 H2 Heater A-204127 EU 228 FCCU A-207128 EU 241 #1 H2 Plant Reformer/Heater A-212129 EU 245 Merox Off Gas Incinerator (old SRU ½ incinerator) A-213130 EU 254 Unit 94H3 Thermal Oxidizer Back-up A-215131 EU 276 Central Buffer Zone Offgas A-216132 EU 277 West Buffer Zone Offgas A-218133 EU 282 OSWTP – Thermal Oxidizer A-220134 EU 294 Hydrocracker Feed Heater A-223135 EU 295 Hydrocracker Reboiler A-226136 EU 296 No 4 Hydrogen Plant Reformer A-229137 EU 312 No 6 Cooling Tower Diesel Pump A-232138 EU 313 Steam Boiler No 9 A-233139 EU 324 #3 Crude Unit Vacuum Heater A-237140 CE 002 Direct Flame Afterburner A-240141 CE 003 Activated Carbon Adsorption A-241142 CE 026 Direct Flame Afterburner A-243143 CE 028 Direct Flame Afterburner A-244144 CE 029 Direct Flame Afterburner A-245145 CE 050 Flaring A-246146 FS 001 Unburied Sewer Lines A-248147 FS 009 Coke Pile A-250148 FS 027 15-Coker Gasoline A-251149 FS 045 Delayed Coker and Gasoline A-252150 MR 027 23H-2 O2 Analyzer A-253151 MR 152 NOx Monitor at 25H4 A-255152 MR 153 CO Monitor at 25H4 A-256153 MR 154 O2 Monitor at 25H4 A-257154 MR 156 41 Unit Fuel Gas Mix Drum Total Sulfur A-258155 MR 161 47/45 Mix Drum Fuel Gas Combustion SO2 Monitor at 25H3 A-259156 MR 162 47/45 Mix Drum Fuel Gas Combustion SO2 Monitor at 29H1/2 A-260157 MR 165 47/45 Mix Drum Fuel Gas Combustion O2 Monitor at 25H3 A-261158 MR 166 47/45 Mix Drum Fuel Gas Combustion O2 Monitor at 29H1/2 A-262159 MR 167 27H-101 CO Monitor A-263160 MR 168 27H-101 NOx Monitor A-264161 MR 170 71B6 NOx Monitor A-265162 MR 171 71B6 CO Monitor A-266163 MR 179 29H-1/2 NOx Monitor A-268164 MR 180 29H-1/2 CO Monitor A-269165 MR 181 29H-1/2 O2 Monitor A-270166 MR 182 27H-101 O2 Monitor A-272 Table B: Submittals

Appendices

Appendix A: Insignificant Activities and Likely Applicable Requirements (Added with Permit Action 001)

Appendix B: Stack Parameters Relied Upon in the Modeling to Demonstrate Compliance with the National Ambient Air Quality Standards for Sulfur Dioxide (SO2) – Amendment 8 to the Administrative Order; Title I Conditions (Added with Permit Action 002) Appendix C: Supporting and Administrative Requirements Associated with the State Implementation Plan (SIP) (Added with Permit Action 002) Appendix D: Consent Decree (Added with Permit Action 001) Appendix E: Flint Hills Resources ULSD Project Projected Emissions Increases (Added with Permit Action 001)

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:

Flint Hills Resources, LP (FHR) owns and operates the Pine Bend Refinery (the Refinery) in the city of Rosemount, Dakota County, Minnesota. The petroleum refinery processes primarily heavy, sour crude oil from Western Canada, although it may also process oil from other parts of the world. Pipelines currently deliver all of the crude oil to the refinery, where FHR processes it to produce a wide variety of products. These products include unleaded gasoline, home heating oil, commercial and industrial heating oils, transportation fuels, jet fuels, petroleum coke, asphalt, elemental sulfur, and carbon dioxide. FHR distributes these products to customers in Minnesota and the surrounding Upper Midwest States via pipelines, trucks, barges and rails.

PERMIT ACTION 002 DESCRIPTION:

The purpose of the No. 3 Crude Unit Expansion Project is to increase the capacity of the No. 3 Crude Unit from 100,000 barrels per day (bpd) to 150,000 bpd. The project will require the addition of two new emission sources - the No. 3 Crude Unit Vacuum Heater (25H-4; EU324) and additional fugitive equipment associated with the 25 Crude Unit (FS 048). Two existing emission units will be modified – the No. 3 Crude Charge Heater (EU 040; 25H-1) and the No. 3 Crude Vacuum Heater (EU 041; 25H-3). With the addition of the new No. 3 Crude Unit Vacuum Heater (25H-4; EU 324), the existing No. 3 Crude Vacuum Heater (EU 041; 25H-3) will become the No. 3 Crude Unit Vacuum Distillate Heater and will receive additional burners.

The permit amendment incorporates two other permit applications submitted by FHR - a minor permit amendment for a new sulfuric acid storage tank was received on September 28, 2005, and an administrative amendment to extend the testing deadline for fuel gas particulate matter by 120 days received on March 27, 2006.

This permit amendment also incorporates a new fuel firing limit on EU 052 (27H-1) established by a Notice of Compliance dated December 9, 2005. Such limits generally require that the permit be reopened to reflect the revised limit with a MPCA-initiated major amendment under Minn. R. 7007.1600, subp. 1(D).

PERMIT ACTION 003 DESCRIPTION

This permit action is a Major Amendment to install ultra low Nitrogen Oxides (NOX) burners (ULNB) and flue gas recirculation on Boiler No. 6 (EU126) as required by the Facility’s 2001 Consent Decree. These modifications trigger reconstruction under 40 CFR pt. 63, subp. DDDDD and are conservatively assumed to trigger reconstruction under 40 CFR pt. 60, subp. Db. The Facility will be installing NOX, Carbon Monoxide (CO) and SO2 CEMS as part of complying with the newly applicable rules.


This permit action was a major permit amendment for the replacement of both coke drums (E&F) in the No. 3 coker unit due to end of life conditions. A capacity of approximately 4000 barrels of charge per day for the No. 3 coker unit was permitted by this permit action. As a result of this permitted increase, utilization of the two existing No. 3 coker charge heaters was expected to increase. This permit action also allowed modification of heater tubes and convection sections of both heaters to increase efficiency, without an increase in heat input capacity of the units.

Potential increases in emissions from coke loading, unloading, and transport activities associated with the increase in coke production were required to be offset by a decrease in emissions due to a reduction in the coke pile storage space from 30 acres to 15 acres and a shift in operations at the coke pad toward more railcar and less truck transport. To accommodate the new coker drums, the steam air decoking water collection pit that handles the decoking activities for both the No. 3 coker charge heaters will be relocated. Potential increases in sulfur dioxide (SO2) emissions due to the capacity increase of the No. 3 coker unit and resulting increase in fuel gas production were to be offset by a fuel gas sulfur reduction project within the refinery fuel gas system.

This permit action also included several other permit amendments that are unrelated to the No. 3 Coke Unit Drum Replacement Project. These amendments were either included in the same application as the coker drum replacement project permit, were submitted as separate permit amendments by FHR, or are amendments that would otherwise require permit reopening and amendment by the agency. A complete list of these amendments can be found in the technical support document for this permit action.


This permit action is a major amendment. The No. 2 Crude Unit train is being modified to meet projected equipment life goals based on crude slates and corrosion rates. Metallurgy upgrades are being completed on the Crude Unit 11-1, 12 Vacuum Distillation and 16 Vacuum Distillation (FS019, FS022, FS029) and includes substantial sections of piping, valves, and connectors. The project includes metallurgical upgrades to some heat exchangers and vessels using weld overlays. Heater piping for both No. 2 Vacuum Heater, EU019 (16H-1 convection section) and Vacuum Pre-Strip Heater, EU016 (12H-4 convection and radiant sections) are also being upgraded; however, no changes are proposed for the burners (no increase in heater potential). No additional crude rate is being achieved with these changes; specifically, no significant changes are being proposed for any pumps.

The MPCA initiated major amendment under Minn. R. 7007.1600, subp. 1(D); mandatory permit reopenings, that are needed in order to assure compliance with applicable requirements are included in this permit action. This permit action incorporates new or revised limits. The limits have been imposed through performance testing under Minn. R. 7017.2025, subp. 3 and are already in affect.


This major amendment is a combination of several permit applications for unrelated changes at the facility. These changes are for sour water tanks, installation of a new Penex unit (44 Unit) to meet new mobile source air toxic (MSAT II) requirements for (reduction of) gasoline benzene content, updated testing and test-related requirements for the Nos. 1, 2, and 3 coker heaters, a 120-day test extension for coker heaters Nos. 1, 2, and 3-1, and revisions to the requirements for the No. 3 coker drum replacement permit issued in October 2007 due to changes in the scope of the drum replacement project.

The primary change in the No. 3 coker drum replacement project is the decision to not modify the two No. 3 coker heaters. This results in a reduction in the No. 3 coker charge rate increase from 4000 barrels per day to 1500 barrels per day. The associated reduction in the emissions increase makes the project no longer a major Prevention of Significant Deterioration Program modification.

TABLE A: LIMITS AND OTHER REQUIREMENTS 01/21/09

Flint Hills Resources LP - Pine Bend

03700011 - 006

Facility Name:

Permit Number:

A-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 itA. 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 CFR pt. 50; MNState Implementation Plan (SIP)

Modeling: Any increase in SO2 emissions beyond modeled conditions associatedwith the emission units in the SIP shall be modeled at the new predicted SO2emission rates to determine the impact on the NAAQS. (See Appendices C and D).The Permittee may install and operate any new SO2 process or control equipmentwith a maximum potential SO2 rate that does not exceed 2.28 lb/hr, andfurthermore the Permittee may modify and operate existing SO2 process or controlequipment to increase the SO2 emission rate up to 2.28 lb/hr over the modeledemission rate for that source. See Appendix D of this permit.

Title I Condition: SIP for SO2 NAAQS 40 CFR pt. 50and MN State Implementation Plan (SIP)

General Operating and Maintenance Requirements for the SIP: The Permittee shalloperate and maintain the process equipment described in Appendix C according tothe parameters set forth in Appendix C. The parameters were used in the computermodeling performed to demonstrate that the SO2 maintenance area will attaincompliance with the SO2 NAAQS. In addition, the Permittee shall comply with thesupporting and administrative requirements set forth in Appendix D.


Retain all records at the stationary source for a period of five (5) years from thedate of the required monitoring, sample, measurement, or report that correspondswith the SIP Title I Condition.

Title I Condition: Recordkeeping for the StateImplementation Plan (SIP) for SO2 Requirements

The Permittee shall follow the supporting and administrative requirementsassociated with the SIP in Attachment D.

Title I Condition: Supporting and AdministrativeRequirements associated with State ImplementationPlan (SIP) for SO2

Construction and Operation of SIP Emission Units: The Permittee may beginactual construction of new emission units or modification to existing emission unitsupon permit issuance. However, the Permittee shall not operate any new emissionunit or modified emission unit until any required SIP amendment is approved byEPA.


B. SOURCE-SPECIFIC REQUIREMENTS hdr

Permit Appendices: This permit contains 4 appendices as listed in the permit Tableof Contents. The Permittee shall comply with all requirements contained in theappendices.

Minn. R. 7007.0800, subp. 2

#3 Crude Unit Expansion Project: The Permittee shall monitor the actual emissionsof any regulated NSR pollutant that could increase as a result of the project andthat were analyzed using the ATPA test, and the potential emissions of anyregulated NSR pollutant that could increase as a result of the project and that wereanalyzed using potential emissions. The Permittee shall calculate and maintain arecord of the sum of the actual and potential (if 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.

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

#3 Crude Unit Expansion Project: The Permittee must submit a report to theAgency if the annual summed (actual plus potential, if applicable) emissions differfrom the preconstruction projection and exceed the baseline actual emissions by asignificant amount as listed at 40 CFR Section 52.21(b)(23). Such report shall besubmitted to the Agency within 60 days after the end of the year in which theexceedances 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 potential emissions) 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.

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



03700011 - 006

Facility Name:

Permit Number:

A-2

Ultra Low Sulfur Diesel (ULSD) Fuels Project Recordkeeping:

The Permittee shall monitor the emissions of any regulated New Source Review(NSR) pollutant that could increase as a result of the project and that is emitted byany emissions unit identified in Appendix E; and calculate and maintain a record ofthe annual emissions, in tons per year on a calendar year basis, for a period of 5years following resumption of regular operations after the change.

On an annual basis, the Permittee shall calculate the overall change in emissionsfrom the ULSD project for each regulated NSR pollutant. For those units listed as"New" units in Appendix E, the change in emissions shall equal potential emissionsfrom the unit. For all other units (or groups of units) listed in Appendix E, thechange in emissions for each unit shall calculated by subtracting baseline actualemissions from each unit.

40 CFR Section 52.21(r)(6)(iii); Minn. R. 7007.0800,subps. 2 and 5

(actual emissions from July 1, 2001, to June 30, 2003) from the actual emissionsfrom the unit for the calendar year.

The Permittee may exclude, in calculating any increase in emissions that resultsfrom the ULSD project, that portion of the unit's emissions following the project thatthe unit could have accommodated from July 1, 2001 to June 30, 2003 and that arealso unrelated to the ULSD project, including any increased utilization due toproduct demand growth.

CONTINUED40 CFR Section 52.21(r)(6)(iii); Minn. R. 7007.0800,subps. 2 and 5

Annual Report for ULSD: The Permittee shall submit a report to the MPCA if theannual emissions, in tons per year, from the ULSD project, exceed the baselineactual, by a significant amount for that regulated NSR pollutant, and if suchemissions differ from the preconstruction projection as documented and maintainedin Appendix E. Such report shall be submitted to the Administrator within 60 daysafter the end of such year. The report shall contain the following:(a) The name, address and telephone number of the major stationary source;(b) The annual emissions as calculated pursuant to the Project EmissionsRecordkeeping requirement of this section; and(c) Any other information that the Permittee wishes to include in the report (e.g. anexplanation as to why the emissions differ from the preconstruction projection).

40 CFR Section 52.21(r)(6)(v)

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 oil in any process heateror boiler located at the refinery.

Title I Condition: Limit taken to avoid classification as amajor modification under 40 CFR Section 52.21 forNOx and SO2; Minn. R. 7007.3000

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

Minn. R. 7007.0800, subp. 5

C. 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 Table A.

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)



03700011 - 006

Facility Name:

Permit Number:

A-3

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)

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)

D. 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 PerformanceTestThe 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 followingformal review 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 to 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 a minimum of 1hour.

Minn. R. 7007.0800, subp. 6

E. MONITORING REQUIREMENTS hdr



03700011 - 006

Facility Name:

Permit Number:

A-4

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)

F. MODELING REQUIREMENTS hdr

G. 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).

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.

Minn. R. 7007 0800, subp. 5(B)

H. 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

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



03700011 - 006

Facility Name:

Permit Number:

A-5

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 through Minn. R. 7007.1500

Extension Requests: The Permittee may apply for an Administrative Amendmentto extend 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).

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)- (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 68

RMPs must be submitted to the Risk Management Plan (RMP) Reporting Center,P.O. Box 1515, Lanham-Seabrook, Maryland 20703-1515. RMP submittalinformation may be obtained at http://www.epa.gov/swercepp or calling1-800-424-9346.

CONTINUEDRisk Management Plan: 40 CFR 68

I. NATIONAL EMISSION STANDARDS FOR HAZARDOUS AIR POLLUTANTSUNDER PART 63

hdr

The Permittee shall comply with the requirements of 40 CFR pt. 63, subp. EEEE bythe compliance date February 3, 2007, unless EPA grants an extension.

40 CFR pt. 63, subp. EEEE-National EmissionStandards for Hazardous for Hazardous Air Pollutantfor Organic Liquids Distribution

The Permittee shall comply with the requirements of 40 CFR pt. 63, subp. GGGGGby the compliance date October 3, 2006, unless EPA grants an extension.

40 CFR pt. 63, subp. GGGGG-National EmissionStandards for Hazardous for Hazardous Air Pollutantsfor Site Remediation

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. industrial, commercial, and institutional boilers and process heaters;b. brick and structural clay products manufacturing;c. clay ceramics manufacturing.

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

J. NATIONAL EMISSION STANDARS FOR HAZARDOUS AIR POLLUTANTSUNDER PART 61

hdr

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 63.654(a); Minn. R.7011.9930. E.

The Permittee must collect samples and analyze waste streams to determinebenzene concentration in the stream.

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

The Permittee shall request the Administrator's approval prior toconstruction/modification of affected source. Under 40 CFR pt. 61, subp. FF,affected source is the entire facility. The Permittee may modify equipment withinthe facility and add/remove/modify control equipment as long as the entire facility incompliance with 40 CFR pt. 61, subp. FF.

40 CFR Section 60.14; 40 CFR Section 60.15; 40 CFRSection 60.4; 40 CFR Section 61.05; 40 CFR Section61.15

Quarterly Reports: The Permittee shall prepare and submit quarterly NESHAPinspection and certification report.

40 CFR Section 61.357; 40 CFR Section 63.654; Minn.R. 7011.7280; Minn. R. 7011.9930.E.



03700011 - 006

Facility Name:

Permit Number:

A-6

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-d)

K. DETERMINING IF A PROJECT/MODIFICATION IS SUBJECT TO NEWSOURCE REVIEW (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 - 006

Facility Name:

Permit Number:

A-7

Subject Item: GP 001 Boiler Nos. 1,2,3 and 4

Associated Items: EU 121 Steam Boiler No. 1 at Boilerhouse

EU 122 Steam Boiler No. 2 at Boilerhouse



SV 095 Common Boilerhouse Stack

What to do Why to do itBoiler Permanent Shutdown: Within 180 days of startup of Boiler No. 9 (EU 313).Boilers No. 1, 2, 3, and 4 shall be permanently shutdown.

Title I Condition: To avoid classification as a majormodification under 40 CFR Section 52.21(b)(3)(viii)



03700011 - 006

Facility Name:

Permit Number:

A-8

Subject Item: GP 002 Cooling Towers (#3, #4, #5 and #6)

Associated Items: EU 268 No 1 Cooling Tower

EU 269 No 3 Cooling Tower




What to do Why to do itA. EMISSION LIMITS hdr

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

Title I Condition: Limit to avoid classification as amajor modification under 40 CFR Section 52.21

Particulate Matter < 10 micron: less than or equal to 2.4 tons/year using 365-dayRolling Sum for EU-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.


Particulate Matter < 10 micron: less than or equal to 1.9 tons/year using 365-dayRolling Sum for EU-270. This limit becomes effective upon startup of EU-296.










B. RECORDKEEPING REQUIREMENTS hdr

PM and PM10 Emission Calculations: The Permittee shall use the following tocalculate PM and PM10 emissions, unless an alternative calculation method isproposed by the Permittee and approved 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 0.44

Title I Condition: Calculations for a limit to avoidclassification as a major modification under 40 CFRSection 52.21

PM and PM10 Recordkeeping: The Permittee shall calculate and record the dailyand 365-day rolling sum PM/PM10 emissions from each cooling tower.

Title I Condition: Recordkeeping for a limit to avoidclassification as a major modification under 40 CFRSection 52.21

C. 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



03700011 - 006

Facility Name:

Permit Number:

A-9

Subject Item: GP 003 ULSD Project CO Emissions

Associated Items: EU 294 Hydrocracker Feed Heater

EU 295 Hydrocracker Reboiler

EU 296 No. 4 Hydrogen Plant Reformer

SV 167 Hydrogen Plant PSA Feed Bypass

SV 168 Hydrogen Plant PSA Purge Bypass

What to do Why to do itA. EMISSION LIMIT hdr

Carbon Monoxide: less than or equal to 66.1 tons/year using 365-day Rolling Sum(EU 294, EU 295 and EU 296)


B. MONITORING REQUIREMENTS hdr

CO Analyzer: The Permittee shall install, calibrate, maintain and operate ananalyzer to continuously monitor the CO concentration in the PSA feed stream.

Minn. R. 7007.0800, subp. 4

Flow Meter: The Permittee shall install, calibrate, maintain and operate a flowmeter to continuously measure the flow to the PSA unit upon startup of EU-296.

Minn. R. 7007.0800, subp. 4

Bypass Valve Status Monitor: The Permittee shall install, calibrate, maintain andoperate monitors to determine bypass valve status and continuously determinewhether the bypass valves are open or closed.

Minn. R. 7007.0800, subp. 4

Monitoring Equipment Calibration: Calibrate and/or maintain CO analyzer, flowmeters and bypass valve according to manufacturer specifications. Maintaindocumentation showing that the calibrations and/or maintenance has beencompleted.

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

C. RECORDKEEPING REQUIREMENTS hdr

CO Calculations and Recordkeeping: The Permittee shall calculate and record thedaily and 365-day rolling sum CO emissions from the listed emissions units above.


CO Calculations: When a bypass valve is open, the flow meter shall be used tomonitor the flow to the PSA unit and the CO analyzer shall be used to monitor theCO concentration in the PSA feed stream.

Minn. R. 7007.0800, subp. 5

Recordkeeping: The Permittee shall record the daily and the 365-day rolling sumof CO emissions from the PSA bypass vents.

Minn. R. 7007.0800, subp. 5



03700011 - 006

Facility Name:

Permit Number:

A-10

Subject Item: GP 004 ULSD Project VOC Emissions



EU 296 No. 4 Hydrogen Plant Reformer

FS 133 Hydrocracker Feed Equipment

FS 134 No. 4 Hydrogen Plant Fugitive Equipment

TK 522 Heavy Naphtha



Volatile Organic Compounds: less than or equal to 25.7 tons/year using 12-monthRolling Sum (EU 294, EU 295, EU 296, FS 133, FS 134, TK 943, TK 944, and TK945)

Title I Condition: Limit to avoid classification as amajor modification under 40 CFR Section 52.21.

B. RECORDKEEPING REQUIREMENT hdr

VOC Calculations and Recordkeeping: By the 28th day of each month, thePermittee shall sum and record VOC emissions from the listed emission units foreach month and for the previous 12 months (12-month rolling sum). Emissionsshall be calculated using the most current AP-42 emission factor for uncontrolledcombustion of natural gas unless a different emission factor is developed by thePermittee and approved by the MPCA in accordance with Minn. R. 7019.3040 to7019.3100. Fugitive emissions will be determined on a semi-annual basis after allrequired monitoring is completed.




03700011 - 006

Facility Name:

Permit Number:

A-11

Subject Item: GP 007 Tanks subject to NSPS UU (each tank)

Associated Items: TK 019 Asphalt

TK 029 Asphalt

TK 037 Asphalt

TK 039 Asphalt

TK 411 Asphalt

TK 412 Asphalt

TK 414 Asphalt

TK 415 Asphalt

TK 416 Asphalt

TK 417 Asphalt

TK 418 Asphalt

TK 423 Asphalt

TK 424 Asphalt

What to do Why to do itA. STANDARDS hdr

After the compliance dates specified in paragraph (h) of this section (8/18/98), aGroup 1 or Group 2 storage vessel that is part of an existing source and is alsosubject to the provisions of 40 CFR pt. 60, subp. Kb is required to comply only withthe requirements of 40 CFR pt. 60, subp. Kb.

40 CFR Section 63, subp. CC40 CFR Section 63.640(n)(1),NSPS Kb Overlap

Standards for these tanks only apply while they are storing asphalt. 40 CFR Section 60.11(d); 40 CFR Section 60.470(a);Minn. R. 7011.0950

Opacity: Within 60 days after achieving the maximum production rate at which theaffected facility will be operated, but not later than 180 days after initial startup ofsuch facility, no owner or operator subject to the provisions of this subpart shallcause to be discharged into the atmosphere from any asphalt storage tank exhaustgases with opacity greater than 0 percent, except for one consecutive 15-minuteperiod in any 24-hour period when the transfer lines are being blown for clearing.The control device shall not be bypassed during this 15-minute period.

Limit does not apply during startup, shutdown, and malfunction.

40 CFR Section 60.11(c); 40 CFR Section 60.472(c);Minn. R. 7011.0950

B. PERFORMANCE TEST REQUIREMENTS hdr

In conducting performance tests required in 40 CFR Section 60.8(b), the ownershall use as reference methods and procedures the test methods in Appendix A ofthis part or other methods and procedures so specified in the section, except asprovided in 40 CFR Section 60.8(b).

40 CFR Section 60.474(b)

Method 9 and the procedures in 40 CFR Section 60.11 shall be used to determineopacity.

40 CFR Section 60.474(c)(5)

C. RECORDKEEPING AND REPORTING REQUIREMENTS hdr

An owner or operator subject to the provisions of this subpart and using a controldevice not mentioned in 40 CFR Section 60.473(a)-(b) shall provide to theAdministrator information describing the operation of the control device and theprocess parameter(s) which would indicate proper operation and maintenance ofthe device. The Administrator may require continuous monitoring and will determinethe process parameters to be monitored.

40 CFR Section 60.473(c)

The industry is exempted from the quarterly reports required under 40 CFR Section60.7(c). The owner/operator is required to record and report the operatingtemperature of the control device during the performance test and, as required by40 CFR Section 60.7(d), maintain a file of the temperature monitoring results for atleast two years.


Report: May apply to change opacity standard. 40 CFR Section 60.11(e)(6)-(8); 40 CFR Section60.4(a); 40 CFR Section 60.4(b)(Y)



03700011 - 006

Facility Name:

Permit Number:

A-12

Subject Item: GP 008 External FloatingTanks NSPSKb > 39,890 gallons

Associated Items: TK 001 Organic Liquid

TK 002 Organic Liquid




















What to do Why to do itIf storing VOL with max TVP between 0.75 psia and 11.1 psia, comply with therequirements listed under GP 019

40 CFR Section 60.112b(a)

If storing benzene waste as defined in 40 CFR Section 61.341 and either notexempting that waste from control under 40 CFR Section 61.342, or classifying thewaste as uncontrolled, comply with the requirements listed under GP 019regardless of vapor pressure.

40 CFR Section 61.342(c)(1)(ii); 40 CFR Section63.647(a)

Maintain records of current applicability of NSPS Kb control requirements andNESH FF control requirements for each tank on-site. Records may be electronic.

40 CFR Section 60.112b(a); 40 CFR Section61.342(c)(1)(ii)

Subject to 40 CFR Section 60, subps. Kb and A (general provisions). Compliancewith 40 CFR Section 60, subps. Kb and A as listed in this permit fully satisfies therequirements of 40 CFR Section 63, subps. A and CC, 40 CFR Section 60, subps.K, Ka, and QQQ, 40 CFR Section 61, subps. A and FF, as applicable, for thesetanks.

40 CFR Section 61.342(c)(1)(ii); 40 CFR Section61.351(a); Minn. R. 7011.1520, subp. C; Minn. R.7011.9930, subp. E



03700011 - 006

Facility Name:

Permit Number:

A-13

Subject Item: GP 009 Tanks subject to VOC Limit (CFP)

















TK 019 Asphalt









TK 029 Asphalt






TK 037 Asphalt


TK 039 Asphalt








03700011 - 006

Facility Name:

Permit Number:

A-14




TK 065 Ethanol





























TK 334 Wet Slop

TK 336 Organic Liquid Storage Tank

TK 411 Asphalt

TK 412 Asphalt

TK 414 Asphalt

TK 415 Asphalt

TK 416 Asphalt

TK 417 Asphalt



03700011 - 006

Facility Name:

Permit Number:

A-15


TK 423 Asphalt

TK 424 Asphalt


Volatile Organic Compounds: less than or equal to 411 tons/year using 12-monthRolling Average (all the tanks listed above).

Title I Condition: 40 CFR Section 52.21 netting limit forVOC


Recordkeeping: The Permittee shall record product throughput in barrels (bbl). Minn. R. 7007.0800, subp. 4

Recordkeeping: The Permittee shall record the total VOC emissions from listedtanks in tons/yr as a 12-month rolling average.

Title I Condition: Recordkeeping associated with 40CFR Section 52.21 netting limit for VOC



03700011 - 006

Facility Name:

Permit Number:

A-16

Subject Item: GP 010 Tanks/Basins subject to NESHAP FF w/vapor recovery & control device

Associated Items: EU 178 OSWTP - API Oil/Water Separator Fore Bay

EU 182 OSWTP - Sludge Basin 2A

EU 183 OSWTP - Equalization Basin 2B

EU 184 OSWTP - Equalization Basin 2C

EU 185 OSWTP-Enhanced Biological Treatment Basin 94B3C

EU 186 OSWTP - DAF Tank (old)

EU 187 OSWTP - DAF Tank (new)

EU 188 OSWTP - DAF Rapid Mix Tank (old)

EU 189 OSWTP - DAF Rapid Mix Tank (new)

EU 190 OSWTP - DAF Floc Tank (old)

EU 191 OSWTP - DAF Floc Tank (new)

EU 197 OSWTP - Oily Sludge Dewatering (Centrifuge)

EU 218 Old Oil/Water Separator at Old Bottom Loading Rack

EU 222 11V-45 Sludge Recycle Tanks

EU 223 14V-22 Slop Drum

EU 278 OSWTP-API Oil/Water Separator Exit Bay

EU 280 OSWTP-Enhanced Biological Treatment Basin 94B3A

EU 281 OSWTP-Enhanced Biological Treatment Basin 94B3B

EU 289 Air Saturation Drum 94V22

EU 290 94V-25D Wemco Corrugated Plate Separators-Post API Flow

EU 291 94V-25E Wemco Corrugated Plate Separators-Post API Flow

EU 292 94V-25F Wemco Corrugated Plate Separators - Spring Lake


EU 314 Oily Sludge Storage Vessel

TK 312 Chemical/Additive Storage Tank


TK 524 Wastewater Storage Tank 102TK12

TK 525 Organic Liquid Storage Tank 52TK1

What to do Why to do itStandard: Maintain compliance with design, equipment, work practice, operationalstandards.

40 CFR Section 61.12(b); Minn. R. 7011.9900

All equipment that contains waste subject to NESHAP FF standards: The coverand all openings (e.g., access hatches, sampling ports, and gauge wells) shall bedesigned to operate with no detectable emissions as indicated by an instrumentreading of less than 500 ppmv above background, as determined initially andthereafter at least once per year by the methods specified in 40 CFR Section61.355(h).

40 CFR Section 61.343(a)(1)(i); 40 CFR Section61.343(a)(1)(i)(B); 40 CFR Section 63.654(a); Minn. R.7011.9930, subp. E

Install, operate, and maintain a fixed-roof and closed-vent system that routes allorganic vapors vented from the tank to a control device.

40 CFR Section 61.343(a)(1); 40 CFR Section61.343(a)(1)(i); 40 CFR Section 63.654(a); Minn. R.7011.9930, subp. E



03700011 - 006

Facility Name:

Permit Number:

A-17

Measuring: The Permittee shall test equipment for compliance with no detectableemissions in accordance with the following requirements: (1) Monitoring shallcomply with Method 21 from appendix A of 40 CFR part 60.(2) The detection instrument shall meet the performance criteria of Method 21.(3) The instrument shall be calibrated before use on each day of its use by theprocedures specified in Method 21.

40 CFR Section 61.343(a)(1)(i)-(i)(A); 40 CFR Section61.355(h); 40 CFR Section 61.355(h)(1)-(4); 40 CFRSection 61.355(h)(4)(i)-(ii); 40 CFR Section61.355(h)(5)-(7); 40 CFR Section 61.356(h); 40 CFRSection 63.654(a); Minn. R. 7011.9930, subp. E

4) Calibration gases shall be:(i) Zero air (less than 10 ppm of hydrocarbon in air); and(ii) A mixture of methane or n-hexane and air at a concentration of approximately,but less than, 10,000 ppm methane or n-hexane.(5) The background level shall be determined as set forth in Method 21.(6) The instrument probe shall be traversed around all potential leak interfaces asclose as possible to the interface as described in Method 21.(7) The arithmetic difference between the maximum concentration indicated by theinstrument and the background level is compared to 500 ppm for determiningcompliance.

CONTINUED40 CFR Section 61.343(a)(1); 40 CFR Section61.355(h); 40 CFR Section 61.355(h)(1)-(4); 40 CFRSection 61.355(h)(4)(i)-(ii); 40 CFR Section61.355(h)(5)-(7); 40 CFR Section 61.356(h); 40 CFRSection 63.654(a); Minn. R. 7011.9930, subp E

Visual Inspections: Each fixed-roof, seal, access door, and all other openings shallbe checked by visual inspection initially and quarterly thereafter to ensure that nocracks or gaps occur and that access doors and other openings are closed andgasketed properly.

40 CFR Section 61.343(c); 40 CFR Section 61.356(g);40 CFR Section 61.357(d)(8); 40 CFR Section63.654(a); Minn. R. 7011.9930, subp. E

Repair problems found during NESHAP visual inspections: Except as provided in40 CFR Section 61.350, when a broken seal or gasket or other problem isidentified, or when detectable emissions are measured, first efforts at repair shallbe made as soon as practicable, but not later than 45 calendar days afteridentification..

40 CFR Section 61.343(d); 40 CFR Section61.357(d)(8); 40 CFR Section 63.654(a); Minn. R.7011.9930, subp. E

Delay of repair of facilities or units that are subject to the provisions of this subpartwill be allowed:

(1) if the repair is technically impossible without a complete or partial facility or unitshutdown.

(2) Repair of such equipment shall occur before the end of the next facility or unitshutdown.

40 CFR Section 61.350(a)-(b); 40 CFR Section63.654(a); Minn. R. 7011.9930, subp. E

Recordkeeping: An owner or operator shall maintain a record for each visualinspection required that identifies a problem (such as a broken seal, gap or otherproblem) which could result in benzene emissions. The record shall include thedate of the inspection, waste management unit and control equipment locationwhere the problem is identified, a description of the problem, a description of thecorrective action taken, and the date the corrective action was completed.

40 CFR Section 61.356(g)-(h); 40 CFR Section63.654(a); Minn. R. 7011.9930, subp. E

An owner or operator shall maintain a record for each test of no detectableemissions required. The record shall include the following information: date the testis performed, background level measured during test, and maximum concentrationindicated by the instrument reading measured for each potential leak interface. Ifdetectable emissions are measured at a leak interface, then the record shall alsoinclude the waste management unit, control equipment, and leak interface locationwhere detectable emissions were measured, a description of the problem, adescription of the corrective action taken, and the date the corrective action wascompleted.

CONTINUED40 CFR Section 61.356(g)-(h); 40 CFR Section63.654(a); Minn. R. 7011.9930, subp. E

Submit: due 90 days after year starting 01/07/2005 NESHAP annual correctiveaction report. The report must summarizes all inspections required during whichdetectable emissions are measured or a problem (such as a broken seal, gap orother problem) that could result in benzene emissions is identified, includinginformation about the repairs or corrective action taken.

40 CFR Section 61.357(d)(8); 40 CFR Section63.654(a); Minn. R. 7011.9930, subp. E; Minn. R.7017.1010, subp. 3



03700011 - 006

Facility Name:

Permit Number:

A-18

Subject Item: GP 011 Diesel Engines with SIP Conditions and <83.3 hr/mon

Associated Items: EU 007 Emergency generator @ #1,2 crude units

EU 024 Emergency Generator @ FCC

EU 036 Emergency Generator @ #3 Coker

EU 042 Emergency Generator @ #3 Coker Unit

EU 100 Emergency Generator at Platformer

EU 128 Diesel for Standby Circ Pump at #3 Cooling Tower (S end)

EU 129 Diesel for Standby Circ Pump at #3 Cooling Tower (N end)

EU 130 Diesel for Standby Circ Pump at #4 Cooling Tower

EU 131 Diesel for Fire Water Pump at #4 Cooling Tower



EU 198 Diesel for Fire Water Pump at Lagoon

EU 199 Diesel for Fire Water Pump at Storm/Water Basin

What to do Why to do itA. EMISSION LIMITS (APPLIES TO EACH UNIT) hdr

Sulfur Dioxide: less than or equal to 0.5 lbs/million Btu heat input using 3-hourRolling Average . (Compliance with the fuel sulfur content standard willdemonstrate compliance with this requirement)

Minn. R. 7011.2300, subp. 2

Opacity: less than or equal to 20 percent opacity once operating temperatures havebeen attained. (visible air contaminants)

Minn. R. 7011.2300, subp. 1

B. OTHER LIMITS AND REQUIREMENTS (APPLIES TO EACH UNIT) hdr

Operating Hours: less than or equal to 1,000 hours/year using 12-month RollingSum

Title I Condition: SIP for SO2 NAAQS 40 CFR pt. 50;MN State Implementation Plan (SIP)

Sulfur Content of Fuel: less than or equal to 0.05 percent by weight of diesel fuel. Title I Condition: SIP for SO2 NAAQS 40 CFR pt. 50;MN State Implementation Plan (SIP)

Power output from portable diesel engines: less than or equal to 0.23 MMhp-hr permonth using a 12-month rolling sum.

Title I Condition: Netting limit for NOx, 40 CFR Section52.21

C. RECORDKEEPING REQUIREMENTS (APPLIES TO EACH UNIT) hdr

Recordkeeping of Hours of Operation: By the 28th day of each month, record thehours of operation for each engine for the previous month. Sum the hours ofoperation for the previous 12 months and record the 12-month rolling sum.

Title I Condition: Recordkeeping associated with SIPfor SO2 NAAQS 40 CFR pt. 50; MN StateImplementation Plan (SIP)

Diesel Fuel Certification: The Permittee shall retain written documentation of eachshipment of diesel fuel oil. The written documentation shall include the followinginformation: the sulfur content of the diesel fuel, the method used to determine thesulfur content and certification that the sulfur content is less than 0.05 percent byweight.

Minn. R. 7007.0800, subp. 5

Recordkeeping: The Permittee shall calculate and record the monthly and the12-month rolling sum of the total power output from GP 011 engines(MMhp-hr/month) by the 28th day of each month.

Title I Condition: Recordkeeping associated withNetting limit for NOx, 40 CFR Section 52.21

D. REPORTING REQUIREMENTS hdr

The Permittee shall comply with 40 CFR pt. 63, subp. ZZZZ by the compliancedate, February 26, 2007.

National Emission Standards for Hazardous AirPollutants for Stationary Reciprocating InternalCombustion Engines



03700011 - 006

Facility Name:

Permit Number:

A-19

Subject Item: GP 012 Portable Diesel Engines NonExempt


Power output from portable diesel engines: less than or equal to 6.3696 MMhp-hrper year using a 12-month rolling sum from the sum of all non-exempt portablediesels.

Title I Condition: Limit to avoid classification as a majormodification for NOx, 40 CFR Section 52.21

Sulfur Dioxide: less than or equal to 0.5 lbs/million Btu heat input using 3-hourRolling Average . (Compliance with the fuel sulfur content standard willdemonstrate compliance with this requirement).

Minn. R. 7011.2300, subp. 2


Minn. R. 7011.2300, subp. 1

B. OTHER LIMITS AND REQUIREMENTS hdr

Diesel Engines Allowed: The Permittee may bring new portable diesels on-site,remove existing portable diesels, and modify existing portable diesels withoutapplying for a permit amendment.


C. RECORDKEEPING AND REPORTING REQUIREMENTS hdr

Recordkeeping: The Permittee shall calculate and record the month and the12-month rolling sum of the total power output from GP 012 engines(MMhp-hr/month and MMhp-hr/yr)) by the 28th day of each month.

Title I Condition: Recordkeeping associated with limitto avoid classification as a major modification for NOx,40 CFR Section 52.21

Recordkeeping: Calculate and record the monthly hours of operation in hours permonth.

Title I Condition: Recordkeeping associated with limitto avoid classification as a major modification for NOx,40 CFR Section 52.21



03700011 - 006

Facility Name:

Permit Number:

A-20

Subject Item: GP 014 Portable Diesel which are Exempt


Opacity: less than or equal to 20 percent opacity once operating temperatures havebeen obtained. (visible air contaminants)

Minn. R. 7011.2300, subp. 1


Recordkeeping of Exempt Portable Diesel Engines: The Permittee shall documentthe exemption for any non-mobile portable diesel engine brought on-site and usedexclusively for maintenance or construction or which is less than to equal to 73horsepower (hp).

Title I Condition: Recordkeeping associated with limittaken to avoid classification as a major modificationunder 40 CFR Section 52.21

Recordkeeping on location: On a monthly basis, the Permittee shall updaterecording list of the location of each exempt portable diesel engines.

Title I Condition: Recordkeeping associated with limittaken to avoid classification as a major modificationunder 40 CFR Section 52.21

C. REPORTING REQUIREMENT hdr

Reporting: The Permittee shall submit a report to MPCA when the totalhorsepower (hp) of exempt portable diesel engines exceeds 294 hp. Thisrequirement applies to portable diesel engines that are exempt due to the individualpower output being less than or equal to 73 hp. It also specifically excludes thosediesel engines that are categorically exempt.

Title I Condition: Reporting associated with limit takento avoid classification as a major modification under 40CFR Section 52.21



03700011 - 006

Facility Name:

Permit Number:

A-21

Subject Item: GP 015 FCC Spent Catalyst Transfers

Associated Items: EU 230 FCC Fresh Catalyst Transfer to Hopper

EU 231 FCC Spent Catalyst Transfer to Hopper

EU 232 FCC Spent Catalyst Transfer to Hopper


Total Particulate Matter: less than or equal to 0.3 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. 7011.0710, subp. 1.B.

Opacity: less than or equal to 20 percent opacity except for one six-minute periodper hour of not more than 60 percent opacity. This emission limit applies to eachemission unit in this group.

Minn. R. 7011.0710, subp. 1.A.



03700011 - 006

Facility Name:

Permit Number:

A-22

Subject Item: GP 017 Loading Rack Activities in CFP group limit

Associated Items: EU 004 New Truck Bottom Loading (gas, distillate) including the trucks (replaces EU4)

EU 205 Asphalt & Heavy Fuel Oil Truck Loading

EU 207 Barge Loading/Unloading Heavy Product (N side)

EU 208 Barge Loading/Unloading Heavy Product (S side)

EU 209 Track 8 Rail Loading

EU 216 Tracks 1-7 Rail Loading Excluding Sulfur, spent acid loading


Volatile Organic Compounds: less than or equal to 100 tons/year using 365-dayRolling Average (Applies to the group of emission units listed above.)

Title I Condition: 40 CFR Section 52.21 netting limit forVOC


VOC Recordkeeping and Calculations: The Permittee shall calculate and recordthe VOC emissions from the listed units above for each day and the previous 365days (365-day rolling average).

Title I Condition: Recordkeeping associated with 40CFR Section 52.21 netting limit for VOC



03700011 - 006

Facility Name:

Permit Number:

A-23

Subject Item: GP 019 External Floating Tanks NSPSKb > 39,890 (0.75-11.1 psi)

What to do Why to do itAn external floating roof. An external floating roof means a pontoon-type ordouble-deck type cover that rests on the liquid surface in a vessel with no fixedroof. Each external floating roof must meet the following specifications:

(i) Each external floating roof shall be equipped with a closure device between thewall of the storage vessel and the roof edge. The closure device is to consist of twoseals, one above the other. The lower seal is referred to as the primary seal, andthe upper seal is referred to as the secondary seal.

(A) The primary seal shall be either a mechanical shoe seal or a liquid-mountedseal. Except as provided in 60 CFR Section 113b(b)(4), the seal shall completelycover the annular space between the edge of the floating roof and tank wall.

40 CFR Section 60.112b(a)(2)(i)-(iii); Minn. R.7011.1520, subp. C

B) The secondary seal shall completely cover the annular space between theexternal floating roof and the wall of the storage vessel in a continuous fashionexcept as allowed in 60 CFR Section 113b(b)(4).

CONTINUED40 CFR Section 60.112b(a)(2)(i)-(iii); Minn. R.7011.1520, subp. C

(ii) Except for automatic bleeder vents and rim space vents, each opening in anoncontact external floating roof shall provide a projection below the liquid surface.Except for automatic bleeder vents, rim space vents, roof drains, and leg sleeves,each opening in the roof is to be equipped with a gasketed cover, seal, or lid that isto be maintained in a closed position at all times (i.e., no visible gap) except whenthe device is in actual use. Automatic bleeder vents are to be closed at all timeswhen the roof is floating except when the roof is being floated off or is being landedon the roof leg supports. Rim vents are to be set to open when the roof is beingfloated off the roof legs supports or at the manufacturer's recommended setting.Automatic bleeder vents and rim space vents are to be gasketed. Each emergencyroof drain is to be provided with a slotted membrane fabric cover that covers atleast 90 percent of the area of the opening.


(iii) The roof shall be floating on the liquid at all times (i.e., off the roof leg supports)except during initial fill until the roof is lifted off leg supports and when the tank iscompletely emptied and subsequently refilled. The process of filling, emptying, orrefilling when the roof is resting on the leg supports shall be continuous and shallbe accomplished as rapidly as possible.


Make necessary repairs or empty the storage vessel within 45 days of identificationin any inspection for seals not meeting the requirements listed in 40 CFR Section60.113(b)(4) (i) and (ii).

(i) The accumulated area of gaps between the tank wall and the mechanical shoeor liquid-mounted primary seal shall not exceed 212 Cm 2 per meter of tankdiameter, and the width of any portion of any gap shall not exceed 3.81 cm.

(A) One end of the mechanical shoe is to extend into the stored liquid, and theother end is to extend a minimum vertical distance of 61 cm above the stored liquidsurface.

(B) There are to be no holes, tears, or other openings in the shoe, seal fabric, orseal envelope.

(ii) The secondary seal is to meet the following requirements:

40 CFR Section 60.113b(b)(4)(i)(A)-(B); 40 CFRSection 60.113b(b)(4)(ii)(A)-(C); Minn. R. 7011.1520,subp. C

(A) The secondary seal is to be installed above the primary seal so that itcompletely covers the space between the roof edge and the tank wall except asprovided in 40 CFR Section 60.113(b)(b)(2)(iii).

(B) The accumulated area of gaps between the tank wall and the secondary sealshall not exceed 21.2 cm2 per meter of tank diameter, and the width of any portionof any gap shall not exceed 1.27 cm.

(C) There are to be no holes, tears, or other openings in the seal or seal fabric.

CONTINUED40 CFR Section 60.113b(b)(4)(i)(A)-(B); 40 CFRSection 60.113b(b)(4)(ii)(A)-(C); Minn. R. 7011.1520,subp. C

Determine the gap areas and maximum gap widths, between the primary seal andthe wall of the storage vessel and between the secondary seal and the wall of thestorage vessel according to the following frequency.

(i) Measurements of gaps between the tank wall and the primary seal (seal gaps)shall be performed during the hydrostatic testing of the vessel or within 60 days ofthe initial fill with VOL and at least once every 5 years thereafter.

40 CFR Section 60.113(b)(b)(1)(i)-(iii); Minn. R.7011.1520, subp. C



03700011 - 006

Facility Name:

Permit Number:

A-24

(ii) Measurements of gaps between the tank wall and the secondary seal shall beperformed within 60 days of the initial fill with VOL and at least once per yearthereafter.

(iii) If any source ceases to store VOL for a period of 1 year or more, subsequentintroduction of VOL into the vessel shall be considered an initial fill for the purposesof 40 CFR Section 60.113(b)(b)(1)(i) and (b)(1)(ii).

CONTINUED40 CFR Section 60.113(b)(b)(1)(i)-(iii); Minn. R.7011.1520, subp. C

Determine gap widths and areas in the primary and secondary seals individually bythe following procedures:

(i) Measure seal gaps, if any, at one or more floating roof levels when the roof isfloating off the roof leg supports.

(ii) Measure seal gaps around the entire circumference of the tank in each placewhere a 0.32-cm diameter uniform probe passes freely (without forcing or bindingagainst seal) between the seal and the wall of the storage vessel and measure thecircumferential distance of each such location.

(iii) The total surface area of each gap described in 40 CFR Section60.113b(b)(2)(ii) shall be determined by using probes of various widths to measureaccurately the actual distance from the tank wall to the seal and multiplying eachsuch width by its respective circumferential distance.

40 CFR Section 60.113b(b)(2)(i)-(iii); Minn. R.7011.1520, subp. C

Add the gap surface area of each gap location for the primary seal and thesecondary seal individually and divide the sum for each seal by the nominaldiameter of the tank and compare each ratio to the respective standards in 40 CFRSection 60.113b(b)(4).

40 CFR Section 60.113b(b)(3); Minn. R. 7011.1520,subp. C

Visually inspect the external floating roof, the primary seal, secondary seal, andfittings each time the vessel is emptied and degassed.

(i) If the external floating roof has defects, the primary seal has holes, tears, orother openings in the seal or the seal fabric, or the secondary seal has holes, tears,or other openings in the seal or the seal fabric, the owner or operator shall repairthe items as necessary so that none of the conditions specified in this paragraphexist before filling or refilling the storage vessel with VOL.

40 CFR Section 60.113b(b)(6); 40 CFR Section60.113b(b)(6)(i)-(ii); Minn. R. 7011.1520, subp. C

(ii) For all the inspections required by 40 CFR Section 60.113b(b)(6), the owner oroperator shall notify the Administrator in writing at least 30 days prior to the filling orrefilling of each storage vessel to afford the Administrator the opportunity to inspectthe storage vessel prior to refilling. If the inspection required by 40 CFR Section60.113b(b)(6) is not planned and the owner or operator could not have knownabout the inspection 30 days in advance of refilling the tank, the owner or operatorshall notify the Administrator at least 7 days prior to the refilling of the storagevessel. Notification shall be made by telephone immediately followed by writtendocumentation demonstrating why the inspection was unplanned. Alternatively, thisnotification including the written documentation may be made in writing and sent byexpress mail so that it is received by the Administrator at least 7 days prior to therefilling.

CONTINUED40 CFR Section 60.113b(b)(6); 40 CFR Section60.113b(b)(6)(i)-(ii); Minn. R. 7011.1520, subp. C

If the owner or operator determines that it is unsafe to perform the seal gapmeasurements required in 40 CFR Section 60.113b(b) of subpart Kb or to inspectthe vessel to determine compliance with 40 CFR Section 60.113b(a) of subpart Kbbecause the roof appears to be structurally unsound and poses an imminentdanger to inspecting personnel, the owner or operator shall comply with therequirements in either 40 CFR Section 63.120(b)(7)(i) or 40 CFR Section63.120(b)(7)(ii) of subpart G.

40 CFR Section 63.640(n)(8)(ii); Minn. R. 7011.1520,subp. C

The sliding cover shall be in place over the slotted guidepole opening through thefloating roof at all times except when the sliding cover must be removed for access.If the control technology used includes a guidepole float, the float shall be floatingwithin the guidepole at all times except when it must be removed for access to thestored liquid or when the tank is empty.

STERP Agreement March 2001 Slotted Guidepoles

Visually inspect the deck fitting for the slotted guidepole deck fitting at least onceevery 10 years and each time the vessel is emptied and degassed. If the slottedguidepole deck fitting or control devices have defects, or if a gap of > 1/8" existsbetween any gasket required for control of the slotted guidepole deck fitting andany surface it is intended to seal, such items shall be repaired before filling orrefilling the storage vessel with regulated material. Tanks taken out of hydrocarbonservice, for any reason, do not have to have any controls in place during the timethey are out of service.




03700011 - 006

Facility Name:

Permit Number:

A-25

If the tank is in service, all slotted guidepole deck fitting or control device defects orgaps >1/8" on gaskets or seals required for control must be repaired within 45 daysof inspection. If necessary, the owner or operator may utilize up to two extensionsof up to 30 additional calendar days each. The owner or operator is not required toprovide a request for the extension to the Administrator.


Double wiper seals are approved control technology for slotted ladders underFHR's Storage Tank Emission Partnership Agreement for new and existing tanks.

May 24, 2004, letter from James K. Jackson, U.S. EPA

The owner or operator of each storage vessel as specified in 60 CFR Section110b(a) shall keep readily accessible records showing the dimension of the storagevessel and an analysis showing the capacity of the storage vessel.

40 CFR Section 60.116b(b); Minn. R. 7011.1520,subp. C

Except as provided in 40 CFR Section 60.116b(f) and (g), the owner or operator ofeach storage vessel either with a design capacity greater than or equal to 151 m3storing a liquid with a maximum true vapor pressure greater than or equal to 3.5kPa or with a design capacity greater than or equal to 75 m3 but less than 151 m3storing a liquid with a maximum true vapor pressure greater than or equal to 15.0kPa shall maintain a record of the VOL stored, the period of storage, and themaximum true vapor pressure of that VOL during the respective storage period.

40 CFR Section 60.116b(c); Minn. R. 7011.1520, subp.C

Available data on the storage temperature may be used to determine the maximumtrue vapor pressure as determined below.

(1) For vessels operated above or below ambient temperatures, the maximum truevapor pressure is calculated based upon the highest expected calendar-monthaverage of the storage temperature. For vessels operated at ambient temperatures,the maximum true vapor pressure is calculated based upon the maximum localmonthly average ambient temperature as reported by the National Weather Service.

40 CFR Section 60.116b(e)(1); 40 CFR Section60.116b(e)(2)(i)-(ii); 40 CFR Section60.116b(e)(3)(i)-(iv); Minn. R. 7011.1520, subp. C

For crude oil or refined petroleum products the vapor pressure may be obtained bythe following:

(i) Available data on the Reid vapor pressure and the maximum expected storagetemperature based on the highest expected calendar-month average temperatureof the stored product may be used to determine the maximum true vapor pressurefrom nomographs contained in API Bulletin 2517 (incorporated by reference�see40 CFR Section 60.17), unless the Administrator specifically requests that the liquidbe sampled, the actual storage temperature determined, and the Reid vaporpressure determined from the sample(s).

(ii) The true vapor pressure of each type of crude oil with a Reid vapor pressureless than 13.8 kPa or with physical properties that preclude determination by therecommended method is to be determined from available data and recorded if theestimated maximum true vapor pressure is greater than 3.5 kPa.

CONTINUED40 CFR Section 60.116b(e)(1); 40 CFR Section60.116b(e)(2)(i)-(ii); 40 CFR Section60.116b(e)(3)(i)-(iv); Minn. R. 7011.1520, subp. C

For other liquids, the vapor pressure:

(i) May be obtained from standard reference texts, or

(ii) Determined by ASTM D2879-83, 96, or 97 (incorporated by reference see 40CFR Section 60.17); or

(iii) Measured by an appropriate method approved by the Administrator; or

(iv) Calculated by an appropriate method approved by the Administrator.


Keep a record of each gap measurement performed as required by 40 CFR Section60.113b(b). Each record shall identify the storage vessel in which themeasurement was performed and shall contain:

(i) The date of measurement.

(ii) The raw data obtained in the measurement.

(iii) The calculations described in 40 CFR Section 60.113b (b)(2) and (b)(3).

40 CFR Section 60.115b; 40 CFR Section60.115b(b)(3)(i)-(iii); Minn. R. 7011.1520, subp. C

If a failure that is detected during inspections required in paragraph (b)(1) of 40CFR 60 Section 113b(b) cannot be repaired within 45 days and if the vessel cannotbe emptied within 45 days, the owner or operator may utilize up to two extensionsof up to 30 additional calendar days each. The owner or operator is not required toprovide a request for the extension to the Administrator.

40 CFR Section 60.113b(b)(4)(iii); 40 CFR Section60.19(b); 40 CFR Section 60.19(c); 40 CFR Section60.4(a); 40 CFR Section 60.4(b)(Y); 40 CFR Section63.640(n)(8)(iii); Minn. R. 7011.1520, subp. C

Notify the Administrator 30 days in advance of any gap measurements required by40 CFR Section 60.113b(b)(1) to afford the Administrator the opportunity to havean observer present.

40 CFR Section 60.113b(b)(5); 40 CFR Section60.19(b); 40 CFR Section 60.19(c); 40 CFR Section60.4(a); 40 CFR Section 60.4(b)(Y); Minn. R.7011.1520, subp. C



03700011 - 006

Facility Name:

Permit Number:

A-26

Furnish the Administrator with a report that describes the control equipment andcertifies that the control equipment meets the specifications of 40 CFR Section60.112b(a)(2) and 40 CFR Section 60.113b(b)(2), (b)(3), and (b)(4). This reportshall be an attachment to the notification required by 40 CFR Section 60.7(a)(3).

40 CFR Section 60.115b(b)(1); Minn. R. 7011.1520,subp. C

Within 60 days of performing the seal gap measurements required by 40 CFRSection 60.113(b)(1) furnish the Administrator with a report that contains:

(i) The date of measurement.

(ii) The raw data obtained in the measurement.

(iii) The calculations described in 40 CFR Section 60.113b (b)(2) and (b)(3).

40 CFR Section 60.115b(b)(2)(i)-(iii); 40 CFR Section60.19(b); 40 CFR Section 60.19(c); 40 CFR Section60.4(a); 40 CFR Section 60.4(b)(Y); Minn. R.7011.1520, subp. C

After each seal gap measurement that detects gaps exceeding the limitationsspecified by 40 CFR Section 60.113b(b)(4), submit a report to the Administratorwithin 30 days of the inspection. The report will identify the vessel and contain theinformation specified in 40 CFR Section 60.115(b)(2) and the date the vessel wasemptied or the repairs made and date of repair.

40 CFR Section 60.115b(b)(4); 40 CFR Section60.19(b); 40 CFR Section 60.19(c); 40 CFR Section60.4(a); 40 CFR Section 60.4(b)(Y); Minn. R.7011.1520, subp. C

The owner or operator shall keep copies of all records required by this section,except for the record required by 40 CFR Section 60.116b(b) for at least 2 years.The record required by 40 CFR Section 60.116(b)(b) will be kept for the life of thesource.

40 CFR Section 60.116b(a); Minn. R. 7011.1520

The owner or operator of each vessel storing a waste mixture of indeterminate orvariable composition shall be subject to the following requirements.

(1) Prior to the initial filling of the vessel, the highest maximum true vapor pressurefor the range of anticipated liquid compositions to be stored will be determinedusing the methods described in 40 CFR Section 60.116b(e).

(2) For vessels in which the vapor pressure of the anticipated liquid composition isabove the cutoff for monitoring but below the cutoff for controls as defined in 40CFR Section 60.112b(a), an initial physical test of the vapor pressure is required;and a physical test at least once every 6 months thereafter is required asdetermined by the following methods:(i) ASTM D2879-83, 96, or 97 (incorporated by reference, see 40 CFR Section60.17); or(ii) ASTM D323-82 or 94 (incorporated by reference, see 40 CFR Section 60.17); or

(iii) As measured by an appropriate method as approved by the Administrator.

40 CFR Section 60.116b(f); 40 CFR Section60.116b(f)(1); 40 CFR Section 60.116b(f)(2)(i)-(iii);Minn. R. 7011.1520, subp. C



03700011 - 006

Facility Name:

Permit Number:

A-27

Subject Item: GP 023 NSPS K Tanks w/ fixed roof > 40,000 gals without CVS/CD

Associated Items: TK 500 Cooling Water @ 21 Unit

What to do Why to do itMay not store benzene waste as defined in 40 CFR Section 61.341 UNLESS thatwaste is exempted from control under 40 CFR Section 61.342.

40 CFR Section 61.342(c)(1)(ii); Minn. R. 7011.1520,subp. A

May not store a material that is >4% organic HAPs (annual average) per Table 1 of40 CFR Section 63, subp. CC AND has an annual true vapor pressure >8.3kPA.

40 CFR Section 63.641 Defn-Group 1 storage vessel;Minn. R. 7011.1520, subp. A

The owner or operator of any storage vessel to which this subpart applies shallstore petroleum liquids as follows:

(1) If the true vapor pressure of the petroleum liquid, as stored, is equal to orgreater than 78 mm Hg (1.5 psia) but not greater than 570 mm Hg (11.1 psia), thestorage vessel shall be equipped with a floating roof, a vapor recovery system, ortheir equivalents.

(2) If the true vapor pressure of the petroleum liquid as stored is greater than 570mm Hg (11.1 psia), the storage vessel shall be equipped with a vapor recoverysystem or its equivalent.

40 CFR Section 60.112(a)(1)-(2); Minn. R. 7011.1520,subp. A

Except as provided in paragraph (d) of 40 CFR Section 60.113, the owner oroperator shall maintain a record of the petroleum liquid stored, the period ofstorage, and the maximum true vapor pressure of that liquid during the respectivestorage period.

40 CFR Section 60.113(a); Minn. R. 7011.1520, subp.A

Available data on the typical Reid vapor pressure and the maximum expectedstorage temperature of the stored product may be used to determine the maximumtrue vapor pressure from nomographs contained in API Bulletin 2517, unless theAdministrator specifically requests that the liquid be sampled, the actual storagetemperature determined, and the Reid vapor pressure determined from thesample(s).

40 CFR Section 60.113(b); Minn. R. 7011.1520, subp.A

The true vapor pressure of each type of crude oil with a Reid vapor pressure lessthan 13.8 kPa (2.0 psia) or whose physical properties preclude determination bythe recommended method is to be determined from available data and recorded ifthe estimated true vapor pressure is greater than 6.9 kPa (1.0 psia).

40 CFR Section 60.113(c); Minn. R. 7011.1520, subp.A

The following are exempt from the requirements of 40 CFR Section 60.113:

(1) Each owner or operator of each affected facility which stores petroleum liquidswith a Reid vapor pressure of less than 6.9 kPa (1.0 psia) provided the maximumtrue vapor pressure does not exceed 6.9 kPa (1.0 psia).

(2) Each owner or operator of each affected facility equipped with a vapor recoveryand return or disposal system in accordance with the requirements of 40 CFRSection 60.112.

40 CFR Section 60.113(d); Minn. R. 7011.1520, subp.A



03700011 - 006

Facility Name:

Permit Number:

A-28

Subject Item: GP 024 NSPS Ka Tanks w/fixed roof > 40,000 gals

Associated Items: TK 502 Jet Water @ 23 Unit

TK 505 Sulfur

What to do Why to do itMay not store benzene waste as defined in 40 CFR Section 61.341 UNLESS thatwaste is exempted from control under 40 CFR Section 61.342.

40 CFR Section 61.342(c)(1)(ii); Minn. R. 7011.1520,subp. B

May not store a material that is >4% organic HAPs (annual average) per Table 1 of40 CFR Section 63, subp. CC AND has an annual true vapor pressure >8.3kPA.

40 CFR Section 63.641 Defn-Group 1 storage vessel;Minn. R. 7011.1520, subp. B

If a storage vessel contains a petroleum liquid which, as stored, has a true vaporpressure equal to or greater than 10.3 Kpa (1.5 psia) but not greater than 76.6 kPa(11.1 psia) the storage vessel shall be equipped with an external floating roof per40 CFR Section 60.112a(a)(1)(i)-(iv), internal floating roof per 40 CFR Section60.112a(a)(2), a vapor recovery system per 40 CFR Section 60.112a(a)(3) or asystem equivalent to those described in paragraphs (a)(1), (a)(2) or (a)(3) of 40CFR Section 60.112a as provided in 40 CFR Section 60.114a.

40 CFR Section 60.112a(a); 40 CFR Section60.112(a)(a)(4)

Except as provided in 40 CFR Section 60.115a(d), the owner or operator subject tothis subpart shall maintain a record of the petroleum liquid stored, the period ofstorage, and the maximum true vapor pressure of that liquid during the respectivestorage period.

40 CFR Section 60.115a(a); Minn. R. 7011.1520,subp. B

Available data on the typical Reid vapor pressure and the maximum expectedstorage temperature of the stored product may be used to determine the maximumtrue vapor pressure from nomographs contained in API Bulletin 2517, unless theAdministrator specifically requests that the liquid be sampled, the actual storagetemperature determined, and the Reid vapor pressure determined from thesample(s).

40 CFR Section 60.115a(b); Minn. R. 7011.1520,subp. B

The true vapor pressure of each type of crude oil with a Reid vapor pressure lessthan 13.8 kPa (2.0 psia) or whose physical properties preclude determination bythe recommended method is to be determined from available data and recorded ifthe estimated true vapor pressure is greater than 6.9 kPa (1.0 psia).

40 CFR Section 60.115a(c); Minn. R. 7011.1520, subp.B

The following are exempt from the requirements of 40 CFR Section 60.115a:

(1) Each owner or operator of each storage vessel storing a petroleum liquid with aReid vapor pressure of less than 6.9 kPa (1.0 psia) provided the maximum truevapor pressure does not exceed 6.9 kPa (1.0 psia).

(2) The owner or operator of each storage vessel equipped with a vapor recoveryand return or disposal system in accordance with the requirements of 40 CFRSection 60.112a(a)(3) and (b), or a closed vent system and control device meetingthe specifications of 40 CFR Section 65.42(b)(4), (b)(5), or (c).

40 CFR Section 60.115a(d)(1)-(2); Minn. R.7011.1520, subp. B



03700011 - 006

Facility Name:

Permit Number:

A-29

Subject Item: GP 025 NSPS Kb Tanks w/fixed roof > 39,890 gals

Associated Items: EU 223 14V-22 Slop Drum

TK 019 Asphalt



TK 029 Asphalt






TK 037 Asphalt


TK 039 Asphalt



TK 052 Organic Liquid Strorage Tank









TK 320 Clarified Oil Storage Tank


TK 411 Asphalt

TK 412 Asphalt

TK 414 Asphalt

TK 415 Asphalt

TK 416 Asphalt

TK 417 Asphalt

TK 418 Asphalt

TK 423 Asphalt

TK 424 Asphalt

TK 513 Sour Water Tank

TK 516 Stripped Sour Water @ 26


TK 526 Sulfur Storage Tank



03700011 - 006

Facility Name:

Permit Number:

A-30

Associated Items: TK 528 Chemical/Additive Storage Tank 35TK4

TK 573 Chemical/Additive Storage Tank 102TK15

TK 574 Spent Sulfuric Acid Storage Tank 35TK5

What to do Why to do itMaintain records of current applicability of NSPS Kb control requirements andNESH FF control requirements for each tank on-site. Records may be electronic.

40 CFR Section 60.112b(a)-(b); 40 CFR Section61.342(c)(1)(ii)



If tank is not equipped with a closed vent system and control device per 40 CFRSection 60.112b(3)(i)-(ii), may not store benzene waste as defined in 40 CFRSection 61.341 UNLESS that waste is exempted from control under 40 CFRSection 61.342.

40 CFR Section 60.112b(3)(i)-(ii); 40 CFR Section61.342(c)(1)(ii)

If storing VOL with max TVP > 0.75 psia, comply with requirements listed under GP034.




03700011 - 006

Facility Name:

Permit Number:

A-31

Subject Item: GP 026 NSPS Tanks Kb w/fixed roof & CVS/CD 19,813-39,890 gals (vp > 4.0 psi)

What to do Why to do it(i) The closed vent system shall be designed to collect all VOC vapors and gasesdischarged from the storage vessel and operated with no detectable emissions asindicated by an instrument reading of less than 500 ppm above background andvisual inspections, as determined in 40 CFR pt. 60, subpart VVa, 40 CFR Section60.485a(b).

(ii) The control device shall be designed and operated to reduce inlet VOCemissions by 95 percent or greater. If a flare is used as the control device, it shallmeet the specifications described in the general control device requirements 40CFR Section 60.18 of the General Provisions.

40 CFR Section 60.112b(a)(3)(i)-(ii); 40 CFR Section112b(b)(1); Minn. R. 7011.1520, subp. C; 40 CFR pt.60, subp. VVa

The owner or operator of each source that is equipped with a closed vent systemand control device as required in 40 CFR Section 60.112b (a)(3) or (b)(2) (otherthan a flare) is exempt from 40 CFR Section 60.8 of the General Provisions.


Submit for approval by the Administrator as an attachment to the notificationrequired by 40 CFR Section 60.7(a)(1) or, if the facility is exempt from 40 CFRSection 60.7(a)(1), as an attachment to the notification required by 40 CFR Section60.7(a)(2), an operating plan containing the information listed below.

40 CFR Section 60.113b(c)(1)(i)-(ii); Minn. R.7011.1520, subp. C

i) Documentation demonstrating that the control device will achieve the requiredcontrol efficiency during maximum loading conditions. This documentation is toinclude a description of the gas stream which enters the control device, includingflow and VOC content under varying liquid level conditions (dynamic and static) andmanufacturer's design specifications for the control device. If the control device orthe closed vent capture system receives vapors, gases, or liquids other than fuelsfrom sources that are not designated sources under this subpart, the efficiencydemonstration is to include consideration of all vapors, gases, and liquids receivedby the closed vent capture system and control device. If an enclosed combustiondevice with a minimum residence time of 0.75 seconds and a minimumtemperature of 816 °C is used to meet the 95 percent requirement, documentationthat those conditions will exist is sufficient to meet the requirements of thisparagraph.

CONTINUED40 CFR Section 60.113b(c)(1)(i)-(ii); Minn. R.7011.1520, subp. C

(ii) A description of the parameter or parameters to be monitored to ensure that thecontrol device will be operated in conformance with its design and an explanation ofthe criteria used for selection of that parameter (or parameters).


Operate the closed vent system and control device and monitor the parameters ofthe closed vent system and control device in accordance with the operating plansubmitted to the Administrator in accordance with 40 CFR Section 60.113b(c)(1),unless the plan was modified by the Admininstrator during the review process. Inthis case, the modified plan applies.

40 CFR Section 60.113b(c)(2); Minn. R. 7011.1520,subp. C

The owner or operator of each source that is equipped with a closed vent systemand a flare to meet the requirements in 40 CFR Section 60.112b (a)(3) or (b)(2)shall meet the requirements as specified in the general control devicerequirements, 40 CFR Section 60.18 (e) and (f).

40 CFR Section 60.113b(d); Minn. R. 7011.1520,subp. C

The owner or operator of each storage vessel as specified in 40 CFR Section60.112b(a) shall keep records and furnish reports as required by 40 CFR Section60.115b(c). The owner or operator shall keep copies of all reports and recordsrequired by 40 CFR Section 60.115b, except for the record required by 40 CFRSection 60.115b(c)(1), for at least 2 years. The record required by 40 CFR Section60.115b(c)(1) will be kept for the life of the control equipment.

40 CFR Section 60.115b; Minn. R. 7011.1520, subp. C

The owner or operator shall keep the following records.

(1) A copy of the operating plan.

(2) A record of the measured values of the parameters monitored in accordancewith 40 CFR Section 60.113b(c)(2).

40 CFR Section 60.115b; 40 CFR Section60.115b(c)(1)-(2); Minn. R. 7011.1520, subp. C



03700011 - 006

Facility Name:

Permit Number:

A-32

After installing a closed vent system and flare to comply with 40 CFR Section60.112b, the owner or operator shall meet the following requirements.

(1) A report containing the measurements required by 40 CFR Section 60.18(f) (1),(2), (3), (4), (5), and (6) shall be furnished to the Administrator as required by 40CFR Section 60.8 of the General Provisions. This report shall be submitted within 6months of the initial start-up date.

(2) Records shall be kept of all periods of operation during which the flare pilotflame is absent.

(3) Semiannual reports of all periods recorded under 40 CFR Section 60.115b(d)(2)in which the pilot flame was absent shall be furnished to the Administrator.

49 CFR Section 60.115b(d)(1)-(3); Minn. R.7011.1520, subp. C

The owner or operator shall keep copies of all records required by 40 CFR Section60.116b except for the record required by 40 CFR Section 60.116b(b), for at least 2years. The record required by 40 CFR Section 60.116b(b) will be kept for the life ofthe source.

40 CFR Section 60.116b(a); Minn. R. 7011.1520,subp. C

The owner or operator of each storage vessel as specified in 40 CFR Section60.110b(a) shall keep readily accessible records showing the dimension of thestorage vessel and an analysis showing the capacity of the storage vessel.





2) For crude oil or refined petroleum products the vapor pressure may be obtainedby the following:

(i) Available data on the Reid vapor pressure and the maximum expected storagetemperature based on the highest expected calendar-month average temperatureof the stored product may be used to determine the maximum true vapor pressurefrom nomographs contained in API Bulletin 2517 (incorporated by reference, see40 CFR Section 60.17), unless the Administrator specifically requests that the liquidbe sampled, the actual storage temperature determined, and the Reid vaporpressure determined from the sample(s).



(3) For other liquids, the vapor pressure:


(ii) Determined by ASTM D2879-83, 96, or 97 (incorporated by reference, see 40CFR Section 60.17); or






03700011 - 006

Facility Name:

Permit Number:

A-33



(2) For vessels in which the vapor pressure of the anticipated liquid composition isabove the cutoff for monitoring but below the cutoff for controls as defined in 40CFR Section 60.112b(a), an initial physical test of the vapor pressure is required;and a physical test at least once every 6 months thereafter is required asdetermined by the following methods:(i) ASTM D2879-83, 96, or 97 (incorporated by reference,see 40 CFR Section60.17); or(ii) ASTM D323-82 or 94 (incorporated by reference,see 40 CFR Section 60.17); or

(iii) As measured by an appropriate method as approved by the Administrator




03700011 - 006

Facility Name:

Permit Number:

A-34

Subject Item: GP 027 NSPS Kb w/fixed roof between 19,813 and 39,890 gals

Associated Items: EU 222 11V-45 Sludge Recycle Tanks




TK 334 Wet Slop

TK 335 Wet Slop




If tank is not equipped with a closed vent system and control device per 40 CFRSection 60.112b(3)(i)-(ii), may not store benzene waste as defined in 40 CFRSection 61.341 UNLESS that waste is exempted from control under 40 CFRSection 61.342 or the waste is accounted for as uncontrolled.

40 CFR Section 60.112b(3)(i)-(ii); 40 CFR Section61.342(c)(1)(ii)

If storing VOL with max TVP greater 4.0 psia, comply with requirements listedunder GP 026.




Frac tanks are exempt from NSPS, subpart Kb. September 2, 2004, Letter to FHR from Mr. George T.Czerniak, Chief, Air Enforcement and ComplianceAssurance Branch, U. S. EPA.



03700011 - 006

Facility Name:

Permit Number:

A-35

Subject Item: GP 032 NSPS K Tanks w/fixed roof & CVS/CD & > 40,000 gals

What to do Why to do itIf storing a petroleum liquid, and if the true vapor pressure of the petroleum liquid,as stored, is equal to or greater than 78 mm Hg (1.5 psia) but not greater than 570mm Hg (11.1 psia) the storage vessel shall be equipped with a floating roof, avapor recovery system or their equivalents.

40 CFR Section 60.112(a); 40 CFR Section60.112(a)(1); Minn. R. 7011.1520, subp. A

If storing a petroleum liquid, and if the true vapor pressure of the petroleum liquid,as stored, is greater than 570 mm Hg (11.1psia), the storage vessel shall beequipped with a vapor recovery system or its equivalent.

40 CFR Section 60.112(a); 40 CFR Section60.112(a)(2); Minn. R. 7011.1520, subp. A

May not store a material that is >4% organic HAPs (annual average) per Table 1 of40 CFR Section 63, subp. CC AND has an annual average true vapor pressure>8.3kPa.

40 CFR Section 63.641 Defn-Group 1 storage vessel;Minn. R. 7011.1520. subp. A



03700011 - 006

Facility Name:

Permit Number:

A-36

Subject Item: GP 033 NSPS Kb Tanks w/fixed roof and CVS/CD & > 39,890

Associated Items: EU 223 14V-22 Slop Drum



If storing VOL with max TVP > 0.75 psia, comply with requirements listed underGP 034.



40 CFR Section 61.342(c)(1)(ii)





03700011 - 006

Facility Name:

Permit Number:

A-37

Subject Item: GP 034 NSPS Kb tanks w/fixed roof & CVS/CD > 39,890 and vp > 0.75

What to do Why to do it(i) The closed vent system shall be designed to collect all VOC vapors and gasesdischarged from the storage vessel and operated with no detectable emissions asindicated by an instrument reading of less than 500 ppm above background andvisual inspections, as determined in 40 CFR pt. 60, subpart VVa, 40 CFR Section60.485a(b).

(ii) The control device shall be designed and operated to reduce inlet VOCemissions by 95 percent or greater. If a flare is used as the control device, it shallmeet the specifications described in the general control device requirements 40CFR Section 60.18 of the General Provisions.

40 CFR Section 60.112b(a)(3)(i)-(ii); 40 CFR Section112b(b)(1); Minn. R. 7011.1520, subp. C; 40 CFR pt.60, subp. VVa

The owner or operator of each source that is equipped with a closed vent systemand control device as required in 40 CFR Section 60.112b (a)(3) or (b)(2) (otherthan a flare) is exempt from 40 CFR Section 60.8 of the General Provisions.


Submit for approval by the Administrator as an attachment to the notificationrequired by 40 CFR Section 60.7(a)(1) or, if the facility is exempt from 40 CFRSection 60.7(a)(1), as an attachment to the notification required by 40 CFR Section60.7(a)(2), an operating plan containing the information listed below.

40 CFR Section 60.113b(c)(1)(i)-(ii); Minn. R.7011.1520, subp. C

i) Documentation demonstrating that the control device will achieve the requiredcontrol efficiency during maximum loading conditions. This documentation is toinclude a description of the gas stream which enters the control device, includingflow and VOC content under varying liquid level conditions (dynamic and static) andmanufacturer's design specifications for the control device. If the control device orthe closed vent capture system receives vapors, gases, or liquids other than fuelsfrom sources that are not designated sources under this subpart, the efficiencydemonstration is to include consideration of all vapors, gases, and liquids receivedby the closed vent capture system and control device. If an enclosed combustiondevice with a minimum residence time of 0.75 seconds and a minimumtemperature of 816 °C is used to meet the 95 percent requirement, documentationthat those conditions will exist is sufficient to meet the requirements of thisparagraph.


(ii) A description of the parameter or parameters to be monitored to ensure that thecontrol device will be operated in conformance with its design and an explanation ofthe criteria used for selection of that parameter (or parameters).


Operate the closed vent system and control device and monitor the parameters ofthe closed vent system and control device in accordance with the operating plansubmitted to the Administrator in accordance with 40 CFR Section 60.113b(c)(1),unless the plan was modified by the Admininstrator during the review process. Inthis case, the modified plan applies.

40 CFR Section 60.113b(c)(2); Minn. R. 7011.1520,subp. C

The owner or operator of each source that is equipped with a closed vent systemand a flare to meet the requirements in 40 CFR Section 60.112b (a)(3) or (b)(2)shall meet the requirements as specified in the general control devicerequirements, 40 CFR Section 60.18 (e) and (f).

40 CFR Section 60.113b(d); Minn. R. 7011.1520,subp. C

The owner or operator of each storage vessel as specified in 40 CFR Section60.112b(a) shall keep records and furnish reports as required by 40 CFR Section60.115b(c). The owner or operator shall keep copies of all reports and recordsrequired by 40 CFR Section 60.115b, except for the record required by 40 CFRSection 60.115b(c)(1), for at least 2 years. The record required by 40 CFR Section60.115b(c)(1) will be kept for the life of the control equipment.


The owner or operator shall keep the following records.

(1) A copy of the operating plan.

(2) A record of the measured values of the parameters monitored in accordancewith 40 CFR Section 60.113b(c)(2).

40 CFR Section 60.115b(c)(1)-(2); Minn. R.7011.1520, subp. C



03700011 - 006

Facility Name:

Permit Number:

A-38

After installing a closed vent system and flare to comply with 40 CFR Section60.112b, the owner or operator shall meet the following requirements.

(1) A report containing the measurements required by 40 CFR Section 60.18(f) (1),(2), (3), (4), (5), and (6) shall be furnished to the Administrator as required by 40CFR Section 60.8 of the General Provisions. This report shall be submitted within 6months of the initial start-up date.

(2) Records shall be kept of all periods of operation during which the flare pilotflame is absent.

(3) Semiannual reports of all periods recorded under 40 CFR Section 60.115b(d)(2)in which the pilot flame was absent shall be furnished to the Administrator.

49 CFR Section 60.115b(d)(1)-(3); Minn. R.7011.1520, subp. C

The owner or operator shall keep copies of all records required by 40 CFR Section60.116b except for the record required by 40 CFR Section 60.116b(b), for at least 2years. The record required by 40 CFR Section 60.116b(b) will be kept for the life ofthe source.








(i) Available data on the Reid vapor pressure and the maximum expected storagetemperature based on the highest expected calendar-month average temperatureof the stored product may be used to determine the maximum true vapor pressurefrom nomographs contained in API Bulletin 2517 (incorporated by reference, see40 CFR Section 60.17), unless the Administrator specifically requests that the liquidbe sampled, the actual storage temperature determined, and the Reid vaporpressure determined from the sample(s).





(ii) Determined by ASTM D2879-83, 96, or 97 (incorporated by reference, see 40CFR Section 60.17); or






03700011 - 006

Facility Name:

Permit Number:

A-39



(2) For vessels in which the vapor pressure of the anticipated liquid composition isabove the cutoff for monitoring but below the cutoff for controls as defined in 40CFR Section 60.112b(a), an initial physical test of the vapor pressure is required;and a physical test at least once every 6 months thereafter is required asdetermined by the following methods:(i) ASTM D2879-83, 96, or 97 (incorporated by reference,see 40 CFR Section60.17); or(ii) ASTM D323-82 or 94 (incorporated by reference,see 40 CFR Section 60.17); or

(iii) As measured by an appropriate method as approved by the Administrator




03700011 - 006

Facility Name:

Permit Number:

A-40

Subject Item: GP 035 NSPS Kb Tanks w/fixed roof & CVS/CD & > 19,813 and < 39,890 gals




If storing VOL with max TVP > 4.0 psia, comply with requirements listed under GP026.








03700011 - 006

Facility Name:

Permit Number:

A-41

Subject Item: GP 037 IFR tank/basin subject to NESHAPs FF following the requirements of Kb





As an alternative to the standards for tanks specified in 40 CFR Section 61.343; anowner or operator may elect to comply with one of the following:

(1) A fixed roof and internal floating roof meeting the requirements in 40 CFRSection 60.112b(a)(1);

(2) An external floating roof meeting the requirements of 40 CFR Section 60.112b(a)(2); or

(3) An alternative means of emission limitation as described in 40 CFR Section60.114b.

If an owner or operator elects to comply with the provisions of this section, then theowner or operator is exempt from the provisions of 40 CFR Section 61.343 of thissubpart applicable to the same facilities.

40 CFR Section 61.351(a); 40 CFR Section61.351(a)(1); 40 CFR Section 61.351(b); 40 CFRSection 61.356(k); 40 CFR Section 61.357(f); 40 CFRSection 63.654(a); Minn. R. 7011.9930, subp. E


40 CFR Section 61.351(a)(1); 40 CFR Section63.640(o)(1); 40 CFR Section 63.647(a)

Comply with requirements of GP 039 (NSPS, subp. Kb for Internal Floating RoofTanks)




03700011 - 006

Facility Name:

Permit Number:

A-42

Subject Item: GP 038 NSPS Kb Tanks w/internal floating roof > 39,890 gallons


















TK 065 Ethanol













If storing VOL with max TVP between 0.75 psia and 11.1 psia, comply withrequirements listed under GP 039.



40 CFR Section 61.342(c)(1)(ii); 40 CFR Section63.647(a); Minn. R. 7011.9930, subp. E





03700011 - 006

Facility Name:

Permit Number:

A-43

Subject Item: GP 039 NSPS Kb tanks w/internal floating> 39,890 gals & tvp (0.75-11.1 psi)

Associated Items: TK 367 Non-Phen Water @ 45 Unit

TK 368 Non-Phen Water @ 45 Unit


What to do Why to do itThe internal floating roof shall rest or float on the liquid surface (but not necessarilyin complete contact with it) inside a storage vessel that has a fixed roof. Theinternal floating roof shall be floating on the liquid surface at all times, except duringinitial fill and during those intervals when the storage vessel is completely emptiedor subsequently emptied and refilled. When the roof is resting on the leg supports,the process of filling, emptying, or refilling shall be continuous and shall beaccomplished as rapidly as possible.

40 CFR Section 60.112b(a)(1)(i); Minn. R. 7011.1520,subp. C

Each internal floating roof shall be equipped with one of the following closuredevices between the wall of the storage vessel and the edge of the internal floatingroof:

(A) A foam- or liquid-filled seal mounted in contact with the liquid (liquid-mountedseal). A liquid-mounted seal means a foam- or liquid-filled seal mounted in contactwith the liquid between the wall of the storage vessel and the floating roofcontinuously around the circumference of the tank.

(B) Two seals mounted one above the other so that each forms a continuousclosure that completely covers the space between the wall of the storage vesseland the edge of the internal floating roof. The lower seal may be vapor-mounted,but both must be continuous.

40 CFR Section 60.112b(b)(1)(ii)(A)-(C); Minn. R.7011.1520, subp. C

(C) A mechanical shoe seal. A mechanical shoe seal is a metal sheet heldvertically against the wall of the storage vessel by springs or weighted levers and isconnected by braces to the floating roof. A flexible coated fabric (envelope) spansthe annular space between the metal sheet and the floating roof.

CONTINUED40 CFR Section 60.112b(b)(1)(ii)(A)-(C); Minn. R.7011.1520, subp. C

Each opening in a noncontact internal floating roof except for automatic bleedervents (vacuum breaker vents) and the rim space vents is to provide a projectionbelow the liquid surface.

40 CFR Section 60.112b(a)(1)(iii); Minn. R. 7011.1520,subp. C

Each opening in the internal floating roof except for leg sleeves, automatic bleedervents, rim space vents, column wells, ladder wells, sample wells, and stub drains isto be equipped with a cover or lid which is to be maintained in a closed position atall times (i.e., no visible gap) except when the device is in actual use. The cover orlid shall be equipped with a gasket. Covers on each access hatch and automaticgauge float well shall be bolted except when they are in use.

40 CFR Section 60.112b(a)(1)(iv); Minn. R. 7011.1520,subp. C

Automatic bleeder vents shall be equipped with a gasket and are to be closed at alltimes when the roof is floating except when the roof is being floated off or is beinglanded on the roof leg supports.

40 CFR Section 60.112b(a)(1)(v); Minn. R. 7011.1520,subp. C

Rim space vents shall be equipped with a gasket and are to be set to open onlywhen the internal floating roof is not floating or at the manufacturer's recommendedsetting.

40 CFR Section 60.112b(a)(1)(vi); Minn. R. 7011.1520,subp. C

Each penetration of the internal floating roof for the purpose of sampling shall be asample well. The sample well shall have a slit fabric cover that covers at least 90percent of the opening.

40 CFR Section 60.112b(a)(1)(vii); Minn. R.7011.1520, subp. C

Each penetration of the internal floating roof that allows for passage of a columnsupporting the fixed roof shall have a flexible fabric sleeve seal or a gasketedsliding cover.

40 CFR Section 60.112b(a)(1)(viii); Minn. R.7011.1520, subp. C

Each penetration of the internal floating roof that allows for passage of a laddershall have a gasketed sliding cover.

40 CFR Section 60.112b(a)(1)(ix); Minn. R. 7011.1520,subp. C

Visually inspect the internal floating roof, the primary seal, and the secondary seal(if one is in service), prior to filling the storage vessel with VOL. If there are holes,tears, or other openings in the primary seal, the secondary seal, or the seal fabricor defects in the internal floating roof, or both, the owner or operator shall repair theitems before filling the storage vessel.

40 CFR Section 60.113b(a)(1); Minn. R. 7011.1520,subp. C



03700011 - 006

Facility Name:

Permit Number:

A-44

For vessels equipped with a liquid-mounted or mechanical shoe primary seal,visually inspect the internal floating roof and the primary seal or the secondary seal(if one is in service) through manholes and roof hatches on the fixed roof at leastonce every 12 months after initial fill. If the internal floating roof is not resting on thesurface of the VOL inside the storage vessel, or there is liquid accumulated on theroof, or the seal is detached, or there are holes or tears in the seal fabric, the owneror operator shall repair the items or empty and remove the storage vessel fromservice within 45 days. If a failure that is detected during inspections required in thisparagraph cannot be repaired within 45 days and if the vessel cannot be emptiedwithin 45 days, the owner or operator may utilize up to two extensions of up to 30additional calendar days each. The owner or operator is not required to provide arequest for the extension to the Administrator.

40 CFR Section 60.113b(a)(2); 40 CFR Section60.113b(a)(3)(ii); 40 CFR Section 63.640(n)(8)(iii);Minn. R. 7011.1520, subp. C

Such a request for an extension must document that alternate storage capacity isunavailable and specify a schedule of actions the company will take that will assurethat the control equipment will be repaired or the vessel will be emptied as soon aspossible.

CONTINUED40 CFR Section 60.113b(a)(2); 40 CFR Section60.113b(a)(3)(ii); Minn. R. 7011.1520, subp. C

For vessels equipped with a double seal system as specified in 40 CFR Section60.112b(a)(1)(ii)(B).

i) visually inspect the vessel as specified in 40 CFR 60.113(b)(a)(4) at least every 5years; or

ii) visually inspect the vessel as specified in 40 CFR Section 60. 113(b)(a)(2).

40 CFR Section 60.113b(a)(3)(i)-(ii); 40 CFR Section60.113b(a)(4); Minn. R. 7011.1520, subp. C

Visually inspect the internal floating roof, the primary seal, the secondary seal (ifone is in service), gaskets, slotted membranes and sleeve seals (if any) each timethe storage vessel is emptied and degassed. If the internal floating roof hasdefects, the primary seal has holes, tears, or other openings in the seal or the sealfabric, or the secondary seal has holes, tears, or other openings in the seal or theseal fabric, or the gaskets no longer close off the liquid surfaces from theatmosphere, or the slotted membrane has more than 10 percent open area, theowner or operator shall repair the items as necessary so that none of the conditionsspecified in this paragraph exist before refilling the storage vessel with VOL.


In no event shall inspections conducted in accordance with this provision occur atintervals greater than 10 years in the case of vessels conducting the annual visualinspection as required by 40 CFR Section 60.113b(a)(2) and (a)(3)(ii) and atintervals no greater than 5 years in the case of vessels specified in 40 CFR Section60.113b(a)(3)(ii).

CONTINUED40 CFR Section 60.113b(a)(4); Minn. R. 7011.1520,subp. C

The sliding cover shall be in place over the slotted guidepole opening through thefloating roof at all times except when the sliding cover must be removed for access.If the control technology used includes a guidepole float, the float shall be floatingwithin the guidepole at all times except when it must be removed for access to thestored liquid or when the tank is empty.


Visually inspect the deck fitting for the slotted guidepole deck fitting at least onceevery 10 years and each time the vessel is emptied and degassed. If the slottedguidepole deck fitting or control devices have defects, or if a gap of > 1/8" existsbetween any gasket required for control of the slotted guidepole deck fitting andany surface it is intended to seal, such items shall be repaired before filling orrefilling the storage vessel with regulated material. Tanks taken out of hydrocarbonservice, for any reason, do not have to have any controls in place during the timethey are out of service.


If the tank is in service, all slotted guidepole deck fitting or control device defects orgaps >1/8" on gaskets or seals required for control must be repaired within 45 daysof inspection. If necessary, the owner or operator may utilize up to two extensionsof up to 30 additional calendar days each. The owner or operator is not required toprovide a request for the extension to the Administrator.


Double wiper seals are approved control technology for slotted ladders underFHR's Storage Tank Emission Partnership Agreement.

May 24, 2004, Letter from James K. Jackson, U. S.EPA

The owner or operator of each storage vessel as specified in 40 CFR Section60.112b(a) shall keep records and furnish reports as required by 40 CFR Section60.115b(a). The owner or operator shall keep copies of all reports and recordsrequired by this section for at least 2 years.


Furnish the Administrator with a report that describes the control equipment andcertifies that the control equipment meets the specifications of 40 CFR Section60.112b(a)(1) and 40 CFR Section 60.113b(a)(1). This report shall be anattachment to the notification required by 40 CFR Section 60.7(a)(3).


The owner or operator shall keep copies of all records required by this section,except for the record required by 40 CFR Section 60.116b(b) for at least 2 years.The record required by 40 CFR Section 60.116b(b) will be kept for the life of thesource.




03700011 - 006

Facility Name:

Permit Number:

A-45



Except as provided in 40 CFR Section 60.116b(f) and (g), the owner or operator ofeach storage vessel either with a design capacity greater than or equal to 151 m3storing a liquid with a maximum true vapor pressure greater than or equal to 3.5kPa or with a design capacity greater than or equal to 75 m3 but less than 151 m3storing a liquid with a maximum true vapor pressure greater than or equal to 15.0kPa shall maintain a record of the VOL stored, the period of storage, and themaximum true vapor pressure of that VOL during the respective storage period.


Keep a record of each inspection performed as required by 40 CFR Section60.113b (a)(1), (a)(2), (a)(3), and (a)(4). Each record shall identify the storagevessel on which the inspection was performed and shall contain the date the vesselwas inspected and the observed condition of each component of the controlequipment (seals, internal floating roof, and fittings).


Notify the Administrator in writing at least 30 days prior to the filling or refilling ofeach storage vessel for which an inspection is required by 40 CFR Section60.113b(a)(1) and (a)(4) to afford the Administrator the opportunity to have anobserver present. If the inspection required by 40 CFR Section 60.113b(a)(4) is notplanned and the owner or operator could not have known about the inspection 30days in advance or refilling the tank, the owner or operator shall notify theAdministrator at least 7 days prior to the refilling of the storage vessel. Notificationshall be made by telephone immediately followed by written documentationdemonstrating why the inspection was unplanned. Alternatively, this notificationincluding the written documentation may be made in writing and sent by expressmail so that it is received by the Administrator at least 7 days prior to the refilling.

40 CFR Section 60.113b(a)(5); 40 CFR Section60.19(b)-(c); 40 CFR Section 60.4(a); 40 CFR Section60.4(b)(Y); Minn. R. 7011.1520, subp. C

If any of the conditions described in 40 CFR Section 60.113b(a)(2) are detectedduring the annual visual inspection required by 40 CFR Section 60.113b(a)(2), areport shall be furnished to the Administrator within 30 days of the inspection. Eachreport shall identify the storage vessel, the nature of the defects, and the date thestorage vessel was emptied or the nature of and date the repair was made.

After each inspection required by 40 CFR Section 60.113b(a)(3) that finds holes ortears in the seal or seal fabric, or defects in the internal floating roof, or othercontrol equipment defects listed in 40 CFR 60.113b(a)(3)(ii), a report shall befurnished to the Administrator within 30 days of the inspection. The report shallidentify the storage vessel and the reason it did not meet the specifications of 40CFR Section 61.112b(a)(1) or 40 CFR Section 60.113b(a)(3) and list each repairmade.

40 CFR Section 60.115b(a)(3)-(4) 40 CFR Section60.19(b)-(c); 40 CFR Section 60.4(a); 40 CFR Section60.4(b)(Y); Minn. R. 7011.1520, subp. C



40 CFR Section 60.116b(e)1; 40 CFR Section60.116b(e)(2)(i-ii); 40 CFR Section 60.116b(3)(i-iv);Minn. R. 7011.1520, subp. C


(i) Available data on the Reid vapor pressure and the maximum expected storagetemperature based on the highest expected calendar-month average temperatureof the stored product may be used to determine the maximum true vapor pressurefrom monographs contained in API Bulletin 2517 (incorporated by reference,see 40CFR Section 60.17), unless the Administrator specifically requests that the liquid besampled, the actual storage temperature determined, and the Reid vapor pressuredetermined from the sample(s).

CONTINUED40 CFR Section 60.116b(e)1; 40 CFR Section60.116b(e)(2)(i-ii); 40 CFR Section 60.116b(3)(i-iv);Minn. R. 7011.1520, subp. C



03700011 - 006

Facility Name:

Permit Number:

A-46




(ii) Determined by ASTM D2879-83, 96, or 97 (incorporated by reference, see 40CFR 60.17); or



CONTINUED40 CFR Section 60.116b(e)1; 40 CFR Section60.116b(e)(2)(i-ii); 40 CFR Section 60.116b(3)(i-iv);Minn. R. 7011.1520, subp. C

The owner or operator of each vessel storing a waste mixture of indeterminate orvariable composition shall be subject to the following requirements.(1) Prior to the initial filling of the vessel, the highest maximum true vapor pressurefor the range of anticipated liquid compositions to be stored will be determinedusing the methods described in 40 CFR Section 60.116b(e).(2) For vessels in which the vapor pressure of the anticipated liquid composition isabove the cutoff for monitoring but below the cutoff for controls as defined in 40CFR Section 60.112b(a), an initial physical test of the vapor pressure is required;and a physical test at least once every 6 months thereafter is required asdetermined by the following methods:

(i) ASTM D2879-83, 96, or 97 (incorporated by reference, see 40 CFR Section60.17); or(ii) ASTM D323-82 or 94 (incorporated by reference,see 40 CFR Section 60.17); or(iii) As measured by an appropriate method as approved by the Administrator.

40 CFR Section 60.116(f)(1); 40 CFR Section60.116b(f)(2)(i-iii); Minn. R. 7011.1520, subp. C



03700011 - 006

Facility Name:

Permit Number:

A-47

Subject Item: GP 042 MACT CC Requirements, satisfied by NSPS Kb

















TK 019 Asphalt








TK 037 Asphalt

TK 039 Asphalt








TK 065 Ethanol








03700011 - 006

Facility Name:

Permit Number:

A-48


























What to do Why to do itSubject to 40 CFR Section 60, subps. Kb and A (general provisions). Compliancewith 40 CFR Section 60, subps. Kb and A as listed in this permit fully satisfies therequirements of 40 CFR Section 63, subps. A and CC, 40 CFR Section 60, subps.K, Ka, and QQQ, 40 CFR Section 61, subps. A and FF, as applicable, for thesetanks.

40 CFR Section 63.640(n)(1); Minn. R. 7011.7280;Minn. R. 7019.0100, subp. 2A-D



03700011 - 006

Facility Name:

Permit Number:

A-49

Subject Item: GP 043 MACT CC Group 2 Tanks (not subject to NSPS Ka or Kb)

Associated Items: TK 300 Chemical/Additive Storage Tank



TK 330 Spent Sul Acid @ 35 Unit

TK 331 Spent Sul Acid @ 35 Unit

TK 366 Amine @ 45 Unit


TK 411 Asphalt

TK 412 Asphalt

TK 414 Asphalt

TK 415 Asphalt

TK 416 Asphalt

TK 417 Asphalt

TK 418 Asphalt

TK 500 Cooling Water @ 21 Unit

TK 501 Water/Process Mixture Storage Tank

TK 502 Jet Water @ 23 Unit



What to do Why to do itAt all times, including period of startup, shutdown, and malfunction, operate andmaintain equipment and associated air pollution control equipment, in a mannerconsistent with good air pollution control practices for minimizing emissions.

40 CFR Section 63.6(e)(1)(i)-(iii); Minn. R. 7011.7280;Minn. R. 7017.2015, subp. 2A-B

Prepare and submit semi-annual MACT CC Periodic Report. Report is due 60 daysafter the end of the 6 month period; reporting periods are January 1 - June 30 andJuly 1 - December 31.

40 CFR Section 63.10(d)(5)(i)-(ii); 40 CFR Section63.646(k); 40 CFR Section 63.654(g)(6)(i)(C)-(D); 40CFR Section 63.654(g)(6)(iii); 40 CFR Section 63.9(i);Minn. R. 7011.7280; Minn. R. 7019.0100, subp. 2A-D



03700011 - 006

Facility Name:

Permit Number:

A-50

Subject Item: GP 044 Tanks MN R 1969-73 and > 65,000 gals



TK 366 Amine @ 45 Unit

TK 411 Asphalt

TK 412 Asphalt

TK 414 Asphalt

What to do Why to do itFor tanks storing petroleum liquids listed in Minn. R. 7011.1500, subp. 8, thePermittee shall comply with the following requirements:

(1) If the true vapor pressure of the petroleum liquid, as stored, is equal to orgreater than 128 mm Hg (2.5 psia) but not greater than 642 mm Hg (12.5 psia) thestoragevessel shall be equipped with a floating roof, a vapor recovery system or theirequivalents.

(2) If the true vapor pressure of the petroleum liquid, as stored, is greater than 642mm Hg (12.5 psia), the storage vessel shall be equipped with a vapor recoverysystem or its equivalent..

Minn. R. 7011.1505, subp. 2C(1)-(2)



03700011 - 006

Facility Name:

Permit Number:

A-51

Subject Item: GP 045 Tanks MN R 1969-73 and 2,000-65,000 gals




What to do Why to do itFor tanks storing petroleum liquids listed in Minn. R. 7011.1500, subp. 8, thePermittee shall equip the storage vessel (as defined in Minn. R. 7011.1500, subp.10) with a permanent submerged fill pipe or comply with the following requirements:

(1) If the true vapor pressure of the petroleum liquid, as stored, is equal to orgreater than 78 mm Hg (1.5 psia) but not greater than 570 mm Hg (11.1 psia), thestorage vessel shall be equipped with a floating roof, a vapor recovery system, or theirequivalents.

(2) If the true vapor pressure of the petroleum liquid as stored is greater than 570mm Hg (11.1 psia), the storage vessel shall be equipped with a vapor recoverysystem or its equivalent.

Minn. R. 7011.1505, subp. 2B; Minn. R. 7011.1500,subp. 10



03700011 - 006

Facility Name:

Permit Number:

A-52

Subject Item: GP 046 Tanks MN R post 1973 and > 40,000 gals

Associated Items: EU 314 Oily Sludge Storage Vessel


























TK 415 Asphalt

TK 416 Asphalt

TK 417 Asphalt

TK 418 Asphalt

TK 423 Asphalt

TK 424 Asphalt

TK 500 Cooling Water @ 21 Unit

TK 502 Jet Water @ 23 Unit

TK 505 Sulfur



TK 516 Stripped Sour Water @ 26




03700011 - 006

Facility Name:

Permit Number:

A-53

Associated Items: TK 522 Heavy Naphtha






TK 574 Spent Sulfuric Acid Storage Tank 35TK5

What to do Why to do itThe requirements in this GP 046 only apply to tanks storing petroleum liquids asdefined in Minn. R. 7011.1500, subp. 8.

Minn. R. 7011.1500, subps. 8 and 11

For tanks storing petroleum liquids listed in Minn. R. 7011.1500, subp. 8, thePermittee shall comply with the following requirements:

(1) If the true vapor pressure of the petroleum liquid, as stored, is equal to orgreater than 78 mm Hg (1.5 psia) but not greater than 570 mm Hg (11.1 psia) thestoragevessel shall be equipped with a floating roof, a vapor recovery system or theirequivalents.

(2) If the true vapor pressure of the petroleum liquid, as stored, is greater than 570mm Hg (11.1psia), the storage vessel shall be equipped with a vapor recoverysystem or its equivalent.

Minn. R. 7011.1510, subp. 3(C)(1)-(2)

Records: The owner or operator shall each storage tank: maintain a file of eachtype of petroleum liquid stored, of the typical Reid vapor pressure of each type ofpetroleum liquid stored, of the dates of storage and withdrawals, and of the date onwhich the storage vessel is empty;

Minn. R. 7011.1510, subp. 1. A.

Records: The owner or operator shall for each storage tank: Determine and recordthe average monthly storage temperature and true vapor pressure of the petroleumliquid stored at such temperature if:

(1) the petroleum liquid has a true vapor pressure, as stored, greater than 26 mmHg (0.5 psia) but less than 78 mm Hg (1.5 psia) and is stored in a storage vesselother than one equipped with a floating roof, a vapor recovery system or theirequivalents; or

(2) the petroleum liquid has a true vapor pressure, as stored, greater than 470 mmHg (9.1 psia) and is stored in a storage vessel other than one equipped with avapor recovery system or its equivalent.

Minn. R. 7011.1510, subp. 1.B(1)-(2)

Calculation: The average monthly storage temperature is an arithmetic averagecalculated for each calendar month, or portion thereof if storage is for less than amonth, from bulk liquid storage temperatures determined at least once every sevendays.

Minn. R. 7011.1510, subp. 2

Vapor pressure determination. The true vapor pressure shall be determined by theprocedure in American Petroleum Institute Bulletin 2517. This procedure isdependent upon determination of the storage temperature and the Reid vaporpressure, which requires sampling of the petroleum liquids in the storage vessels.Unless the agency or the commissioner requires in specific cases that the storedpetroleum liquid be sampled, the true vapor pressure may be determined by usingthe average monthly storage temperature and the typical Reid vapor pressure. Forthose liquids for which certified specifications limiting the Reid vapor pressure exist,that Reid vapor pressure may be used. For other liquids, supporting analytical datamust be made available on request of the agency or the commissioner when typicalReid vapor pressure is used.

Minn. R. 7011.1510, subp. 3



03700011 - 006

Facility Name:

Permit Number:

A-54

Subject Item: GP 047 Tanks MN R post 1973 and 2,000 - 40,000 gals

Associated Items: TK 208 Chemical/Additive Storage Vessel











TK 525 Organic Liquid Storage Tank 52TK1

















TK 545 Chemical/Additive Storage Tank 105V3













03700011 - 006

Facility Name:

Permit Number:

A-55

Associated Items: TK 556 Chemical/Additive Storage Tank 25V41

TK 557 Chemical/Additive Storage Tank 26ME3






















What to do Why to do itFor tanks storing petroleum liquids listed in Minn. R. 7011.1500, subp. 8, thePermittee shall equip the storage vessel (as defined in Minn. R. 7011.1500, subp.10) with a permanent submerged fill pipe or comply with the following requirements:

(1) If the true vapor pressure of the petroleum liquid, as stored, is equal to orgreater than 78 mm Hg (1.5 psia) but not greater than 570 mm Hg (11.1 psia), thestorage vessel shall be equipped with a floating roof, a vapor recovery system, ortheir equivalents.

(2) If the true vapor pressure of the petroleum liquid as stored is greater than 570mm Hg (11.1 psia), the storage vessel shall be equipped with a vapor recoverysystem orits equivalent.

Minn. R. 7011.1505, subp. 3B; Minn. R. 7011.1505,subp. 3C(1)-(2); Minn. R. 7011.1500, subp. 10



03700011 - 006

Facility Name:

Permit Number:

A-56

Subject Item: GP 052 Tanks NSPS QQQ





What to do Why to do itSubject to 40 CFR Section 60, subps. Kb and A (general provisions). [Compliancewith 40 CFR Section 60, subps. Kb and A as listed in this permit fully satisfies therequirements of 40 CFR Section 63, subps. A and CC, 40 CFR Section 60, subps.K, Ka, and QQQ, 40 CFR Section 61, subps. A and FF, as applicable, for thesetanks.]

40 CFR Section 60.11(d); 40 CFR Section60.690-60.699; 40 CFR Section 63.640(o)(1); Minn. R.7011.1435, subp. C

(1) If an emission point cannot be repaired or corrected without a process unitshutdown, the expected date of a successful repair shall be recorded.

(2) The reason for the delay as specified in 40 CFR Section 60.692-6 shall berecorded if an emission point or equipment problem is not repaired or corrected inthe specified amount of time.

(3) The signature of the owner or operator (or designee) whose decision it was thatrepair could not be effected without refinery or process shutdown shall be recorded.

(4) The date of successful repair or corrective action shall be recorded.

40 CFR Section 60.697(e)(1)-(4)



03700011 - 006

Facility Name:

Permit Number:

A-57

Subject Item: GP 053 EFR tank/basin subject to NESHAPs FF following the requirements of Kb

Associated Items: EU 200 OSWTP-Equalization Basin 7A

EU 201 OSWTP-Equalization Basin 7B













Subject to 40 CFR Section 60, subps. Kb and A (general provisions). Compliancewith 40 CFR Section 60, subps. Kb and A as listed in this permit fully satisfies therequirements of 40 CFR Section 63, subps. A and CC, 40 CFR Section 60, subps.K, Ka, and QQQ, 40 CFR Section 61, subps. A and FF, as applicabile, for thesetanks.


Comply with requirements of GP 019 (NSPS, subp. Kb for External Floating RoofTanks)




03700011 - 006

Facility Name:

Permit Number:

A-58

Subject Item: GP 054 Storage Tank Heaters built before June 11, 1973

Associated Items: EU 144 Tank 19 Heater

EU 145 Tank 39 Heater






EU 154 Tank 410 Line Heater













What to do Why to do itA. EMISSION LIMITS (LIMITS APPLY TO EACH UNIT.) hdr

Total Particulate Matter: less than or equal to 0.4 lbs/million Btu heat input using3-hour Rolling Average . The PTE for this heater is 0.00745 lb/mmBtu heat input atmaximum capacity. Compliance with the fuel restriction requirement constitutescompliance with this limit.

Minn. R. 7011.1405, subp. 3. A.

Opacity: less than or equal to 20 percent opacity using 6-minute Average except forone six-minute period per hour of not more than 60 percent opacity. Compliancewith the fuel restriction requirement constitutes compliance with this limit.

Minn. R. 7011.1405, subp. 3. A.

Sulfur Dioxide: less than or equal to 1.75 lbs/million Btu heat input using 3-hourRolling Average . Compliance with the fuel restriction requirement constitutescomplaince with this limit.

Minn. R. 7011.1405, subp. 2


Fuel Restriction: Authorized to burn natural gas only. Title I Condition: SIP for SO2 NAAQS, 40 CFR pt. 50;MN State Implementation Plan (SIP)

Recordkeeping: Record and maintain records of fuel combusted in the unit on amonthly basis.

Minn. R. 7007.0800, subp. 5



03700011 - 006

Facility Name:

Permit Number:

A-59

Subject Item: GP 055 Emission Units subject to Minn. R. built before June 11, 1973

Associated Items: EU 054 #6 HDS Reactor Charge Heater

EU 055 #2 HDS Fractionation Heater

EU 056 HDS Heater (hot oil system)

EU 057 Unisar Reactor Charge Heater

EU 058 #5 HDS Charge Heater (naphtha)

EU 059 #1 HDS Reactor Charge Heater

EU 060 #1 HDS Fractionation Heater

EU 061 #2 HDS Reactor Charge Heater

EU 240 H2 Plant Vaporizer Heater

EU 241 #1 H2 Plant Reformer/Heater


Hydrogen Sulfide: less than or equal to 0.10 grains/dry standard cubic foot using3-hour Rolling Average (230 mg/dscm[162 ppm]). This limit does not apply duringperiods of startup, shutdown, or malfunction.

40 CFR 60.104(a)(1); Minn. R. 7011.1490, subp. 2[most stringent, meets limit set by Minn. R. 7011.1410,subp. 3]


Minn. R. 7011.1405, subp. 3. A.


Minn. R. 7011.1405, subp. 3. A.

Sulfur Dioxide: less than or equal to 1.75 lbs/million Btu heat input using 3-hourRolling Average . Compliance with the fuel restriction requirement constitutescompliance with this limit.

Minn. R. 7011.1405, subp. 2


Fuel Restriction: Authorized to burn refinery gas and natural gas only. Minn. R. 7007.0800, subp. 2

Recordkeeping: Record and maintain records of each fuel combusted in the uniton a monthly basis.

Minn. R. 7007.0800, subp. 5



03700011 - 006

Facility Name:

Permit Number:

A-60

Subject Item: GP 056 Storage Tank Heaters built after June 11, 1973

Associated Items: EU 149 Asphalt Line Heater







EU 274 Asphalt tk Heater for tk 415

EU 275 Asphalt tk Heater for tk 418

What to do Why to do itA. EMISSION LIMITS (LIMIT APPLIES TO EACH UNIT.) hdr


Minn. R. 7011.1410, subp. 3. B.


Minn. R. 7011.1410, subp. 3. B.


Minn. R. 7011.1410, subp. 3. A


Fuel Restriction: Authorized to burn natural gas only. Title I Condition: SIP for SO2 NAAQS, 40 CFR pt. 50;MN State Implementation Plan (SIP)

Recordkeeping: Record and maintain records of fuel combusted in the unit on amonthly basis.

Minn. R. 7007.0800, subp. 5



03700011 - 006

Facility Name:

Permit Number:

A-61

Subject Item: GP 057 Emission Units subject to Minn. R. built after June 11, 1973

Associated Items: EU 093 Naphtha Hydrotreater Charge Heater

EU 094 Naphtha Hydotreater Stripper Reboiler

EU 095 Platformer Charge Heater (Grouped with EU 095/096/097)

EU 097 Platformer #2 Interheater(Grouped with EU 095/096/097)

EU 098 Platformer Stabilizer Reboiler Heater

EU 099 Platformer Catalyst Regeneration Vent

EU 102 Unit 38 Gasoil HDS A-Train Heater

EU 103 Unit 38 Gasoil HDS B-Train Heater

EU 104 Unit 38 Gasoil HDS Fractionation Charge Heater

EU 209 Track 8 Rail Loading





Minn. R. 7011.1410, subp. 3. B


Minn. R. 7011.1410, subp. 3. B


Minn. R. 7011.1410, subp. 3. A.




Minn. R. 7007.0800, subp. 5



03700011 - 006

Facility Name:

Permit Number:

A-62

Subject Item: GP 058 Equipment subject to both NESH FF controls and NSPS QQQ

Associated Items: EU 177 OSWTP - Trash Rack & Diversion Box (S1)

EU 178 OSWTP - API Oil/Water Separator Fore Bay


EU 279 OSWTP-API Oil/Water Separator Mid Bay

EU 283 94S-2A/D Slop Oil Sump at API Oil/Water Separator

FS 045 23- Delayed Coker & Gasoline Plant





What to do Why to do itSubject to 40 CFR Section 61, subps. A and FF requirements. Compliance with 40CFR Section 61, subp. FF and 40 CFR Section 61, subp. A requirements as listedin this permit fully satisfies 40 CFR Section 60, subps. A and QQQ, 40 CFR Section63, subps. A and CC requirements.

40 CFR Section 60.690-60.699; 40 CFR Section60.692-3(a)(4)-(5); 40 CFR Section 60.692-3(b); 40CFR Section 60.692-3(c)(2); 40 CFR Section60.692-3(d)-(e); 40 CFR Section 60.692-5(a); 40 CFRSection 63.640(o)(1)



03700011 - 006

Facility Name:

Permit Number:

A-63

Subject Item: GP 059 Containers subject to NESH FF; w/vac trucks to haul NESH FF waste

Associated Items: EU 284 Phase Separator at Alt Waste Handling Site

EU 315 Vac Trucks at FHR



The owner or operator shall install, operate, and maintain a cover on eachcontainer used to handle, transfer, or store waste in accordance with the followingrequirements: each opening shall be maintained in a closed, sealed position (e.g.,covered by a lid that is gasketed and latched) at all times that waste is in thecontainer except when it is necessary to use the opening for waste loading,removal, inspection, or sampling.

40 CFR Section 61.345(a)(1); 40 CFR Section61.345(a)(1)(ii); 40 CFR Section 63.654(a); Minn. R.7011.9930, subp. E

When a waste is transferred into a container by pumping, the owner or operatorshall perform the transfer using a submerged fill pipe. The submerged fill pipe outletshall extend to within two fill pipe diameters of the bottom of the container while thecontainer is being loaded. During loading of the waste, the cover shall remain inplace and all openings shall be maintained in a closed, sealed position except forthose openings required for the submerged fill pipe, those openings required forventing of the container to prevent physical damage or permanent deformation ofthe container or cover, and any openings complying with 40 CFR Section60.345(a)(4) of this section.

40 CFR Section 61.345(a)(2); 40 CFR Section63.654(a); Minn. R. 7011.9930, subp. E

Treatment of a waste in a container, including aeration, thermal or other treatment,must be performed by the owner or operator in a manner such that while the wasteis being treated the container meets the standards specified in 40 CFR Section61.345(a)(3)(i) through (iii) of this section, except for covers and closed-ventsystems that meet the requirements in 40 CFR Section 61.345(a)(4) of this section.

40 CFR Section 61.345(a)(3)

The owner or operator transferring the waste shall:

(1) Each waste management unit that receives or manages the waste prior toshipment of the waste offsite.

(2) Include with each offsite waste shipment a notice stating that the waste containsbenzene which is required to be managed and treated.

40 CFR Section 61.342(f); 40 CFR Section61.342(f)(2); 40 CFR Section 61.355(k)(2)(iii); 40 CFRSection 61.356(c); Minn. R. 7011.9930, subp. E

An owner or operator shall test equipment for compliance with no detectableemissions as required in accordance with the following requirements:

(1) Monitoring shall comply with Method 21 from appendix A of 40 CFR pt. 60;

(2) The detection instrument shall meet the performance criteria of Method 21.

(3) The instrument shall be calibrated before use on each day of its use by theprocedures specified in Method 21.

40 CFR Section 61.355(h); 40 CFR Section 61.356(h);40 CFR Section 63.654(a); Minn. R. 7011.9930, subp.E

4) Calibration gases shall be:

(i) Zero air (less than 10 ppm of hydrocarbon in air); and

(ii) A mixture of methane or n-hexane and air at a concentration of approximately,but less than, 10,000 ppm methane or n-hexane.

(5) The background level shall be determined as set forth in Method 21.

(6) The instrument probe shall be traversed around all potential leak interfaces asclose as possible to the interface as described in Method 21.

(7) The arithmetic difference between the maximum concentration indicated by theinstrument and the background level is compared to 500 ppm for determiningcompliance.

CONTINUED40 CFR Section 61.355(h); 40 CFR Section 61.356(h);40 CFR Section 63.654(a); Minn. R. 7011.9930, subp.E

Delayed Repairs: Delay of repair of facilities or units that are subject to theprovisions of this subpart will be allowed if the repair is technically impossiblewithout a complete or partial facility or unit shutdown.

Repair of such equipment shall occur before the end of the next facility or unitshutdown.




03700011 - 006

Facility Name:

Permit Number:

A-64

Repairs: when a broken seal or gasket or other problem is identified, first efforts atrepair shall be made as soon as practicable, but not later than 15 calendar daysafter identification.

40 CFR Section 61.345(c); 40 CFR Section 63.654(a);Minn. R. 7011.9930, subp. E;

Monitoring: Each applicable potential leak point must be monitored using Method21 on an annual basis per 40 CFR Section 61.347(a)(1)(i)(A).

40 CFR Section 61.354

Quarterly Inspection: Each cover and all openings shall be visually inspectedquarterly to ensure that they are closed and gasketed properly.

40 CFR 61.345(b); 40 CFR Section 61.356 (g) 40 CFRSection 61.357(d)(8); 40 CFR Section 63.654(a); Minn.R. 7011.9930, subp. E

Annual Report: Shall submit annually to the Administrator a report that summarizesall inspections required during which detectable emissions are measured or aproblem (such as a broken seal, gap or other problem) that could result in benzeneemissions is identified, including information about the repairs or corrective actiontaken.




03700011 - 006

Facility Name:

Permit Number:

A-65

Subject Item: GP 060 Oil/water separators w/floating roof subject to NSPS QQQ

Associated Items: EU 279 OSWTP-API Oil/Water Separator Mid Bay

EU 323 API Separator

What to do Why to do itThe roof shall be floating on the liquid (i.e., off the roof supports) at all times exceptduring abnormal conditions (i.e., low flow rate).

40 CFR Section 60.693-2(a)(3)

Standard: Maintain compliance with design, equipment, work practice, operationalstandards.


Standard: The owner or operator shall make necessary repairs within 30 calendardays of identification of seals not meeting the requirements or roof openings notmeeting requirements unless delay of repair provisions are invoked.

40 CFR Section 60.693-2(a)(1)(iv); 40 CFR Section60.693-2(a)(5)(ii)

Oil-water separator must have external floating roof meeting the specifications:

Each floating roof shall be equipped with a closure device between the wall of theseparator and the roof edge. The closure device is to consist of a primary seal anda secondary seal.

(i) The primary seal shall be a liquid-mounted seal or a mechanical shoe seal.

(A) A liquid-mounted seal means a foam- or liquid-filled seal mounted in contactwith the liquid between the wall of the separator and the floating roof. A mechanicalshoe seal means a metal sheet held vertically against the wall of the separator bysprings or weighted levers and is connected by braces to the floating roof. A flexiblecoated fabric (envelope) spans the annular space between the metal sheet and thefloating roof.

(B) The gap width between the primary seal and the separator wall shall not exceed3.8 cm (1.5 in.) at any point.

40 CFR Section 60.693-2(a)(1); 40 CFR Section60.693-2(d); 40 CFR Section 61.352(a); 40 CFRSection 61.352(a)(1); 40 CFR Section 61.352(c); 40CFR Section 61.356(l); 40 CFR Section 63.654(a);Minn. R. 7011.9930, subp. E

C) The total gap area between the primary seal and the separator wall shall notexceed 67 cm2/m (3.2 in.2/ft) of separator wall perimeter.

(ii) The secondary seal shall be above the primary seal and cover the annularspace between the floating roof and the wall of the separator.

(A) The gap width between the secondary seal and the separator wall shall notexceed 1.3 cm (0.5 in.) at any point.

(B) The total gap area between the secondary seal and the separator wall shall notexceed 6.7 cm2/m (0.32 in.2/ft) of separator wall perimeter.

(iii) The maximum gap width and total gap area shall be determined by the methodsand procedures specified in 40 CFR Section 60.696(d).

CONTINUED40 CFR Section 60.693-2(a)(1); 40 CFR Section60.693-2(d); 40 CFR Section 61.352(a); 40 CFRSection 61.352(a)(1); 40 CFR Section 61.352(c); 40CFR Section 61.356(l); 40 CFR Section 63.654(a);Minn. R. 7011.9930, subp. E

Each opening in the roof shall be equipped with a gasketed cover, seal, or lid,which shall be maintained in a closed position at all times, except during inspectionand maintenance.

40 CFR Section 60.693-2(a)(2)

Monitor: Measurement of primary seal gaps shall be performed within 60 calendardays after initial installation of the floating roof and introduction of refinerywastewater and once every 5 years thereafter.

40 CFR Section 60.693-2(a)(1)(iii)(A); 40 CFR Section60.696(d)(1)(i)-(iii); 40 CFR Section 60.696(d)(2)(i)

Monitor: Measurement of secondary seal gaps shall be performed within 60calendar days of initial introduction of refinery wastewater and once every yearthereafter.

40 CFR Section 60.693-2(a)(1)(iii)(B); 40 CFR Section60.696(d)(1)(i)-(iii); 40 CFR Section 60.696(d)(2)(i)



03700011 - 006

Facility Name:

Permit Number:

A-66

The maximum gap widths and maximum gap areas between the primary seal andthe separator wall and between the secondary seal and the separator wall shall bedetermined individually within 60 calendar days of the initial installation of thefloating roof and introduction of refinery wastewater or 60 calendar days after theequipment is placed back into service using the following procedure when theseparator is filled to the design operating level and when the roof is floating off theroof supports.

(i) Measure seal gaps around the entire perimeter of the separator in each placewhere a 0.32 cm (0.125 in.) diameter uniform probe passes freely (without forcingor binding against seal) between the seal and the wall of the separator andmeasure the gap width and perimetrical distance of each such location.

40 CFR Section 60.696(d)(1); 40 CFR Section60.696(d)(1)(i)-(ii)

(ii) The total surface area of each gap shall be determined by using probes ofvarious widths to measure accurately the actual distance from the wall to the sealand multiplying each such width by its respective perimetrical distance.

(iii) Add the gap surface area of each gap location for the primary seal and thesecondary seal individually, divide the sum for each seal by the nominal perimeterof the separator basin and compare each to the maximum gap area as specified in40 CFR Section 60.693�2.

CONTINUED40 CFR Section 60.696(d)(1); 40 CFR Section60.696(d)(1)(i)-(ii)

(a) Delay of repair of facilities or units that are subject to the provisions of thissubpart will be allowed if the repair is technically impossible without a complete orpartial facility or unit shutdown.

(b) Repair of such equipment shall occur before the end of the next facility or unitshutdown.

40 CFR Section 61.350(a)-(b)

Records required for visual inspections: The date, location, and corrective actionfor each visual inspection during which a broken seal, gap, or other problem isidentified that could result in benzene emissions.

40 CFR Section 61.356(l)(1)

Record secondary seal measurements, location, date and corrective actions, if any,annually.


Record primary seal measurements, location, date and corrective actions, if any,every 5 years. Maintain records for at least 10 years.


Prepare and submit quarterly NESHAP inspection/certification report: Install andoperate the control equipment, shall submit quarterly reports that identify all sealgap measurements, as required in 40 CFR Section 60.693-2(a), that are outsidethe prescribed limits.

40 CFR Section 61.357(g)

Prepare and submit NESHAP annual corrective action report: the owner or operatorshall submit annually to the Administrator a report that summarizes all inspectionsrequired during which detectable emissions are measured or a problem (such as abroken seal, gap or other problem) that could result in benzene emissions areidentified, including information about the repairs or corrective action taken.

40 CFR Section 61.357(d)(8)



03700011 - 006

Facility Name:

Permit Number:

A-67

Subject Item: GP 061 Oil/water separators w/fixed roof subject to NSPS QQQ



What to do Why to do itRecord: (1) If an emission point cannot be repaired or corrected without a processunit shutdown, the expected date of a successful repair shall be recorded.

(2) The reason for the delay shall be recorded if an emission point or equipmentproblem is not repaired or corrected in the specified amount of time.



40 CFR Section 60.697(e)(1)-(4)



03700011 - 006

Facility Name:

Permit Number:

A-68

Subject Item: GP 062 Oil/water sep. subject to NESH FF w/CVS & control device; no dilution air opening






What to do Why to do itThe owner or operator shall install, operate, and maintain a cover on eachcontainer used to handle, transfer, or store waste in accordance with the followingrequirements: each opening shall be maintained in a closed, sealed position (e.g.,covered by a lid that is gasketed and latched) at all times that waste is in thecontainer except when it is necessary to use the opening for waste loading,removal, inspection, or sampling.

40 CFR Section 61.345(a)(1); 40 CFR Section61.345(a)(1)(ii); 40 CFR Section 63.654(a); Minn. R.7011.9930, subp. E



The owner or operator shall install, operate, and maintain a fixed-roof andclosed-vent system that routes all organic vapors vented from the oil-waterseparator to a control device.

40 CFR Section 61.347(a)(1); 40 CFR Section 61.352(b); 40 CFR Section 63.654(a); Minn. R. 7011.9930,subp. E
























03700011 - 006

Facility Name:

Permit Number:

A-69





03700011 - 006

Facility Name:

Permit Number:

A-70

Subject Item: GP 063 Oil/water sep w/closed vent sys and control device subject to NSPS QQQ




What to do Why to do itRecord: (1) If an emission point cannot be repaired or corrected without a processunit shutdown, the expected date of a successful repair shall be recorded.




40 CFR Section 60.697(e)(1)-(4)



03700011 - 006

Facility Name:

Permit Number:

A-71

Subject Item: GP 065 Treatment Processes to meet destruction req. NESH FF

Associated Items: EU 185 OSWTP-Enhanced Biological Treatment Basin 94B3C



What to do Why to do itAll equipment that contains waste subject to NESHAP FF standards must maintainopenings (e.g. hatches, covers, lids, etc.) in a closed, sealed position.

40 CFR Section 61.348(e); 40 CFR Section63.654(a);Minn. R. 7011.9930, subp. E

Maintain compliance with design, equipment, work practice, operational standards. 40 CFR Section 61.12(b); Minn. R. 7011.9900

Control benzene waste streams per 40 CFR Section 61, subp. FF standards andinstall, operate and maintain a treatment process to remove or destroy benzene toless than 10 ppmw.

40 CFR Section 61.348(a); 40 CFR Section61.348(a)(5); 40 CFR Section 61.348(b); 40 CFRSection 63.654(a); Minn. R. 7011.9930, subp. E

The owner or operator of a treatment process or wastewater treatment system unitthat is used to comply with the provisions of this section shall monitor the unit inaccordance with the applicable requirements in 40 CFR Section 61.354.

40 CFR Section 61.348(g); 40 CFR Section 61.354(a);40 CFR Section 61.354(b)(2); 40 CFR Section61.355(g); 40 CFR Section 61.356(b)(6); 40 CFRSection 61.356(i)(4); 40 CFR Section 63.654(a); Minn.R. 7011.9930, subp. E


(1) Annual monitoring shall comply with Method 21 from appendix A of 40 CFR pt.60;
























03700011 - 006

Facility Name:

Permit Number:

A-72

Subject Item: GP 066 VOC Emissions from WWTP

Associated Items: CE 028 Direct Flame Afterburner

CE 029 Direct Flame Afterburner

CE 051 Other

EU 177 OSWTP - Trash Rack & Diversion Box (S1)













EU 200 OSWTP-Equalization Basin 7A

EU 201 OSWTP-Equalization Basin 7B


EU 279 OSWTP-API Oil/Water Separator Mid Bay





EU 290 94V-25D Wemco Corrugated Plate Separators-Post API Flow

EU 291 94V-25E Wemco Corrugated Plate Separators-Post API Flow

EU 292 94V-25F Wemco Corrugated Plate Separators - Spring Lake


EU 314 Oily Sludge Storage Vessel

EU 323 API Separator








What to do Why to do it



03700011 - 006

Facility Name:

Permit Number:

A-73

A. EMISSION LIMIT hdr

Volatile Organic Compounds: less than or equal to 3.42 lbs/hour using 30-dayRolling Average

Title I Condition: Netting Limit for VOC, 40 CFRSection 52.21


VOC Recordkeeping: The Permittee shall record the daily VOC emissions in lb/hr. Title I Condition: Recordkeeping associated withNetting Limit for VOC, 40 CFR Section 52.21

C. REPORTING REQUIREMENT hdr

D. ADDITIONAL REQUIREMENTS hdr

If an instrument reading of 500 ppmv or greater is measured, a leak is detected andthe component does not meet "no detectable emissions".


An owner or operator shall test equipment semi-annually for compliance with nodetectable emissions as required in accordance with the following requirements:




40 CFR Section 61.346(a)(1)(i)&(i)(A); 40 CFR Section61.355(h); 40 CFR Section 61.355 (h)(1)-(4); 40 CFRSection 61.355(h)(4)(i)-(ii); 40 CFR Section61.355(h)(5)-(7); 40 CFR Section 61.356(h); 40 CFRSection 63.654(a); Minn. R. 7011.9930, subp. E




When a leak is detected, repair as soon as practicable. Make first attempt at repairno later than 30 days after the leak is detected. Make final repair as soon aspractical but no later than 180 calendar days after it is detected unless delay ofrepair provisions are invoked. First attempts at repair include, but are not limited to,the best practices described under 40 CFR Section 60.482-7a(e).

40 CFR pt. 63, subps A and CC (most stringent, meetsthe applicable provisions of 40 CFR pt. 60, subps. A,VVa and GGGa; 40 CFR pt. 61, subps. A, J, and V;Clean Fuels Permit (106A-92-I/O-32))

The owner or operator shall submit to the Administrator semiannually a certificationthat all of the required inspections, temperature monitoring, and repairs have beencarried out in accordance with these standards. These reports are due February15 and August 15 of each year.

40 CFR Section 60.698(b)(1); 40 CFR Section60.698(c) for QQQ related components.



03700011 - 006

Facility Name:

Permit Number:

A-74

Subject Item: GP 067 All equipment included in individual drain system, including drains and junction boxes subject to NES

Associated Items: EU 316 FHR Lab Inside

EU 317 FHR Lab Outdoors

FS 001 Unburied Sewer Lines

FS 002 Track 8 Load and Uncontrolled Rail

FS 006 Bottom Loading

FS 018 11-1 Crude Unit


FS 022 12 Vacuum Distillation

FS 024 14-Saturate Plant

FS 027 15-Coker Gasoline


FS 031 17-Fluid Catalytic Cracking (FCC) Unit

FS 032 17-Clarified Oil Vacuum Frac

FS 035 18-1 FCC Gasoline Plant



FS 041 21-1Delayed Coker

FS 042 21-2 Delayed Coker


FS 054 27-Distillate Hydrotreater

FS 060 31 Product Desulfurization

FS 062 32 Powerformer

FS 063 32 Penex

FS 064 32 Aviation Gasoline 0

FS 069 33-Hydrogen Plant No. 1

FS 070 33 Low Pressure Gas/Oil Hydrotreater

FS 075 35 Alkylation

FS 077 36 Dimersol

FS 079 37 Naptha Hydro-Desulfurizer

FS 080 37 Platformer

FS 083 38 High Pressure Gas/Oil Hydrotreater

FS 085 39 Oxy Fuel

FS 087 41 Amine System

FS 088 41 Fuel Gas Liquid Recovery

FS 091 42 Caustic Treating (C3,C4)

FS 093 43 Polymerization

FS 095 45 Sulfur Recovery Unit 3 & 4

FS 096 45 Fuel Gas Treating

FS 099 SWS/Non-Phenolic/Phenolic



03700011 - 006

Facility Name:

Permit Number:

A-75

Associated Items: FS 104 Gas and Distillate Blending

FS 109 84 Flare Gas Recovery

FS 110 North Flare

FS 112 New Flare System and 84-Flare (84Unit1 and 84Unit_1)

FS 119 OSWTP Fugitive Emissions Includes Non-vented Equipment

FS 130 Carbon Canisters & Associated Piping

FS 132 SVE Thermal Oxidizer(86 UNIT3 and 88 UNIT2)


FS 135 44 Penex





40 CFR Section 61.350(a); 40 CFR Section 61.350(b);40 CFR Section 63.654(a); Minn. R. 7011.9930, subp.E



03700011 - 006

Facility Name:

Permit Number:

A-76

Subject Item: GP 068 Type I Drains receiving NESH FF Wastewater and equipped with plugs

Associated Items: FS 018 11-1 Crude Unit


FS 104 Gas and Distillate Blending





Drains must be equipped with a tightly sealed cap or plug. 40 CFR Section 61.346(b)(1); 40 CFR Section63.654(a); Minn. R. 7011.9930, subp. E

Quarterly NESHAP visual inspection: Each drain using tightly fitting cap or plug forcontrol shall be checked by visual or physical inspection quarterly for visual cracksor gaps or other conditions that would reduce the effectiveness controls.

40 CFR Section 61.346(b)(4)(ii); 40 CFR Section61.357(d)(8); 40 CFR Section 63.654(a) Minn. R.7011.9930, subp. E









03700011 - 006

Facility Name:

Permit Number:

A-77

Subject Item: GP 069 Type II Drains subject to NESH FF and also subject to NSPS QQQ

Associated Items: EU 316 FHR Lab Inside

EU 317 FHR Lab Outdoors















FS 048 25-Crude Unit



FS 063 32 Penex





FS 077 36 Dimersol

FS 085 39 Oxy Fuel











FS 135 44 Penex




03700011 - 006

Facility Name:

Permit Number:

A-78



Drains must be equipped with water seal controls or a tightly sealed cap or plug. 40 CFR Section 61.346(b)(1); 40 CFR Section63.654(a); Minn. R. 7011.9930, subp. E

Conduct monthly NESHAP visual inspection of water seal drains for indication oflow water levels or other conditions that would reduce effectiveness.

2001 Consent Order 71(a); 40 CFR Section61.346(b)(4); 40 CFR Section 63.654(a); Minn. R.7011.9930, subp. E







03700011 - 006

Facility Name:

Permit Number:

A-79

Subject Item: GP 071 Type I Drains subject to NSPS QQQ (sealed w/plug)

Associated Items: FS 045 23- Delayed Coker & Gasoline Plant


FS 052 26-Sulfur Recovery Unit SRU 5, TGTU 2

FS 055 27- Hydrogen Plant No. 2

FS 058 28-Naphtha Hydrotreater

FS 085 39 Oxy Fuel

FS 102 47 H2 Recovery Gas




FS 135 44 Penex

What to do Why to do itEach Type I drain must be tightly capped when not in use. 40 CFR Section 60.692-2(a)(4); Minn. R. 7011.1435,

subp. CInspect: Conduct semi-annual visually inspect capped or plugged (Type I) drains.Inspect to ensure caps or plugs are in place and properly installed.

40 CFR Section 60.692-2(a)(4); Minn. R. 7011.1435,subp. C

Repair: Delay of repair of facilities that are subject to the provisions of this subpartwill be allowed if the repair is technically impossible without a complete or partialrefinery or process unit shutdown.

Repair of such equipment shall occur before the end of the next refinery or processunit shutdown.

40 CFR Section 60.692-6(a); 40 CFR Section60.692-6(b); Minn. R. 7011.1435, subp. C

Repairs: Whenever missing or improperly installed caps or plugs are identified, firstefforts at repair shall be made as soon as practicable.


Record: For individual drain systems, the location, date, and corrective action shallbe recorded for each drain when the water seal is dry or otherwise breached, whena drain cap or plug is missing or improperly installed, or other problem is identifiedthat could result in VOC emissions, as determined during the periodic visual orphysical inspection.

40 CFR Section 60.697(b)(1); Minn. R. 7011.1435,subp. C

Record: A copy of the design specifications for all equipment shall be kept for thelife of the source in a readily accessible location.

The following information pertaining to the design specifications shall be kept.

(i) Detailed schematics, and piping and instrumentation diagrams and

(ii) The dates and descriptions of any changes in the design specifications.

40 CFR Section 60.697(f)(1)-(2); 40 CFR Section60.697(f)(2)(i)-(ii); Minn. R. 7011.1435, subp. C

Recordkeeping: (1) If an emission point cannot be repaired or corrected without aprocess unit shutdown, the expected date of a successful repair shall be recorded.

(2) The reason for the delay shall be recorded if an emission point or equipmentproblem is not repaired or corrected in the specified amount of time;



40 CFR Section 60.697(e)(1)-(4)

The owner or operator shall submit to the Administrator semiannually a certificationthat all of the required inspections have been carried out in accordance with thesestandards.

40 CFR Section 60.698(b)(1); 40 CFR Section60.698(c)



03700011 - 006

Facility Name:

Permit Number:

A-80

Subject Item: GP 072 Type II Drains subject to NSPS QQQ active (water seal)

Associated Items: FS 048 25-Crude Unit





FS 106 71 Process Steam Boilers




FS 135 44 Penex

What to do Why to do itFor drains with a water seal at the junction box, flush water to the affected junctionbox via any listed drain cup to verify a water seal.

40 CFR Section 60.692-2(a)(2); 40 CFR Section60.692-2(a)(5)

Inspect: Visually inspect H2O sealed (Type II) drains in active service. Inspectmonthly for indications of low water levels, cracks, gaps, or leaks that could resultin VOC emissions or in lieu of inspection, add water to the cup.





Repairs: Whenever low water levels or missing or improperly installed caps orplugs are identified, water shall be added or first efforts at repair shall be made assoon as practicable, but not later than 24 hours after detection.


Records: For individual drain systems; the location, date, and corrective actionshall be recorded for each drain when the water seal is dry or otherwise breached,when a drain cap or plug is missing or improperly installed, or other problem isidentified that could result in VOC emissions, as determined during the initial andperiodic visual or physical inspection.


Record: (1) A copy of the design specifications for all equipment used to complywith the provisions of this subpart shall be kept for the life of the source in a readilyaccessible location.

(2) The following information pertaining to the design specifications shall be kept.

(i) Detailed schematics, and piping and instrumentation diagrams.







03700011 - 006

Facility Name:

Permit Number:

A-81

Subject Item: GP 075 Type II Drains subject to NSPS inactive (water seal)










What to do Why to do itInspect: Visually inspect H2O sealed (Type II) drains out of active service. Weeklyinspect for indications of low water levels or other problems that could result inVOC emissions.

40 CFR Section 60.692-2(a)(3)




Record: (1) A copy of the design specifications for all equipment used to complywith the provisions of this subpart shall be kept for the life of the source in a readilyaccessible location.









03700011 - 006

Facility Name:

Permit Number:

A-82

Subject Item: GP 076 Junction Boxes subject to NESH FF when equipped with carbon canisters















FS 063 32 Penex




FS 077 36 Dimersol

FS 085 39 Oxy Fuel











Install, operate and maintain a cover and closed vent system that routes all organicvapors vented from the waste management until to a control device.

40 CFR Section 61.346(a)(1); 40 CFR Section61.346(a)(1)(i); 40 CFR Section 63.654(a); Minn. R.7011.9930, subp. E





40 CFR Section 61.346(a)(1)(i)&(i)(A); 40 CFR Section61.355(h); 40 CFR Section 61.355 (h)(1)-(4); 40 CFRSection 61.355(h)(4)(i)-(ii); 40 CFR Section61.355(h)(5)-(7); 40 CFR Section61.356(h); 40 CFRSection 63.654(a); Minn. R. 7011.9930, subp. E



03700011 - 006

Facility Name:

Permit Number:

A-83

(4) Calibration gases shall be:






CONTINUED40 CFR Section 61.346(a)(1); 40 CFR Section61.355(h); 40 CFR Section 61.355 (h)(1)-(4); 40 CFRSection 61.355(h)(4)(i)-(ii); 40 CFR Section61.355(h)(5)-(7); 40 CFR Section61.356(h); 40 CFRSection 63.654(a); Minn. R. 7011.9930, subp. E

Quarterly NESHAP visual inspection: Each drain using water seal controls shall bechecked by visual or physical inspection quarterly for indications of low water levelsor other conditions that would reduce the effectiveness of water seal controls.

40 CFR Section 61.346(a)(2); 40 CFR Section61.346(b)(4)(iii); 40 CFR Section 61.356(g); 40 CFRSection 61.357(d)(8); 40 CFR Section 63.654(a); Minn.R. 7011.9930, subp. E





40 CFR Section 61.346(a)(3); 40 CFR Section61.346(b)(5); 40 CFR Section 61.357(d)(8); 40 CFRSection 63.654(a); Minn. R. 7011.9930, subp. E

Records: An owner or operator shall maintain a record for each visual inspectionthat identifies a problem (such as a broken seal, gap or other problem) which couldresult in benzene emissions. The record shall include the date of the inspection,waste management unit and control equipment location where the problem isidentified, a description of the problem, a description of the corrective action taken,and the date the corrective action was completed.

40 CFR Section 61.356(g)-(h); 40 CFR Section63.654(a); Minn. R. 7011.9930, subp. E

Records: An owner or operator shall maintain a record for each test of nodetectable emissions. The record shall include the following information: date thetest is performed, background level measured during test, and maximumconcentration indicated by the instrument reading measured for each potential leakinterface. If detectable emissions are measured at a leak interface, then the recordshall also include the waste management unit, control equipment, and leakinterface location where detectable emissions were measured, a description of theproblem, a description of the corrective action taken, and the date the correctiveaction was completed.

CONTINUED40 CFR Section 61.356(g)-(h); 40 CFR Section63.654(a); Minn. R. 7011.9930, subp. E





03700011 - 006

Facility Name:

Permit Number:

A-84

Subject Item: GP 077 Junction Boxes receiving Wastewater from NSPS QQQ Units not subject to NESHAPs FF










What to do Why to do itJunction box covers shall have a tight seal around the edge and shall be kept inplace at all times, except during inspection and maintenance.

40 CFR Section 60.692-2(b)(2); Minn. R. 7011.1435,subp. C

Junction boxes shall be equipped with a cover and may have an open vent pipe.The vent pipe shall be at least 90 cm (3 ft) in length and shall not exceed 10.2 cm(4 in) in diameter.


Junction boxes shall be visually inspected semiannually thereafter to ensure thatthe cover is in place and to ensure that the cover has a tight seal around the edge.


Delayed Repairs: Delay of repair of facilities that are subject to the provisions ofthis subpart will be allowed if the repair is technically impossible without a completeor partial refinery or process unit shutdown.



Repair junction boxes: If a broken seal or gap is identified, first effort at repair shallbe made as soon as practicable, but not later than 15 calendar days after thebroken seal or gap is identified.


Record information from drain inspections. Minn. R. 7011.1435, subp. C

Record: For junction boxes; the location, date, and corrective action shall berecorded for inspections when a broken seal, gap, or other problem is identifiedthat could result in VOC emissions.


Recordkeeping: (1) A copy of the design specifications for all equipment used tocomply with the provisions of this subpart shall be kept for the life of the source in areadily accessible location.





Recordkeeping: (1) If an emission point cannot be repaired or corrected without aprocess unit shutdown, the expected date of a successful repair shall be recorded.

(2) The reason for the delay shall be recorded if an emission point or equipmentproblem is not repaired or corrected in the specified amount of time;



40 CFR Section 60.697(e)(1)-(4)





03700011 - 006

Facility Name:

Permit Number:

A-85

Subject Item: GP 079 Non-contact Cooling Water Drains

Associated Items: EU 319 Non Contact Cooling Water Drains

What to do Why to do itRecord: For non-contact cooling water systems subject to the exclusion, an owneror operator shall keep for the life of the facility in a readily accessible location, plansor specifications which demonstrate that the cooling water does not contacthydrocarbons or oily wastewater and is not recirculated through a cooling tower.

40 CFR Section 60.697(j)



03700011 - 006

Facility Name:

Permit Number:

A-86

Subject Item: GP 080 Stormwater Sewers

Associated Items: EU 320 Storm Sewers

What to do Why to do itRecord: For stormwater sewer systems subject to the exclusion in 40 CFR Section60.692-1(d)(1), an owner or operator shall keep for the life of the facility in a readilyaccessible location, plans or specifications which demonstrate that ancillaryequipment does not come in contact with or store oily wastewater.

40 CFR Section 60.697(h)



03700011 - 006

Facility Name:

Permit Number:

A-87

Subject Item: GP 081 Fugitive Compressors Exempt from LDAR Requirements

Associated Items: FS 054 27-Distillate Hydrotreater











What to do Why to do itCompressors in hydrogen service are exempt from LDAR monitoring and repairrequirements, if an owner or operator demonstrates that a compressor is inhydrogen service.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section60.593a(b)(1)

When an owner or operator and the Administrator do not agree on whether a pieceof equipment is in hydrogen service, the procedures in paragraph 40 CFR Section60.593a(b)(2) shall be used to resolve the disagreement.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGG; 40 CFR pt. 61, subps. A, J andV; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section60.593a(b)(2)

Each compressor is presumed not to be in hydrogen service unless an owner oroperator demonstrates that the piece of equipment is in hydrogen service.


For a piece of equipment to be considered in hydrogen service, it must bedetermined that the percentage hydrogen content can be reasonably expectedalways to exceed 50 percent by volume.


For purposes of determining the percentage hydrogen content in the process fluidthat is contained in or contacts a compressor, the owner or operator shall use eitherprocedures that conform to those specified in 40 CFR Section 60.593a(b)(2) orengineering judgment provided the engineering judgment demonstrates that thecontent clearly exceeds 50 percent by volume.


Components that are integral to the compressor, are considered part of thecompressor, and thus exempt from LDAR monitoring and repair requirements if thecompressor is in hydrogen service.


Any existing reciprocating compressors are exempt from seal requirements, whichis, paragraphs (a) through (e) and (h) of 60.482-3a. Provided the owner or operatordemonstrates that recasting the distance piece or replacing the compressor are theonly options available to bring the compressor into compliance.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32));40 CFR Section 60.482-3a(j)



03700011 - 006

Facility Name:

Permit Number:

A-88

Subject Item: GP 082 Fugitive Compressors LDAR Requirements

Associated Items: FS 006 Bottom Loading




















FS 128 88-Butane

What to do Why to do itEach compressor that is not exempt from LDAR requirements in GP 081, FugitiveCompressors Exempt from LDAR Requirements must meet the requirements in GP090, Fugitive LDAR Equipment Designated Non-detectable.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32))

If leak repair requires the shutdown of a compressor and no permanent spare isavailable, then criteria for partial unit shutdown is met, and delay of repair isallowed.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section60.482-9a(a)

Include in the semi-annual LDAR Report: Number of compressors for which leakswere detected.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section60.487a(c)(2)(v)

Include in the semi-annual LDAR Report: Number of compressors for which leakswere not repaired within 15 calendar days or put on the delay of repair list.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section60.487a(c)(2)(vi)



03700011 - 006

Facility Name:

Permit Number:

A-89

Subject Item: GP 087 Fugitive LDAR All Equipment in VOC or HAP Service

Associated Items: FS 002 Track 8 Load and Uncontrolled Rail


FS 008 Top Loading and UC Top Loading



















FS 056 27-5 Hydrogen Plant No. 3




FS 063 32 Penex





FS 077 36 Dimersol




FS 085 39 Oxy Fuel







03700011 - 006

Facility Name:

Permit Number:

A-90

Associated Items: FS 095 45 Sulfur Recovery Unit 3 & 4







FS 110 North Flare


FS 117 All Tankage (including line pumps) 52Unit 2; 61Unit2, 86Unit2 &102Unit2


FS 128 88-Butane





FS 135 44 Penex

What to do Why to do itRegulated equipment in VOC or organic HAP service (>10 wt% VOC per 40 CFRSection 60.481a or >5 wt% organic HAPs listed in Table 1 of 40 CFR Section pt.63, subp. CC) must comply with the leak detection and repair (LDAR) provisions ofthis permit. Compliance with these provisions constitutes full and completecompliance with otherwise applicable requirements of 40 CFR pt. 60, subps. A andGGGa; 40 CFR pt. 61, subps. A, J, and V; 40 CFR pt. 63, subps. A and CC; theLDAR provisions of the 2001 Consent Order (U.S. v. Koch Petroleum Group, Courtfile No. 00-CCU-2756, U.S. Dist of MN); Clean Fuels Permit 106A-92-I/O-32; andrelated Minnesota rules.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, J,and V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32))

LDAR programs shall be implemented refinery-wide, including all componentswithin all contiguous areas that are owned and maintained by the refinery. Asreferenced in this Section, "components" shall mean applicable regulatedequipment as defined in 40 CFR pt. 60, subp. GGGa, and 40 CFR pt. 63, subp.CC, except that components located outside of process unit boundaries shall notbe excluded from applicability by using the definition of "process unit".

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section 60.481a

The owner or operator shall have the option of monitoring all components within aprocess unit within 30 days after the startup of the process unit after the turnaroundwithout having the results of the monitoring used in the leak rate determination.


The owner or operator shall calculate percent leaking valves on a process unit byprocess unit basis. This rate is used to determine monitoring frequency.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section 60.483-1a;40 CFR Section 60.483-2a

When a leak is detected, repair as soon as practicable. Make first attempt at repairno later than 5 days after the leak is detected. Make final repair and monitoring assoon as practical but no later than 15 calendar days after it is detected unless delayof repair provisions are invoked. First attempts at repair include, but are not limitedto, the best practices described under 40 CFR Section 60.482-7a(e).

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Sections60.482-2a(c); 60.482-3a(g); 60.482-7a(d);60.482-8a(c); 60.482-10a(g); 60.482-11a(d)



03700011 - 006

Facility Name:

Permit Number:

A-91

Delay of repair allowed. Repair must typically be completed before the end of thenext process unit shutdown and the following criteria must be met: Delay of repairof equipment will be allowed for equipment which is isolated from the process andwhich does not remain in VOC service. Delay of repair beyond a process unitshutdown will be allowed for a valve, if valve assembly replacement is necessaryduring the process unit shutdown, valve assembly supplies have been depleted,and valve assembly supplies had been sufficiently stocked before the supplieswere depleted. Delay of repair beyond the next process unit shutdown will not beallowed unless the next process unit shutdown occurs sooner than 6 months afterthe first process unit shutdown.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section 60.482-9a

Tag leaking equipment.(1) A weatherproof and readily visible identification, marked with the equipmentidentification number, shall be attached to the leaking equipment.(2) The identification on non-valve equipment may be removed after it has beenrepaired. The identification on a valve may be removed after it has been monitoredfor 2 successive months as specified in 40 CFR Section 60.482-7a(c) and no leakhas been detected during those 2 months.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section 60.486a(b)

Record date, tag number, and leak data when a leak is detected. When each leakis detected as specified in 40 CFR Section 60.482-2a, 40 CFR Section 60.482-3a,40 CFR Section 60.482-7a, 40 CFR Section 60.482-8a, 40 CFR Section60.482-11a, 40 CFR Section 60.483-2a, the following information shall be recordedin a log and shall be kept for 2 years in a readily accessible location:(1) The instrument and operator identification numbers and the equipmentidentification number, except when indications of liquids dripping from a pump aredesignated as a leak.(2) The date the leak was detected and the dates of each attempt to repair the leak.(3) Repair methods applied in each attempt to repair the leak.(4) Maximum instrument reading measured by Method 21 of appendix A�7 of thispart at the time the leak is successfully repaired or determined to be nonrepairable,except when a pump is repaired by eliminating indications of liquids dripping.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section 60.486a(c)

(5) "Repair delayed" and the reason for the delay if a leak is not repaired within 15calendar days after discovery of the leak.(6) The signature of the owner or operator (or designate) whose decision it was thatrepair could not be effected without a process shutdown.(7) The expected date of successful repair of the leak if a leak is not repaired within15 days.(8) Dates of process shutdown that occur while the equipment is unrepaired.(9) The date of successful repair of the leak.

CONTINUED40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section 60.486a(c)

Document applicability determination for all LDAR equipment. The owner oroperator shall demonstrate that a piece of equipment is in light liquid service byshowing that all the following conditions apply:(1) The vapor pressure of one or more of the organic components is greater than0.3 kPa at 20 Celsius, Standard reference texts or ASTM D-2879 (incorporated byreference -- see 40 CFR Section 60.17) shall be used to determine the vaporpressures.(2) The total concentration of the pure organic components having a vaporpressure greater than 0.3 kPa at 20 Celsius is equal to or greater than 20 percentby weight.(3) The fluid is a liquid at operating conditions.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section 60.485a(e)

Document applicability determination for all LDAR equipment.Include (1) the dates of each required initial compliance test as required in 40 CFRSection 60.482-2a(e), 40 CFR Section 60.482-3a(i), 40 CFR Section 60.482-4a,and 40 CFR Section 60.482-7a(f);(2) The background level measured during each compliance test; and(3) The maximum instrument reading measured at the equipment during eachcompliance test.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section60.486a(e)(4)

Report: Provide a listing of those units that became subject to more frequentmonitoring for valves during the reporting interval.




03700011 - 006

Facility Name:

Permit Number:

A-92

Submit semi-annual LDAR Report to the Administrator beginning six months afterthe initial startup date and due 30 days after reporting period thereafter. Allsemi-annual reports to the Administrator shall include the following information,summarized from the information in 40 CFR Section 60.486a:(1) Process unit identification.(2) For each month during the semi-annual reporting period:(i) Number of valves for which leaks were detected as described in 40 CFR Section60.482-7a(b) or 40 CFR Section 60.483-2a;(ii) Number of valves for which leaks were not repaired as required in 40 CFR60.482-7a(d)(1);(iii) Number of pumps for which leaks were detected as described in 40 CFR60.482-2a(b), (d)(4)(ii)(A) or (B), or (d)(5)(iii)(iv) Number of pumps for which leaks were not repaired as required in 40 CFRSection 60.482-2a(c)(1) and 40 CFR Section 60.482-2a(d)(6);(v) Number of compressors for which leaks were detected as described in 40 CFRSection 60.482-3a(f);


(vi) Number of compressors for which leaks were not repaired as required in 40CFR Section 60.482-3a(g)(1); and(ix) The facts that explain each delay of repair and, where appropriate, why aprocess unit shutdown was technically infeasible.

(3) Dates of process unit shutdowns which occurred within the semi-annualreporting period.(4) Revisions to items reported in the initial report.

Also include frequency of monitoring for process units utilizing skip periodmonitoring. Include the results of all performance tests in accordance with 40 CFRSection 60.8 of the General Provisions. The provisions of 40 CFR Section 60.8(d)do not apply to affected facilities subject to the provisions of this subpart exceptthat an owner or operator must notify the Administrator of the schedule for the initialperformance tests at least 30 days before the initial performance tests.

CONTINUED40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section 60.487a(c)

Fugitive sources under FS117, FS128, and FS132 include storage tanks and areconsidered separate process units under the consolidated LDAR programimplemented consistent with the Consent Decree, the Clean Fuels permit, andstate/federal regulations. Any storage tank system components must either beincluded in these FSs or other s as referenced in 40 CFR 60.482-1a(g).

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section 60.481a; 40CFR Section 60.482-1a(g); 40 CFR Section 60.591a

Monitoring to verify repair on delay-of-repair equipment must occur within 15 daysafter startup of the process unit.


Use calibration gases and follow test methods and procedures as referenced in 40CFR Section 60.458a(b)

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section 60.485a(b)

Comply with recordkeeping requirements for equipment calibrations and monitoringevents as referenced in 40 CFR Section 60.486a(a)(3) (i.e. instrument, equipment,operator, date, and reading), 40 CFR Section 60.486a(c) (i.e. equipment, operator,date of leak and repair, repair method, max reading, reason for delay, signature,date of repair and unit shutdown), 40 CFR Section 60.486(e)(7) (i.e. weekly visualpump inspection) , 40 CFR Section 60.486a(e)(10) (i.e. releases from PSVs), and40 CFR Section 60.486(e)(8) (i.e. instrument calibrations)

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Sections60.486a(a)(3); 60.486a(c); 60.486a(e)(8);60.486a(c)(4); 60.486a(e)(7); 60.486a(e)(10)



03700011 - 006

Facility Name:

Permit Number:

A-93

Subject Item: GP 088 Fugitive LDAR in Vacuum Service








What to do Why to do itA list of identification numbers for equipment in vacuum service shall be recordedin a log or database that is kept in a readily accessible location.




03700011 - 006

Facility Name:

Permit Number:

A-94

Subject Item: GP 089 Fugitive LDAR Emission Sources not in VOC or HAP Service

What to do Why to do itInformation and data used to demonstrate that a piece of equipment is not in VOCservice shall be recorded in a log or database that is kept in a readily accessiblelocation.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section60.486a(i)(3)



03700011 - 006

Facility Name:

Permit Number:

A-95

Subject Item: GP 090 Fugitive LDAR Equipment Designated Non-detectable emissions (NDE)


























FS 063 32 Penex





FS 077 36 Dimersol




FS 085 39 Oxy Fuel







03700011 - 006

Facility Name:

Permit Number:

A-96








FS 110 North Flare




FS 128 88-Butane





FS 135 44 Penex

What to do Why to do itIf an instrument reading of 500 ppm or greater is measured, a leak is detected. If aleak is detected, then follow the repair requirements in GP 087.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section60.482-2a(e); 40 CFR Section 60.482-3a(i); 40 CFRSection 60.482-7a(f)

Pumps designated for no detectable emissions must meet specifications: Anypump that is designated for no detectable emission is exempt from barrier systemrequirements if the pump:(1) Has no externally actuated shaft penetrating the pump housing.(2) Is demonstrated to be operating with no detectable emissions as indicated byan instrument reading of less than 500 ppm above background as measured byMethod 21.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section60.482-2a(e)

Compressors designated for no detectable emissions must meet specifications.The compressor must be demonstrated to be operating with no detectableemissions, as indicated by an instrument reading of less than 500 ppm abovebackground, as measured by Method 21.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section 60.482-3a(i)

Valves designated for no detectable emissions must meet specifications: The valvemust:(1) Have no external actuating mechanism in contact with the process fluid.(2) Be operated with emissions less than 500 ppm above background asdetermined by Method 21.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section 60.482-7a(f)

Measure for detectable emissions using Method 21. Test for compliance with 40CFR Section 60.482-7a(f)(2) initially upon designation, annually, and at other timesrequested by the Administrator. The owner or operator shall determine compliancewith the no detectable emission standards in 40 CFR Section 60.482-2a(e), 40CFR Section 60.482-3a(i), 40 CFR Section 60.482-4a, 40 CFR Section60.482-7a(f), and 40 CFR Section 60.482-10a(e) as follows:(1) The requirements of 40 CFR Section 60.482-7a(b) shall apply.(2) Method 21 shall be used to determine the background level. All potential leakinterfaces shall be traversed as close to the interface as possible. The arithmeticdifference between the maximum concentration indicates by the instrument and thebackground level is compared with 500 ppm for determining compliance.




03700011 - 006

Facility Name:

Permit Number:

A-97

Measure for detectable emissions upon Administrator's request. 40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section60.482-2a(e); 40 CFR Section 60.482-3a(i); 40 CFRSection 60.482-7a(f)

Document applicability determination for all LDAR equipment in light liquid service.Include a list of identification numbers for equipment that are designated for nodetectable emissions.




03700011 - 006

Facility Name:

Permit Number:

A-98

Subject Item: GP 091 Fugitive LDAR Open-ended Lines


























FS 063 32 Penex





FS 077 36 Dimersol




FS 085 39 Oxy Fuel







03700011 - 006

Facility Name:

Permit Number:

A-99








FS 110 North Flare




FS 128 88-Butane





FS 135 44 Penex

What to do Why to do itWith the exception of asphalt lines, open-ended lines must be sealed by a cap,blind flange, plug or second valve at all times except during operations requiringflow through the line. Open-ended valves or lines containing materials which wouldautocatalytically polymerize or would present an explosion, serious overpressure,or other safety hazard if capped or equipped with a double block and bleed systemas specified in paragraphs (a) through (c) of this section are exempt from therequirements of paragraphs (a) through (c) of this section. (a)(1) Each open-endedvalve or line shall be equipped with a cap, blind flange, plug, or a second valve,except as provided in 40 CFR Section 60.482-1a(c), 40 CFR Section 60.482-6a(d),and 40 CFR Section 60.482-6a(e)

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section 60.482-6a;40 CFR Section 60.593a(f)

(2) The cap, blind flange, or second valve shall seal the open end at all timesexcept during operations requiring fluid flow through the open-ended valve or line.(b) Each open-ended valve or line equipped with a second valve shall be operatedin a manner such that the valve on the process fluid end is closed before thesecond valve is closed. (c) When a double block-and-bleed system is being used,the bleed valve or line may remain open during operations that require venting theline between the block valves but shall comply with paragraph (a) of this section atall other times.


A leak is detected if an open-ended line is found and not immediately repaired. If aleak is detected, then follow the repair requirements in GP 087.


Coker Units: The langauage proposed included with the LDAR provisions in thispermit would establish a compliance plan to allow for a delay of repair provision forany open-ended lines that would otherwise require significant process changes or ashutdown to fix

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section 60.593a(f)



03700011 - 006

Facility Name:

Permit Number:

A-100

Subject Item: GP 093 Fugitive LDAR PSV to Atmosphere




















FS 063 32 Penex



FS 077 36 Dimersol




FS 085 39 Oxy Fuel












03700011 - 006

Facility Name:

Permit Number:

A-101

After each pressure release, the pressure relief device shall be returned to acondition of no detectable emissions, as indicated by an instrument reading of lessthan 500 ppm above background, as soon as practicable, but no later than 5calendar days after the pressure release, except as provided in 40 CFR 60.482-9a.No later than 5 calendar days after the pressure release, the pressure relief deviceshall be monitored to confirm the conditions of no detectable emissions, asindicated by an instrument reading of less than 500 ppm above background, usingMethod 21 per the requirements stated in GP 090.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section60.482-4a(b)

Document applicability determination for all LDAR pressure relief devices. Include alist of equipment identification numbers for pressure relief devices subject to LDARprovisions.




03700011 - 006

Facility Name:

Permit Number:

A-102

Subject Item: GP 094 Fugitive LDAR PSV with Upstream Rupture Disks







FS 077 36 Dimersol



What to do Why to do itPer 40 CFR Section 60.482-4a(d)(2) after each pressure release, a new rupturedisk shall be installed upstream of the pressure relief device as soon aspracticable, but no later than 5 calendar days after each pressure release, exceptas provided in 40 CFR Section 60.482-9a.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section60.482-4a(d)(2)



03700011 - 006

Facility Name:

Permit Number:

A-103

Subject Item: GP 095 Fugitive LDAR Pumps In Heavy Liquid Service


























FS 063 32 Penex





FS 077 36 Dimersol




FS 085 39 Oxy Fuel







03700011 - 006

Facility Name:

Permit Number:

A-104








FS 110 North Flare




FS 128 88-Butane





FS 135 44 Penex

What to do Why to do itIf an instrument reading of 1,000 ppm or greater is measured, a leak is detected. 40 CFR pt. 70 (consolidated LDAR requirements

based on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32))

If evidence of a potential leak is found by visual, audible, olfactory, or any otherdetection method at pumps, valves, and connectors in heavy liquid service andpressure relief devices in light liquid or heavy liquid service, the owner or operatorshall follow either one of the following procedures:

(1) The owner or operator shall monitor the equipment within 5 days by the methodspecified in 40 CFR Section 60.485a(b) and shall comply with the requirements ofparagraphs (b) through (d) of this section.

(2) The owner or operator shall eliminate the visual, audible, olfactory, or otherindication of a potential leak within 5 calendar days of detection.




03700011 - 006

Facility Name:

Permit Number:

A-105

Subject Item: GP 096 Fugitive LDAR Light Liquid Pumps


























FS 063 32 Penex





FS 077 36 Dimersol




FS 085 39 Oxy Fuel







03700011 - 006

Facility Name:

Permit Number:

A-106








FS 110 North Flare




FS 128 88-Butane




FS 135 44 Penex

What to do Why to do itMonitor pumps for leaks using Method 21. If an instrument reading of 1000 ppm orgreater is measured, a leak is detected.


Weekly visually inspect pumps for indications of liquids dripping from the pumpseal. If there are indications of liquids dripping from the pump seal, either:(i) Monitor the pump within 5 days using Method 21 to determine whether a leak isdetected, or

(ii) Designate the visual indications of liquids dripping as a leak, and repair the leakusing either the procedures in 40 CFR Section 60.482-2a(c) or by eliminating thevisual indications of liquids dripping.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section60.482-2a(b)(2)

Reciprocating pumps in light liquid service are exempt from LDAR monitoring andrepair requirements if recasting the distance piece or replacing the reciprocatingpump is required to meet the standards.


Maintain a written plan that requires monitoring of the pump as frequently aspracticable during safe-to-monitor times but not more frequently than the periodicmonitoring schedule otherwise applicable, and repair of the equipment if a leak isdetected.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section60.482-2a(g)(2)

Monitor unsafe-to-monitor pumps per the written inspection plan. No plan isrequired if no components are on the unsafe-to-monitor list. Plan must requiremonitoring of the pump as frequently as practicable during safe-to-monitor timesbut not more frequently than the periodic monitoring schedule otherwise applicable,and repair of the pump if a leak is detected.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section 60.485a(f);40 CFR Section 60.482-2a(g)(2)

Delay of repair allowed. Repair must typically be completed before the end of thenext process unit shutdown and the following criteria must be met:

(1) Repair requires the use of dual mechanical seal system that includes a barrierfluid system, and

(2) Repair is completed as soon as practicable, but not later than 6 months after theleak was detected.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section60.482-9a(d)



03700011 - 006

Facility Name:

Permit Number:

A-107

A pump that begins operation in light liquid service after the initial startup date forthe process unit must be monitored for the first time within 30 days after the end ofits startup period, except for a pump that replaces a leaking pump.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section60.482-2a(a)(1)



03700011 - 006

Facility Name:

Permit Number:

A-108

Subject Item: GP 099 Fugitive LDAR Sample Stations


























FS 063 32 Penex





FS 077 36 Dimersol




FS 085 39 Oxy Fuel







03700011 - 006

Facility Name:

Permit Number:

A-109








FS 110 North Flare




FS 128 88-Butane




FS 135 44 Penex

What to do Why to do itSampling systems, as defined in 40 CFR Section 60.481a, except in situ samplingsystems and sampling systems without purges, in VOC or HAP service shall beequipped with a closed-purged, closed-loop, or a closed-vent system. Eachclosed-purge, closed-loop, or closed-vent system shall comply with one of thefollowing requirements:(1) Gases displaced during filling of the sample container are not required to becollected or captured.(2) Containers that are part of a closed-purge system must be covered or closedwhen not being filled or emptied.(3) Gases remaining in the tubing or piping between the closed-purge systemvalve(s) and sample container valve(s) after the valves are closed and the samplecontainer is disconnected are not required to be collected or captured.(4) Each closed-purge, closed-loop, or closed-vent system shall be designed andoperated to:


(i) Return the purged process fluid directly to the process line.(ii) Collect and recycle the purged process fluid to a process.(iii) Capture and transport all the purged process fluid to a control device thatcomplies with the requirements of 40 CFR Section 60.482�10a.(iv) Collect, store, and transport the purged process fluid to any of the followingsystems or facilities:(A) A waste management unit as defined in 40 CFR 63.111, if the wastemanagement unit is subject to and operated in compliance with the provisions of 40CFR part 63, subpart G, applicable to Group 1 wastewater streams;

CONTINUED: 40 CFR pt. 70 (consolidated LDARrequirements based on various applicable provisionsof 40 CFR pt. 60, subps. A and GGGa; 40 CFR pt. 61,subps. A, J and V; 40 CFR pt. 63, subps. A and CC;Clean Fuels Permit (106A-92-I/O-32)); 40 CFR Section60.482-5a

(B) A treatment, storage, or disposal facility subject to regulation under 40 CFR part262, 264, 265, or 266;(C) A facility permitted, licensed, or registered by a state to manage municipal orindustrial solid waste, if the process fluids are not hazardous waste as defined in 40CFR part 261;(D) A waste management unit subject to and operated in compliance with thetreatment requirements of 40 CFR 61.348(a), provided all waste management unitsthat collect, store, or transport the purged process fluid to the treatment unit aresubject to and operated in compliance with the management requirements of 40CFR 61.343 through 40 CFR 61.347; or(E) A device used to burn off-specification used oil for energy recovery inaccordance with 40 CFR part 279, subpart G, provided the purged process fluid isnot hazardous waste as defined in 40 CFR part 261.




03700011 - 006

Facility Name:

Permit Number:

A-110

Subject Item: GP 100 Fugitive LDAR Heavy Liquid Valves


























FS 063 32 Penex





FS 077 36 Dimersol




FS 085 39 Oxy Fuel







03700011 - 006

Facility Name:

Permit Number:

A-111








FS 110 North Flare




FS 128 88-Butane





FS 135 44 Penex









03700011 - 006

Facility Name:

Permit Number:

A-112

Subject Item: GP 101 Fugitive LDAR Valves in Light Liquid Service


























FS 063 32 Penex





FS 077 36 Dimersol




FS 085 39 Oxy Fuel







03700011 - 006

Facility Name:

Permit Number:

A-113








FS 110 North Flare




FS 128 88-Butane





FS 135 44 Penex


40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)) 40 CFR Section 60.482-7a(b)

Sustainable skip period monitoring: At process units that have less then 2 percentleaking valves for 2 consecutive months, owner or operator shall monitor eachvalve once every calendar quarter, beginning with the next quarter.

40 CFR pt. 70 (consolidated LDAR requirementsbased on the Consent Decree, various applicableprovisions of 40 CFR pt. 60, subps. A and GGGa; 40CFR pt. 61, subps. A, J and V; 40 CFR pt. 63, subps.A and CC; Clean Fuels Permit (106A-92-I/O-32))

Sustainable skip period monitoring: At process units that have less than or equal to1 percent leaking valves for 2 consecutive quarters, owner or operator may elect tomonitor each valve once every 2 calendar quarters.


Sustainable skip period monitoring: At process units that have less than or equal to0.5 percent leaking valves for 3 consecutive calendar semi-annual periods, owneror operator may elect to monitor each valve once every 4 calendar quarters.


Sustainable skip period monitoring: At process units on a calendar quarterly,semiannual, or annual monitoring schedule that have greater than or equal to 2percent leaking valves in any single detection period, the owner or operator shallmonitor each valve no less than every month, but can once again elect to advanceto less frequent monitoring pursuant to the schedule above.


Sustainable skip period monitoring: At process units on a calendar semi-annual orannual monitoring schedule that have greater than or equal to 1 percent but lessthan 2 percent leaking valves in any single detection period, the owner or operatorshall monitor each valve no less than every calendar quarter, but can again elect toadvance to less frequent monitoring pursuant to the schedule above.


Sustainable skip period monitoring: At process units on a calendar annualmonitoring schedule that have greater than or equal to 0.5 percent but less than 1percent leaking valves in any single detection period, the owner or operator shallmonitor each valve no less than semi-annually, but can again elect to advance toless frequent monitoring pursuant to the schedule above.




03700011 - 006

Facility Name:

Permit Number:

A-114

Monitor difficult-to-monitor valves once per calendar year using Method 21. A valvemay be designated as difficult-to-monitor if the owner or operator of the valvedemonstrates that the valve cannot be monitored without elevating the monitoringpersonnel more than 2 meters above a support surface.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section60.482-7a(h)

Document applicability determination for all LDAR difficult-to-monitor valves.Document the following information: A list of identification numbers for valves thatare designated as difficult-to-monitor, an explanation for each valve stating why thevalve is difficult-to-monitor.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section60.486a(f)(2)

Monitor unsafe-to-monitor valves per the written inspection plan. No plan isrequired if no components are on the unsafe-to-monitor list. Any valve that isdesignated, as described in 40 CFR Section 60.486a(f)(1) as an unsafe-to-monitorvalve is exempt from routine monitoring requirements if:(1) The owner or operator of the valve demonstrates that the valve is unsafe tomonitor because monitoring personnel would be exposed to an immediate dangeras a consequence of routine monitoring and(2) The owner or operator of the valve adheres to a written plan that requiresmonitoring of the valve as frequently as practicable during safe-to-monitor times, ifany.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section60.482-7a(g)

Document applicability determination for all LDAR difficult-to-monitor and unsafe-tomonitor valves. Document the following information: A list of identification numbersfor valves that are designated as unsafe-to-monitor, and explanation for each valvestating why the valve is unsafe-to-monitor, and the plan for monitoring each valve.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section60.486a(f)(1)

Report: Provide a listing of those units that became subject to more frequentmonitoring for valves during the reporting interval.


The owner or operator shall designate each process unit as either quarterlymonitoring or part of the sustainable skip program. It is allowed to switch betweenquarterly monitoring and the sustainable skip period program provided that processunits monitored in the skip period alternative method may not revert to quarterlymonitoring if the most recent monitoring period demonstrates that more than 2% ofthe valves found leaking under the internal leak definition. Pursuant to 40 CFRSection 60.488(d), the Administrator shall be notified of the switch in monitoringfrequency option 90 days prior to implementing the provision.

Quarterly monitoring must be followed unit-wide if selected, and must continueunless the sustainable skip monitoring is selected and implemented for that unit.Quarterly frequency does not take into account valve leak rate.


The percent of valves leaking shall be determined using the following equation:

%VL= (VL/ VT) * 100

Where:

%VL= Percent leaking valves.

VL= Number of valves found leaking.

VT= The sum of the total number of valves monitored.

(2) The total number of valves monitored shall include difficult-to-monitor andunsafe-to-monitor valves only during the monitoring period in which those valvesare monitored.

(3) The number of valves leaking shall include valves for which repair has beendelayed.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section 60.485a(h)



03700011 - 006

Facility Name:

Permit Number:

A-115

(4) Any new valve that is not monitored within 30 days of being placed in serviceshall be included in the number of valves leaking and the total number of valvesmonitored for the monitoring period in which the valve is placed in service.

(5) If the process unit has been subdivided in accordance with 40 CFR Section60.482-7a(c)(1)(ii), the sum of valves found leaking during a monitoring periodincludes all subgroups.

(6) The total number of valves monitored does not include a valve monitored toverify repair.

CONTINUED: 40 CFR pt. 70 (consolidated LDARrequirements based on various applicable provisionsof 40 CFR pt. 60, subps. A and GGGa; 40 CFR pt. 61,subps. A, J and V; 40 CFR pt. 63, subps. A and CC;Clean Fuels Permit (106A-92-I/O-32)); 40 CFR Section60.485a(h)

Leaks greater than 50,000 ppmv will undertake one heroic drill and tap repairattempt within 45-days of detection unless there is a safety or environmentalconcern posed by repairing the leak in this matter.


Valves on the delay of repair list shall continue to be monitored in the samefrequency as the process unit. If a leak reaches 50,000 ppm, and cannot bereduced to less than 50,000 ppm, one heroic drill and tap repair attempt will beattempted within 45-days unless there is a safety or environmental concern posedby repairing the leak in this matter.


If valve leaks greater than 10,000 ppm and on the delay of repair list for longer than36 months, then one heroic drill and tap repair attempt will be attempted within45-days unless there is a safety or environmental concern posed by repairing theleak in this matter.


If a valve underwent a legitimate repair attempt during a process unit shutdown,and if the repair attempt is unsuccessful and continues to leak after the startup ofthe process unit, then the leak is considered a new leak with regards to the repairtimeline.


Monitor using Method 21 within 5 days of detecting a potential leak by visual,audible, olfactory, or other methods.


A valve (not replacing a leaking valve) that begins operation in gas/vapor service orlight liquid service after the initial startup date for the process unit must bemonitored according to paragraphs (a)(2)(i) or (ii).(i) The valve must be monitored for the first time within 30 days after the end of itsstartup period to ensure proper installation.(ii) If the existing valves in the process unit are monitored in accordance with 40CFR Section 60.483-1a or 40 CFR Section 60.483-2a, count the new valve asleaking when calculating the percentage of valves leaking as described in 40 CFRSection 60.483-2a(b)(5). If less than 2.0 percent of the valves are leaking for thatprocess unit, the valve must be monitored for the first time during the nextscheduled monitoring event for existing valves in the process unit or within 90 days,whichever comes first

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section60.482-7a(a)(2)

Any valve for which a leak is not detected for 2 successive months may bemonitored quarterly, beginning with the next calendar quarter (consistent with theunit monitoring schedule), until a leak is detected.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section60.482-7a(c)



03700011 - 006

Facility Name:

Permit Number:

A-116

Subject Item: GP 102 Units where carbon canisters may be used to meet NESHAP FF Requirements

Associated Items: FS 001 Unburied Sewer Lines


























FS 063 32 Penex





FS 077 36 Dimersol




FS 085 39 Oxy Fuel






03700011 - 006

Facility Name:

Permit Number:

A-117

Associated Items: FS 093 43 Polymerization








FS 110 North Flare




FS 128 88-Butane






40 CFR pt. 61, subp. FF - National Emission Standardfor Benzene Waste Operations; 40 CFR61.346(a)(1)(i); 40 CFR Section 61.346(a)(1)(i)(B); 40CFR Section 63.654(a); Minn. R. 7011.9930, subp. E

Control device and closed vent system must be operated at all times when waste isin the waste management unit vented to the control device.

40 CFR Section 61.349(b); 40 CFR Section 63.654(a);Minn. R. 7011.9930, subp. E

Control device must be designed to meet performance standards per NESHAP FF. 40 CFR Section 61.349(a)(2); 40 CFR Section61.349(a)(2)(ii); 40 CFR Section 63.654(a); Minn. R.7011.9930, subp. E

At all times, including periods of startup, shutdown, and malfunction, operate andmaintain equipment and associated air pollution control equipment, in a mannerconsistent with good air pollution control practices for minimizing emissions.Determination of whether acceptable operating and maintenance procedures arebeing used will be based on information available to the Administrator which mayinclude, but is not limited to, monitoring results, review of operating andmaintenance procedures and inspection of the source.

40 CFR Section 61.12(c); Minn. R. 7011.9900

Meet the requirements in GP 090. Fugitive LDAR equipment DesignatedNon-detectable.

40 CFR Section 61.346(a)(1)(i); 40 CFR Section61.355(h); 40 CFR Section 61.356(h); 40 CFR Section63.654(a); Minn. R. 7011.9930, subp. E

Measure VOC or benzene concentration at outlet of 1st carbon canister in carbonadsorption system when the source is connected to the carbon canister, and duringperiods of normal operation in accordance with the frequency specified in 40 CFRSection 61.354(d).

CAAA of 1990 Minn. R. 7007.0800, subp. 2; 40 CFRSection 61.349(h); 40 CFR Section 61.354(c); 40 CFRSection 61.354(d); 40 CFR Section 61.356(j)(10); 40CFR Section 63.654(a); Minn. R. 7011.9930, subp. E

Compliance demo: Replace existing primary carbon container with fresh carboncontainer within 24 hours for a 2-canister system when carbon breakthrough isdetected.

CAAA of 1990 Minn. R. 7007.0800, subp. 2

Install primary and secondary carbon canisters and operate them in series. CAAA of 1990 Minn. R. 7007.0800, subp. 2

Breakthrough shall be defined as a condition where the outlet of the primarycanister is >100 ppmv VOC or >20 ppmv benzene, and the primary canister isproviding a reduction of < 95% VOC or < 98% benzene.


Record date of carbon containers change-outs. 40 CFR Section 61.356(j)(10)

If using PID for Method 21 measurement, then follow manufacturer calibrationprocedures.




03700011 - 006

Facility Name:

Permit Number:

A-118

Per 40 CFR Section 61.349(f), conduct quarterly NESHAP visual inspection. Thevisual inspection shall include inspection of ductwork and piping and connections tocovers and control devices for evidence of visible defects such as holes inductwork or piping and loose connections.

40 CFR Section 61.346(a)(2); 40 CFR Section61.349(f); 40 CFR Section 61.356(g); 40 CFR Section61.357(d)(8); 40 CFR 63.654(a); Minn. R. 7011.9930,subp. E

Equipment Repair: Follow the requirements in GP 090 for equipment repair. 40 CFR Section 61.349(g); 40 CFR Section 61.654(a);Minn. R. 7011.9930, subp. E

Per 40 CFR Section 61.356, maintain required records for NESHAP FF equipment. 40 CFR Section 61.356; 40 CFR Section 63.654(a);Minn. R. 7011.9930, subp. E

The owner or operator subject to the wastewater provisions in 40 CFR Section63.647 shall comply with the recordkeeping and reporting provisions in 40 CFRSection 61.356 and 61.357 of 40 CFR part 61, subpart FF unless they arecomplying with the wastewater provisions specified in 40 CFR Section63.640(o)(2)(ii). There are no additional reporting and recordkeeping requirementsfor wastewater under this subpart unless a wastewater stream is included in anemissions average. Recordkeeping and reporting for emissions averages arespecified in 40 CFR Section 63.653 and in 40 CFR Section 63.654(f)(5) and (g)(8).

40 CFR Section 61.357(d)(7); 40 CFR Section61.357(d)(7)(iv); 40 CFR Section 63.654(a); Minn. R.7011.9930, subp. E; Minn. R. 7017.1010, subp. 3

The owner or operator shall submit annually to the Administrator a report thatsummarizes all inspections required by 40 CFR Section 61.342 through 61.354during which detectable emissions are measured or a problem (such as a brokenseal, gap or other problem) that could result in benzone emissions is identified,including information about the repairs or corrective action taken.




03700011 - 006

Facility Name:

Permit Number:

A-119

Subject Item: GP 104 Refinery Emergency Flares and Flare System (for Consent Decree Flare Policy)

Associated Items: CE 022 Flaring

CE 023 Flaring

CE 024 Flaring

CE 025 Flaring

EU 301 84ME23 E. Flare

EU 302 84ME24 W. Flare

EU 303 84ME25 U. Flare

EU 304 84ME3 N. Flare

What to do Why to do itOpacity: less than or equal to 0 percent opacity from flares except a total 5 minutesin any 2 consecutive hours; limit does not apply during startup, shutdown, ormalfunction.

40 CFR Section 60.11(c); 40 CFR Section 60.18(c); 40CFR Section 60.482-10a(d); 40 CFR Section60.485a(g); 40 CFR Section 60.692-5(c); 40 CFRSection 61.349(a)(2)(iii) & (d); 40 CFR Section63.11(b)(4); Minn. R. 7011.7280; Minn. R. 7011.9930,subp. E

Operation Limit: Flares must meet maximum velocity and minimum heat contentrequirements.

40 CFR Section 60.18; 40 CFR Section 60.482-10a(d);40 CFR Section 60.485a(g); 40 CFR Section60.692-5(c); 40 CFR Section 61.349(a)(2)(iii); 40 CFRSection 61.349(d); Minn. R. 7011.9930, subp. E

Control device and closed vent system: shall be operated at all times when waste isplaced in the waste management unit vented to the control device except whenmaintenance or repair of the waste management unit cannot be completed withouta shutdown of the control device.


All flares must be steam-assisted, air-assisted, or non-assisted. 40 CFR Section 60.18(c)(3); 40 CFR Section60.692-5(c); 40 CFR Section 63.11(b)(2); Minn. R.7011.7280

Fuel Restriction: The Permittee shall use only natural gas for purge gas and pilotgas in all flares.

Minn. R. 7007.0800, subp. 2

Flares shall be operated with pilot flame present at all times when emissions maybe vented to them.

40 CFR Section 60.18; 40 CFR Section 60.482-10a(d);40 CFR Section 60.485a(g); 40 CFR Section60.692-5(c); 40 CFR Section 61.12(a); 40 CFR Section61.349; 40 CFR Section 61.354(c)(3); 40 CFR Section63.11(b)(3) &(5); Minn. R. 7011.7280

Operate the flare system in conformance with the Flare Policy. Operation of theflare system in conformance with the Flare Policy constitutes good air pollutioncontrol practices pursuant to 40 CFR Section 60.11(d) and ensures thatHydrocarbon Flaring is not subject to the emission limitation monitoring, or otherrequirements for refinery fuel gas found in 40 CFR Section 60.100-60.109.

CAAA of 1990; Minn. R. 7007.0800, subp. 2; 40 CFRSection 60.105(a)(4); Minn. R. 7011.1435, subp. A

Conduct performance test if requested by Administrator per section 114 of theClean Air Act, as amended.


Monitor existence of flare pilot flame with thermocouple or equivalent device todetect the presence of a flame.

40 CFR Section 60.482-10a(d); 40 CFR Section60.485a(g); 40 CFR Section 60.692-5(c); 40 CFRSection 63.11; Minn. R. 7011.7280; Minn. R.7017.1010, subp. 1.A-C








03700011 - 006

Facility Name:

Permit Number:

A-120








Each closed-vent system and control device shall be visually inspected quarterly.The visual inspection shall include inspection of ductwork and piping andconnections to covers and control devices for evidence of visable defects such asholes in ductwork or piping and loose connections.

40 CFR Section 61.349(f); 40 CFR Section 61.356(g);40 CFR Section 61.357(d)(8); 40 CFR Section63.654(a); Minn. R. 7011.9930, subp. E

For each control device, maintain documentation that includes the followinginformation regarding the control device operation:

(1) Dates of startup and shutdown of the closed-vent system and control device;

(2) A description of the operating parameter (or parameters ) to be monitored toensure that the control device will be operated in conformance with these standardsand the control device's design specifications and an explanation of the criteriaused for selection of that parameter (or parameters). This documentation shall bekept for the life of the control device; and

(3) Periods when the closed-vent system and control device are not operated asdesigned including all periods and the duration when:Any valve car-seal or closure mechanism is broken or the by-pass line valveposition has changed andThe flow monitoring devices indicate that vapors are not routed to the controldevice as required.

40 CFR Section 61.356(j); 40 CFR Section61.356(j)(1); 40 CFR Section 63.654(a); Minn. R.7011.9930, subp. E

a) Delay of repair of facilities or units will be allowed if the repair is technicallyimpossible without a complete or partial facility or unit shutdown.

(b) Repair of such equipment shall occur before the end of the next facility or unitshutdown


If visible defects are observed during an inspection, or if other problems areidentified, or if detectable emissions are measured, a first effort to repair theclosed-vent system and control device shall be made as soon as practicable but nolater than 5 calendar days after detection. Repair shall be completed no later than15 calendar days after the emissions are detected or the visible defect is observed.

40 CFR Section 61.349(g); 40 CFR Section61.357(d)(8); 40 CFR Section 63.654(a); Minn. R.7011.9930, subp. E

Retain at the source and make available, upon request, for inspection by theAdministrator, for a minimum of 2 years, records of emission test results and otherdata needed to determine emissions.

40 CFR Section 61.13(g); 40 CFR Section 61.356; 40CFR Section 63.654(a); Minn. R. 7011.9930, subp. E

The owner or operator of a control device that is used to comply with the provisionsof this section shall monitor the control device in accordance with 40 CFR Section61.354(c).

40 CFR Section 61.349(h); 40 CFR Section 61.354(c);40 CFR Section 63.654(a); Minn. R. 7011.9930, subp.E

Submit Quarterly Air Quality and Excess Emissions Report. Cover letter,certification, and summary of exceedances shall be submitted in hardcopy format;all other information may be submitted electronically.

40 CFR Section 60.18(c)(1); 40 CFR Section60.18(c)(2); 40 CFR Section 60.4(a); 40 CFR Section60.4(b)(Y); 40 CFR Section 60.952-5(c); Minn. R.7007.0500, subp. 3

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.




03700011 - 006

Facility Name:

Permit Number:

A-121

Submit a report quarterly to the Administrator that includes:(i) If a treatment process or wastewater treatment system unit is monitored; theneach period of operation during which the concentration of benzene in themonitored waste stream exiting the unit is equal to or greater than 10 ppmw.

(ii) If a treatment process or wastewater treatment system unit is monitored, theneach 3-hour period of operation during which the average value of the monitoredparameter is outside the range of acceptable values or during which the unit is notoperating as designed.

(iii) If a treatment process or wastewater treatment system unit is monitored, theneach period of operation during which the flow-weighted annual averageconcentration of benzene in the monitored waste stream entering the unit is equalto or greater than 10 ppmw and/or and/or the total annual benzene quantity is equalto or greater than 1.0 mg/yr.


(iv) For a control device monitored in accordance with 40 CFR Section 61.354(c),each period of operation monitored during which any of the following condition:

Each period in which the pilot flame of a flare is absent.

CONTINUED40 CFR Section 61.357(d)(7); 40 CFR Section63.654(a); Minn. R. 7011.9930, subp. E; Minn. R.7017.1010, subp. 3

Shall submit annually to the Administrator a report that summarizes all inspectionsrequired during which detectable emissions are measured or a problem (such as abroken seal, gap or other problem) that could result in benzene emissions isidentified, including information about the repairs or corrective action taken.


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 - 006

Facility Name:

Permit Number:

A-122

Subject Item: GP 106 Control Equipment Used to Meet Requirements of MACT CC


CE 003 Activated Carbon Adsorption




CE 033 Other

CE 034 Other

CE 050 Flaring



What to do Why to do itConduct performance test if requested by Administrator per section 114 of theClean Air Act, as amended.

40 CFR Section 63.7(a)(3); 40 CFR Section 63.7(d);40 CFR Section 63.7(e)(1); 40 CFR Section 63.7(e)(2);40 CFR Section 63.7(e)(4); Minn. R. 7011.7280; Minn.R. 7017.2015, subp. 3.A

Operate vapor processing system in a manner not to exceed operating parametervalue.

40 CFR Section 63.6(f)(1); 40 CFR Section 63.644(e);Minn. R. 7011.7280

Correct malfunctions as soon as practicable in accordance with the startup,shutdown, and malfunction plan.

40 CFR Section 63.6(e)(1)(ii); 40 CFR Section63.6(e)(1)(iii); Minn. R. 7011.7280

Record occurrence of startup, shutdown, and malfunction of process equipment orof malfunction or maintenance of air pollution control equipment. Documentconformance with or deviation from startup/shutdown/malfunction plan.

40 CFR Section 63, subp. CC. Table 6; 40 CFRSection 63.10(b)(2)(i)-(v); 40 CFR Section63.6(e)(3)(iii)-(iv); Minn. R. 7011.7280

Maintain up-to-date startup, shutdown, malfunction plan (SSMP). 40 CFR Section 63.6(e)(1)(iii); 40 CFR Section63.6(e)(2); 40 CFR Section 63.6(e)(3)(i)-(ii); 40 CFRSection 63.6(e)(3)(v)-(vii); Minn. R. 7011.7280

If a malfunction occurs that was not addressed in the startup, shutdown, andmalfunction plan (SSMP), revise the SSMP within 45 days after the event.

40 CFR Section 63.6(e)(3)(viii); Minn. R. 7011.7280

Record occurrence of Startup/Shutdown/Malfunction of process equipment,malfunction and maintenance of air pollution control equipment, and documentconformance with or deviation from Startup/Shutdown/Malfunction Plan.

40 CFR Section 63.10(b)(2)(i)-(iv)


40 CFR Section 63, subp. CC. Table 6; 40 CFRSection 63.10(d)(5)(i)-(ii); 40 CFR Section63.6(e)(3)(iii)-(iv); 40 CFR Section 63.654(g)(6)(i)(A);40 CFR Section 63.9(i)



03700011 - 006

Facility Name:

Permit Number:

A-123

Subject Item: GP 108 Control Device Required by NESHAP FF; Doesn't include CVS or CC or Refinery Flares



What to do Why to do itControl device and closed vent system must be operated at all times when waste isin the waste management unit vented to the control device.


Temperature: greater than or equal to 28 degrees C using 3-hour Rolling Averagebelow most recent performance test design temperature.

40 CFR Section 61.354(c); 40 CFR Section 63.654(a);Minn. R. 7011.9930, subp. E



40 CFR Section 61.12(a); Minn. R. 7011.9900

2) The control device shall be designed and operated in accordance with thefollowing conditions:

(i) An enclosed combustion device (e.g., a vapor incinerator, boiler, or processheater) shall meet one of the following conditions:

(A) Reduce the organic emissions vented to it by 95 weight percent or greater;

(B) Achieve a total organic compound concentration of 20 ppmv (as the sum of theconcentrations for individual compounds using Method 18) on a dry basis correctedto 3 percent oxygen; or

(C) Provide a minimum residence time of 0.5 seconds at a minimum temperature of760 °C (1,400 °F). If a boiler or process heater issued as the control device, thenthe vent stream shall be introduced into the flame zone of the boiler or processheater.

40 CFR Section 61.349(a)(2); 40 CFR Section63.654(a); Minn. R. 7011.9930, subp. E

A vapor recovery system (e.g., a carbon adsorption system or a condenser) shallrecover or control the organic emissions vented to it with an efficiency of 95 weightpercent or greater, or shall recover or control the benzene emissions vented to itwith an efficiency of 98 weight percent or greater.

CONTINUED40 CFR Section 61.349(a)(2); 40 CFR Section63.654(a); Minn. R. 7011.9930, subp. E

Conduct performance test if requested by Administrator per section 114 of theClean Air Act, as amended.


















03700011 - 006

Facility Name:

Permit Number:

A-124

For each control device, maintain documentation that includes the followinginformation regarding the control device operation:

(1) Dates of startup and shutdown of the closed-vent system and control device;

(2) A description of the operating parameter (or parameters ) to be monitored toensure that the control device will be operated in conformance with these standardsand the control device's design specifications and an explanation of the criteriaused for selection of that parameter (or parameters). This documentation shall bekept for the life of the control device; and

(3) Periods when the closed-vent system and control device are not operated asdesigned including all periods and the duration when:Any valve car-seal or closure mechanism is broken or the by-pass line valveposition has changed andThe flow monitoring devices indicate that vapors are not routed to the controldevice as required.

40 CFR Section 61.356(j); 40 CFR Section61.356(j)(1); 40 CFR Section 63.654(a); Minn. R.7011.9930, subp. E










Submit Quarterly Air Quality and Excess Emissions Report. Cover letter,certification, and summary of exceedances shall be submitted in hardcopy format;all other information may be submitted electronically.

40 CFR Section 60.18(c)(1); 40 CFR Section60.18(c)(2); 40 CFR Section 60.4(a); 40 CFR Section60.4(b)(Y); 40 CFR Section 60.952-5(c); Minn. R.7007.0500, subp. 3

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.















03700011 - 006

Facility Name:

Permit Number:

A-125

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.




03700011 - 006

Facility Name:

Permit Number:

A-126

Subject Item: GP 109 Closed Vent System for NESH FF Equipment

Associated Items: FS 001 Unburied Sewer Lines


























FS 063 32 Penex





FS 077 36 Dimersol




FS 085 39 Oxy Fuel






03700011 - 006

Facility Name:

Permit Number:

A-127

Associated Items: FS 093 43 Polymerization








FS 110 North Flare




FS 128 88-Butane





FS 135 44 Penex

What to do Why to do itEach opening shall be maintained in a closed, sealed position (e.g., covered by alid that is gasketed and latched) at all times that waste is in the drain system exceptwhen it is necessary to use the opening for waste sampling or removal, or forequipment inspection, maintenance, or repair.



Control device and closed vent systems must be operated at all times when wasteis in the waste management unit vented to the control device.


Control device and closed vent system: shall be operated at all times when waste isplaced in the waste management unit vented to the control device except whenmaintenance or repair of the waste management unit cannot be completed withouta shutdown of the control device.



(1) Annual monitoring shall comply with Method 21 from appendix A of 40 CFR pt.60;






03700011 - 006

Facility Name:

Permit Number:

A-128






























03700011 - 006

Facility Name:

Permit Number:

A-129

Subject Item: GP 111 Fuel Gas Supply Systems

Associated Items: EU 063 Fuel Gas Supply System (47 unit) BACKUP: Monitoring Point for FG H2S

EU 256 Fuel Gas Supply System (41 unit) Monitoring Point for FG H2S

EU 263 Fuel Gas Supply System (45 unit) Monitoring Point for FG H2S

MR 075 41V33 Fuel Gas Mix Drum H2S

MR 076 41V-33 Fuel Gas Mix Drum Refinery Flow Meter

MR 080 45V-39 Fuel Gas Mix Drum H2S

MR 088 45V-39 Fuel Gas Mix Drum Flow Meter

MR 091 Fuel Gas H2S Concentration (BACKUP)

MR 092 Fuel Gas Mix Drum Flow Meter


Hydrogen Sulfide: less than or equal to 90 parts per million using 365-day RollingAverage by volume in refinery fuel gas measured at the 41 Unit refinery gas mixdrum and at the 45/47 Unit refinery gas mix drum. Existing continuous monitoringsystems and best engineering judgment shall be used to estimate hydrogen sulfideconcentration to quantify emissions for purposes of compliance with the fuel gasconcentration limits.

Title I Condition: Limit taken to avoid classification as amajor modification under 40 CFR Section 52.21 forSO2; Minn. R. 7007.3000

Recordkeeping: The Permittee shall record and maintain the hourly, daily, and365-day rolling average H2S concentration at the 41 Unit refinery fuel gas mix drumand at the 45/47 Unit refinery fuel gas mix drum.

Title I Condition: Recordkeeping associated with thelimit to avoid classification as a major modificationunder 40 CFR Section 52.21; Minn. R. 7007.3000;Minn. R. 7007.0800, subp. 5

Hydrogen Sulfide: less than or equal to 0.10 grains/dry standard cubic foot using3-hour Rolling Average (230 mg/dscm[162 ppm]). This limit does not apply duringperiods of startup, shutdown, or malfunction. Limit applies to each system.

40 CFR Section 60.104(a)(1); 40 CFR Section60.105(e)(3)(ii); 40 CFR Section 60.8(c); Minn. R.7011.1435 A

Hydrogen Sulfide: less than or equal to 0.186 grains/dry standard cubic foot using1-Hour Average (300 ppm). This is a state-only requirement and, pursuant to Minn.R. 7007.1750, it is not enforceable by the EPA administrator or citizens under theClean Air Act. Limit applies to each system.

Minn. R. 7009.0080

B. RECORDKEEPING REQUIREMENTS (APPLIES TO EACH SYSTEM) hdr

Recordkeeping of Fuel Gas Flow Rate: The Permittee shall record the hourlyaverage fuel gas flow rate.

Title I Condition: Recordkeeping associated withnetting limit for NOx, 40 CFR Section 52.21

Recordkeeping of the High Heating Value (HHV): The Permittee shall calculateand record daily the average HHV in BTU/SCF per mix drum.

Title I Condition: Recordkeeping associated withnetting limit for NOx, 40 CFR Section 52.21

Conduct Root Cause Failure Analysis (RCFA): The Permittee shall comply with theRCFA as required by May 1998 Stipulation Agreement between the MPCA andKoch Refinery.

Minn. R. 7007.0800, subp. 2; MPCA StipulationAgreement May 1998.

C. CEMS REQUIREMENTS FOR H2S hdr

H2S CEMS Emissions Monitoring: The Permittee shall monitor SO2 emissionsusing a H2S CEMS in conjunction with the fuel flow monitors.

40 CFR pt. 60, subp. J; Minn. R. 7017.1006; Minn. R.7007.0800, subp. 4

H2S Content in Refinery Gas: The Permittee shall calibrate, operate and maintain aCEMS to determine the H2S content of the refinery gas. The CEMS shall provide acontinuous record of H2S in ppm.

40 CFR Section 60.105(a)(4); Minn. R. 7017.1006

Calculation: The Permittee shall calculate valid hourly average emissions fromCEMS

Minn. R. 7017.1160, subps 1,2 &3

CEMS QA/QC: The owner or operator of an affected facility is subject to theperformance specifications listed in 40 CFR 60, Appendix B and shall operate,calibrate, and maintain each CEMS according to the QA/QC procedures in 40 CFRpt. 60, Appendix F as amended and maintain a written QA/QC program available ina form suitable for inspection.

40 CFR pt. 60, Appendix F; 40 CFR Section 60.13(a)

CEMS Cylinder Gas Audit (CGA): due before end of each calendar quarter inwhich a Relative Accuracy Test Audit (RATA) is not conducted. Conduct CGAs atleast 2 months apart. Follow the procedures in 40 CFR pt. 60, Appendix F.

40 CFR pt. 60, Appendix F; Minn. R. 7017.1170, subp.4

CEMS Relative Accuracy Test Audit (RATA): due at least once every four calendarquaters after CEMS certification. Follow the procedures in 40 CFR pt. 60,Appendix B and Appendix F.

40 CFR pt. 60, Appendix B and Appendix F; Minn. R.7017.1170, subp. 5



03700011 - 006

Facility Name:

Permit Number:

A-130

CEMS Daily Calibration Drift (CD) Test: The CD shall be quantified and recorded atzero (low-level) and upscale (high-level) gas concentrations at least once daily.The CEMS shall be adjusted whenever the CD exceeds twice the specification of40 CFR pt. 60, Appendix B. 40 CFR pt. 60, Appendix F, shall be used to determineout-of-control periods for CEMS. Follow the procedures in 40 CFR pt. 60, AppendixF.

Minn. R. 7017.1170, subp. 3

Continuous Operation: CEMS must be operated and data recorded during allperiods of emission unit operation including periods of emission unit start-up,shutdown, or malfunction except for periods of acceptable monitor downtime. Thisrequirement applies whether or not a numerical emission limit applies during theseperiods. A CEMS must not be bypassed except in emergencies where failure tobypass would endanger human health, safety, or plant equipment.

Minn. R. 7017.1090, subp. 1; Minn. R. 7017.1002,subp 10. A.-C

Acceptable monitor downtime is a violation of subpart 1, except for reasonableperiods of monitor downtime due to the following causes:

A. damage to the monitoring system to Acts of God such as lightning strikes,tornadoes, or floods which render the monitor inoperative;B. sudden and not reasonably preventable breakdowns;C. scheduled monitor maintenance based upon equipment manufacturer'srecommended maintenance schedule which cannot reasonably be conducted whenthe emission unit is not operating; orD. unavoidable monitor downtime in order to conduct daily drift checks, calibrationerror audits, relative accuracy tests audits, linearity checks, and cylinder gas auditsrequired by a compliance document, applicable requirement, or by request of theCommissioner.

Minn. R. 7017.1090, subp. 2; Minn. R. 7017.1002,subp. 10. A.-C

QA Plan: Develop and implement a written quality assurance plan that covers eachCEMS. The plan shall be on site and available for inspection within 30 days aftermonitor certification. The plan shall contain all of the information required by 40CFR 60, App. F, section 3. The CEMS manufactures recommended spare partsshall be kept onsite unless the Commissioner approves exclusions.

Minn. R. 7017.1170, subp. 2

Recordkeeping: The owner or operator must retain records of all CEMS monitoringdata and support information for a period of five years from the date of themonitoring sample, measurement or report. Records shall be kept at the source.

Minn. R. 7017.1130

D. CMS REQUIREMENT hdr

Fuel Flowrate: The Permittee shall calibrate, operate and maintain CMS that recordthe fuel flowrate at each fuel combustion device.

Minn. R. 7007.0800, subp. 4

CMS QA/QC: The Permittee shall follow manufacturer recommendations forpreventative maintenance and periodic monitoring to ensure CMS reliability,including but not limited to annual calibrations for fuel gas flow meters.

Minn. R. 7007.0800, subp. 4

E. REPORTING REQUIREMENT (APPLIES TO EACH SYSTEM) hdr



03700011 - 006

Facility Name:

Permit Number:

A-131

Subject Item: GP 112 Sulfur Recovery Units

Associated Items: EU 045 #5 Sulfur Recovery Unit (SRU)

EU 111 #3 Sulfur Recovery Unit (SRU)


MR 036 TGTU2 SO2 Analyzer - 26H21

MR 037 TGTU2 O2 Analyzer - 26H21

MR 082 45H-6 SO2


MR 114 TGTU2 CO Analyzer

MR 139 45 CO ppm

SV 042 26H21 Stack

SV 093 45H61 Stack


Sulfur Dioxide: less than or equal to 428 tons/year using 365-day Rolling Average .Emissions from acid gas flaring incidents are not included in the calculations ofemissions against the caps.

Effective 10/2/04 and for the first 365 days after this date, SO2 emissions intons/year are limited as determined by the following equation:E = 428[0.15 + 0.85(D/365)]whereE = SO2 emissions in total tons since 10/2/04D = number of days since 10/2/04

Title I Condition: Limit to avoid classification as amajor modification under 40 CFR Section 52.21; Minn.R. 7007.3000

Carbon Monoxide: less than or equal to 608 tons/year using 365-day RollingAverage . Emissions from acid gas flaring incidents are not included in thecalculations of emissions against the caps.

Effective 10/2/04 and for the first 365 days after this date, CO emissions intons/year are limited as determined by the following equation:E = 608[0.15 + 0.85(D/365)]whereE = CO emissions in total tons since 10/2/04D = number of days since 10/2/04


Evaluate the effectiveness of the sulfur degassing system by June 30, 2005. Title I Condition: Limit to avoid classification as amajor modification under 40 CFR Section 52.21; Minn.R. 7007.3000

If the sulfur degassing system is effective, the Permittee shall continue operationand propose to the MPCA appropriate permit conditions by August 1, 2005.


Compliance Plan: If sulfur degassing system is not effective, the Permittee shallrevise and submit to the MPCA a compliance plan by December 31, 2005.



SO2 and CO Recordkeeping: The Permittee shall record the hourly, daily, and365-day rolling average emission rate of SO2 and CO for No. 3, 4 and 5 sulfurrecovery units and tail gas treatment units.

Title I Condition: Recordkeeping associated with limitto avoid classification as a major modification under 40CFR Section 52.21: Minn. R. 7007.3000; Minn. R.7007.0800, subp. 5

C. CEM REQUIREMENTS FOR CO hdr

Emissions Monitoring: The Permittee shall calibrate, operate and maintain COcontinuous emissions monitoring system (CEMS).

Minn. R. 7017.1006; Minn. R. 7007.0800, subp. 4

CO Emissions Measuring: The Permittee shall use a CO CEMS to measure sulfurrecovery units (No. 3, 4 and 5) emissions from SV 042 and SV 093.

Minn. R. 7017.1006


Minn. R. 7017.1160, subps 1,2 &3



03700011 - 006

Facility Name:

Permit Number:

A-132








Minn. R. 7017.1170, subp. 3







Minn. R. 7017.1170, subp. 2


Minn. R. 7017.1130



03700011 - 006

Facility Name:

Permit Number:

A-133

Subject Item: GP 113 NSPS Kb Tanks with Fixed Roof subject to NESHAP FF following the requirements of Kb


EU 223 14V-22 Slop Drum














03700011 - 006

Facility Name:

Permit Number:

A-134

Subject Item: GP 114 Fugitive LDAR Connectors, Misc. All FS numbers are included in this group.

What to do Why to do itIf an instrument reading of 500 ppm or greater is measured, a leak is detected. 40 CFR pt. 70 (consolidated LDAR requirements

based on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32))

The owner or operator shall implement a program to monitor all applicableaccessible connectors of 2.0 inches nominal diameter or greater once every fouryears, with a portion of that facility-wide monitoring to occur annually. This programdoes not apply to inaccessible or unsafe to monitor connectors, as defined in 40CFR Section 63.174."






(b) Flint Hills Resources is required to meet a 500 ppm leak definition as noted incondition 1 for this group.

(c)(1) When a leak is detected, it shall be repaired as soon as practicable, but notlater than 15 calendar days after it is detected, except as provided in 40 CFRSection 60.482-9a.

(2) The first attempt at repair shall be made no later than 5 calendar days aftereach leak is detected.

(d) First attempts at repair include, but are not limited to, the best practicesdescribed under 40 CFR Section 60.482-2a(c)(2) and 60.482-7a(e).


Connectors in gas/vapor or light liquid service are exempt from the requirements in40 CFR Section 60.482-11a, provided the owner or operator complies with 40 CFRSection 60.482-8a for all connectors, not just those in heavy liquid service.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGGa; 40 CFR pt. 61, subps. A, Jand V; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR Section 60.593A(g)



03700011 - 006

Facility Name:

Permit Number:

A-135

Subject Item: GP 115 Sulfur Degassing System

Associated Items: EU 217 Sulfur Loading

TK 505 Sulfur



Hydrogen Sulfide: less than or equal to 10 tons/year using 12-month RollingAverage beginning in August 2005 through July 31, 2006, as the first period.

Title I Condition: Limit to avoid classification as a majormodification under 40 CFR Section 52.21


Hydrogen Sulfide: The Permittee shall calculate and record the 12-month rollingaverage H2S emissions form the listed units using engineering calculations basedon degas operational parameters and annual sampling to support thesecalculations.




03700011 - 006

Facility Name:

Permit Number:

A-136

Subject Item: GP 116 Refinery Fuel Gas SO2 and PM10 Emissions

Associated Items: MR 156 41 Unit Fuel Gas Mix Drum Total Sulfur

MR 161 47/45 Mix Drum Fuel Gas Combustion SO2 Monitor at 25H3

MR 162 47/45 Mix Drum Fuel Gas SO2 Monitor at 29H1/2

MR 165 47/45 Mix Drum Fuel Gas Combustion O2 Monitor at 25H3

MR 166 47/45 Mix Drum Fuel Gas Combustion O2 Monitor at 29H1/2


Sulfur Dioxide: less than or equal to 878 tons/year using 365-day Rolling Sum fromall refinery fuel gas

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

B. CMS REQUIREMENT FOR THE 41 UNIT FUEL GAS MIX DRUM hdr

Install, operate, and maintain a total sulfur CEMS on the 41 unit refinery fuel gasmix drum in accordance with 40 CFR Part 60, Appendix B and Appendix F. Install,operate, and maintain flow meters on each refinery fuel gas mix drum or eachcombustion device firing fuel gas from the 41 unit refinery fuel gas mix drum.

Title I Condition: To avoid classification as a majormodification under 40 CFR Section 52.21 and Minn. R.7007.3000; Minn. R. 7007.0800, subp. 4

Recordkeeping for SO2 limit based on a 365-day rolling sum: The Permittee shallcalculate and record the rolling sum each calendar day based on data from therefinery fuel gas flow meters and total sulfur monitor. For the first 364 days, therolling sum shall be calculated each day based on total emissions since initialstartup of EU 324 (25H-4). For the first 364 days of operation, daily complianceshall be demonstrated when the following formula is true:N < 130 + 2.05nWhere:N = total actual SO2 emissions through day n (tpy)n = number of days since initial startup of EU 324 (25H-4)


Daily Recordkeeping: The Permittee shall maintain daily records of all monitoringdata and calculations of SO2 to show continuous compliance with the applicableemission limits.


C. CMS REQUIREMENT FOR THE 45 UNIT FUEL GAS MIX DRUM hdr

Install, operate, and maintain SO2 and O2 CEMS on two heaters firing refinery fuelgas in accordance with 40 CFR Part 60, Appendix B and Appendix F. Install,operate, and maintain flow meters on each refinery fuel gas mix drum or eachcombustion device firing fuel gas from the 45 unit refinery fuel gas mix drum.


Recordkeeping for SO2 limit based on a 365-day rolling sum: The Permittee shallcalculate and record the rolling sum each calendar day based on data from therefinery fuel gas flow meters, SO2 CEMS, and O2 CEMS. For the first 364 days,the rolling sum shall be calculated each day based on total emissions since initialstartup of EU 324 (25H-4). For the first 364 days of operation, daily complianceshall be demonstrated when the following formula is true:N < 130 + 2.05nWhere:N = total actual SO2 emissions through day n (tpy)n = number of days since initial startup of EU 324 (25H-4)


Daily Recordkeeping: The Permittee shall maintain daily records of all monitoringdata and calculations of SO2 to show continuous compliance with the applicableemission limits.




03700011 - 006

Facility Name:

Permit Number:

A-137

Subject Item: SV 042 26H21 Stack


EU 047 SRU 5 Sulfur Pit

EU 235 Incinerator for TGTU2 Bypasses & SRU5 Sulfur Degassing

GP 112 Sulfur Recovery Units



MR 040 EMRC Flow for TGTU2 - 26H21

MR 041 26H-21 Fuel Gas Flow

MR 042 EMRC Temperature Thermocouple for TGTU2

MR 114 TGTU2 CO Analyzer


Sulfur Dioxide: less than or equal to 170.8 lbs/hour using 3-hour Rolling Average .The Permittee shall use CEMS to monitor the sulfur dioxide emissions in order tocalculate pounds of sulfur dioxide per hour (lb/hr).

Title I Condition: SIP for SO2 NAAQS, 40 CFR pt. 50;MN State Implementation Plan (SIP)

Sulfur Dioxide: less than or equal to 93.6 lbs/hour using 24-hour Rolling Average Title I Condition: SIP for SO2 NAAQS, 40 CFR pt. 50;MN State Implementation Plan (SIP)

Sulfur Dioxide: less than or equal to 409.8 tons/year using 12-month RollingAverage


Sulfur Dioxide: less than or equal to 250 parts per million by volume (dry, 0%oxygen), using 12-hour Rolling Average. Limit does not apply during startup,shutdown, or malfunction.

40 CFR Section 60.104; 40 CFR Section 60.105; 40CFR Section 60.8(c); Minn. R. 7011.1435. A [Meetslimit set by 40 CFR Section 63.1568(a)(1)

Sulfur Dioxide: less than or equal to 170.8 lbs/hour using 1-Hour Average . This isa state-only requirement and pursuant to the Minn. R. 7007.1750, it is notenforceable by the EPA administrator or citizens under the Clean Air Act.

Minn. R. 7009.0080

Nitrogen Oxides: less than or equal to 2.44 lbs/hour using 24-hour Rolling Averagefor EU 045.

Title I Condition: BACT Limit for NOx, 40 CFR Section52.21

Nitrogen Oxides: less than or equal to 0.122 lbs/million Btu heat input using365-day Rolling Average for EU 045. The limit does not apply during startup orshutdown.


Carbon Monoxide: less than or equal to 121.0 tons/year using 365-day RollingAverage . Emissions from acid gas flaring incidents are not included in thecalculation of emissions against the caps.

Title I Condition: Limit to avoid classification as a majormodification under 40 CFR Section 52.21; Minn. R.7007.3000

Hydrogen Sulfide: less than or equal to 0.10 grains/dry standard cubic foot using3-hour Rolling Average (230 mg/dscm[162 ppm]). This limit applies only to fuel gascombusted in the SRU/TGTU, not to SRU process/waste gases per EPA guidance.This limit does not apply during periods of startup, shutdown, or malfunction.

40 CFR 60.104(a)(1); Minn. R. 7011.1410, subp. 2

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

B. CALCULATIONS AND RECORDKEEPING REQUIREMENTS hdr

SO2 Emission Calculation and Recordkeeping: The Permittee shall maintainrecords of the calculated SO2 emissions of hourly average of total stack SO2emissions in lb/hr.

Title I Condition: Recordkeeping associated with SIPfor SO2 NAAQS 40 CFR pt. 50; MN StateImplementation Plan (SIP); Minn. R. 7009.0080;

SO2 Emission Calculation and Recordkeeping: The Permittee shall maintainrecords of the calculated SO2 emissions of total stack SO2 emissions in tons/year.

Title I Condition: Recordkeeping associated with SIPfor SO2 NAAQS 40 CFR pt. 50

NOx Emission Calculations and Recordkeeping: The Permittee shall record andcalculate the 24-hour rolling average of NOx emissions in lb/hr.

Title I Condition: Recordkeeping associated withBACT limit for NOx

CO Emission Calculation and Recordkeeping: The Permittee shall maintain recordand calculate the 365-day rolling average CO emissions of total stack in tons/year.

Title I Condition: Recordkeeping associated with limitto avoid classification as a major modification under 40CFR Section 52.21 for CO

SO2 Concentration Recordkeeping: The Permittee shall record on an hourlyaverage of SO2 in ppm (dry, 0% oxygen).

Recordkeeping associated with NSPS limit; 40 CFRSection 60.107

C. OTHER REQUIREMENTS hdr



03700011 - 006

Facility Name:

Permit Number:

A-138

Monitoring SO2 concentration: The Permittee shall monitor and record the totalSRU SO2 emissions (including sulfur degassing and bypasses) at stack ppm (at0% oxygen).

Title I Condition: CAAA of 1990; Minn. R. 7007. 0800,subp. 4; Minn. R. 7011.1435



D. CEM REQUIREMENTS FOR SO2 AND CO hdr

SO2 Emissions Monitoring: The Permittee shall calibrate, operate and maintainSO2 Continuous Emissions Monitoring System (CEMS).

Title I Condition: SIP for SO2 NAAQS 40 CFR pt. 50;MN State Implementation Plan (SIP); CAAA of 1990;Minn. R. 7017.1006

CO Emissions Monitoring: The Permittee shall calibrate, operate and maintain COContinuous Emissions Monitoring System (CEMS).

Minn. R. 7007.0800, subp. 2; Minn. R. 7017.1006

CO Emissions Measuring: The Permittee shall use a CO CEMS to measure COemissions from SV 042.

Minn. R. 7017.1006

SO2 Emissions Measuring: The Permittee shall use a SO2 CEMS to measure SO2from SV 042.

Minn. R. 7017.1006

CEMS QA/QC: The Permittee of an affected facility is subject to the performancespecifications listed in 40 CFR 60, Appendix B and shall operate, calibrate, andmaintain each CEMS according to the QA/QC procedures in 40 CFR pt. 60,Appendix F as amended and maintain a written QA/QC program available in a formsuitable for inspection.







Minn. R. 7017.1170, subp. 3


Minn. R. 7017.1090, subp. 1



Minn. R. 7017.1090, subp. 2

QA Plan: Develop and implement a written quality assurance plan that covers theCEMS. The plan shall be on site and available for inspection within 30 days aftermonitor certification. The plan shall contain all of the information required by 40CFR 60, App. F, section 3. The CEMS manufactures recommended spare partsshall be kept onsite unless the Commissioner approves exclusions.

Minn. R. 7017.1170, subp. 2

Recordkeeping: The Permittee must retain records of all CEMS monitoring dataand support information for a period of five years from the date of the monitoringsample, measurement or report. Records shall be kept at the source.

Minn. R. 7007.1130

E. O2 MONITOR REQUIREMENTS hdr

QA Plan: Develop and implement a written quality assurance plan that covers theO2 monitor. The plan shall be on site and available for inspection within 30 daysafter monitor certification. The plan shall contain all the information required by 40CFR pt. 60, Appendix F, Section 3.

Minn. R. 7007.0800, subp. 4



03700011 - 006

Facility Name:

Permit Number:

A-139

O2 QA/QC: The owner or operator of an affected facility is subject to theperformance specifications listed in 40 CFR pt. 60, Appendix B and shall operate,calibrate and maintain the O2 monitor according to the QA/QC procedures in 40CFR pt. 60, Appendix F as amended and maintain a written QA/QC programavailable in a form suitable for inspection.

Minn. R. 7007.0800, subp. 4

F. REPORTING REQUIREMENTS hdr

G. NATIONAL EMISSION STANDARDS FOR HAZARDOUS AIR POLLUTANTS hdr

The Permittee shall comply with 40 CFR pt. 63, subp. UUU by compliance dateApril 11, 2005.

National Emission Standards for Hazardous AirPollutants for Petroleum Refineries: Catalytic CrackingUnits, Catalytic Reforming Units, and Sulfur RecoveryUnits



03700011 - 006

Facility Name:

Permit Number:

A-140

Subject Item: SV 066 32H5 6 7 Stack

Associated Items: EU 073 Powerformer Reactor Charge Heater (Grouped with EU 073/074/075)

EU 074 Powerformer Reactor #1 Reheat Heater(Grouped with EU 073/074/075)

EU 075 Powerformer Reactor #2 Reheat Heater( (Grouped with EU 073/074/075)

MR 064 32H5,6,7 O2 Analyzer for NOx

MR 125 32H-5 Fuel Gas Flowmeter




Nitrogen Oxides: less than or equal to 29.6 tons/year using 365-day Rolling Sum(EU 073, EU 074 and EU 075)


Nitrogen Oxides: less than or equal to 0.045 lbs/million Btu heat input using 3-hourRolling Average (Limit applies to each heater.)

Title I Condition: CAAA of 1990; Minn. R. 7007.0800,subp. 2

Carbon Monoxide: less than or equal to 23.7 tons/year using 365-day Rolling Sum Title I Condition: To avoid classification as a majormodification under 40 CFR Section 52.21 and Minn. R.7007.3000

Hydrogen Sulfide: less than or equal to 0.10 grains/dry standard cubic foot using3-hour Rolling Average (230 mg/dscm[162 ppm]). This limit does not apply duringperiods of startup, shutdown, or malfunction. (Limit applies to each unit)

40 CFR Section 60.104(a)(1); Minn. R. 7011.1490,subp. 2; (most stringent; meet limits set by Minn. R.7011.1490, subp. 2)

Total Particulate Matter: less than or equal to 0.4 lbs/million Btu heat input using3-hour Rolling Average (Limit applies to each unit). Compliance with the fuelrestriction requirement constitutes compliance with this limit.

Minn. R. 7011.1410, subp. 3. B.

Opacity: less than or equal to 20 percent opacity using 6-minute Average ; exceptfor one six-minute period per hour of not more than 60 percent opacity. (limitapplies to each unit). Compliance with the fuel restriction requirement constitutescompliance with this limit.

Minn. R. 7011.1410, subp. 3. B.



Fuel Usage: less than or equal to 113.2 million Btu's/hour using 8-hour BlockAverage based on the lower heating value of fuel burned. Downtime of 15 or moreminutes is not to be included as operating time.

The unit may not be operated at a higher heat input unless a performance test isconducted at a higher rate and MPCA staff determine compliance at that rate forthe emission unit.

Minn. R. 7017.2025

Recordkeeping of Heat Input: The Permittee shall calculate the average heat inputfor each 8-hour block by dividing the total heat input by the total operating time ineach 8-hour block. Downtime of 15 or more minutes is not to be included asoperating time.

Minn. R. 7007.0800, subp. 5

Recordkeeping: Record and maintain records of each fuel combusted in each uniton a monthly basis.

Minn. R. 7007.0800, subp. 5

To determine compliance with the CO limit based on a 365-day rolling sum, thePermittee shall calculate and record the rolling sum each calendar day. For thefirst 364 days of operation, the rolling sum shall be calculated each day based ontotal actual emissions since initial startup. For the first 364 days of operation, dailycompliance shall be demonstrated when the following formula is true:N < 3.50 + 0.0554nWhere:N = total actual CO emissions through day n (tpy)n = number of days since initial startup


C. MONITORING REQUIREMENTS hdr

Monitoring for NOx and CO emissions: The Permittee shall continuously monitorfuel combustion rate and stack O2. The Permittee shall use the most recentcorrelation to determine NOx and CO lb/MMBtu emissions on an hourly basis.

Title I Condition: Monitoring associated with CAAA of1990; Minn. R. 7007.0800, subp. 4

D. RECORDKEEPING AND REPORTING REQUIREMENTS hdr



03700011 - 006

Facility Name:

Permit Number:

A-141

NOx Emission Calculation and Recordkeeping: The Permittee shall calculate andrecord the 3-hour (arithmetic mean) lb/MMBtu of NOx using all of the 1-houraverages obtained during the previous 3-hour period.

Title I Condition: Recordkeeping associated withCAAA of 1990; Minn. R. 7007.0800, subp. 5

NOx and CO Calculations and Recordkeeping: The Permittee shall calculate andrecord daily and 365-day rolling sum NOx and CO emissions from EU-073, EU-074and EU-075. NOx emissions shall be calculated using 0.045 lb/mmBtu, unless adifferent emission factor is developed by the Permittee and approved by the MPCAin accordance with Minn. R. 7019.3040 to 7019.3100. CO emissions shall bebased on fuel combustion rate and lb/MMBtu emissions.

Title I Condition: Recordkeeping for a limit to avoidclassification as a major modification under 52.21;Minn. R. 7007.0800, subp. 5

E. CMS REQUIREMENTS hdr

Fuel Flowrate: The Permittee shall operate, and maintain continuous monitoringsystem (CMS) that record the fuel flowrate at each fuel combustion device.

Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4

F. O2 MONITOR REQUIREMENTS hdr

Firebox O2: The Permittee shall operate, and maintain a CMS that records the O2in the common convection section at 32H-5/6/7.

Minn. R. 7007.0800, subp. 4

Monitor QA/QC: The Permittee shall follow manufacturer recommendations forpreventative maintenance and periodic monitoring to ensure analyzer reliability,including but not limited to annual calibrations.

Minn. R. 7007.0800, subp. 4

G. PERFORMANCE TEST REQUIREMENT hdr

Performance Test: due before end of each 36 months starting 03/30/2008 for NOxemissions.

Minn. R. 7017.2020, subp. 1

Performance Test: due 60 days after Initial Startup of EU 324 (25H4) or by03/30/2008, whichever date is later, to measure CO emissions

Minn. R. 7017.2020, subp. 1

Performance Test Pre-test Meeting: due 7 days before Performance Test Minn. R. 7017.2030, subp. 4



03700011 - 006

Facility Name:

Permit Number:

A-142


Associated Items: EU 093 Naphtha Hydrotreater Charge Heater

EU 094 Naphtha Hydotreater Stripper Reboiler

EU 098 Platformer Stabilizer Reboiler Heater



MR 138 37H6 Fuel Gas Flowmeter

MR 169 37H1 2 6 O2 Analyzer for NOx


Nitrogen Oxides: less than or equal to 17.7 tons/year using 365-day Rolling Sumeffective upon startup of EU 324 (25H-4).


Nitrogen Oxides: less than or equal to 0.045 lbs/million Btu heat input using 3-hourRolling Average effective upon installation of the ultra low NOx burners.



Daily Recordkeeping: Record and maintain records of the type and amount of eachfuel combusted in each heater on a daily basis

Minn. R. 7007.0800, subp. 5

To determine compliance with the NOx limit based on a 365-day rolling sum, thePermittee shall calculate and record the rolling sum each calendar day. For thefirst 364 days of operation, the rolling sum shall be calculated each day based ontotal actual emissions since initial startup of EU 324 (25H-4). For the first 364 daysof operation, daily compliance shall be demonstrated when the following formula istrue:N < 2.61 + 0.0414nWhere:N = total actual NOx emissions through day n (tpy)n = number of days since initial startup


C. MONITORING hdr

Monitoring for NOx Emissions: The Permittee shall continuously monitor fuelcombustion rate. The Permittee shall use the most recent performance test todemonstrate compliance with the lb/MMBtu and tons/year emission limits.


D. RECORDKEEPING hdr

NOx Calculations and Recordkeeping: The Permittee shall calculate and recorddaily and 365-day rolling sum NOx emissions from EU 093, EU 094 and EU 098.NOx emissions based on fuel combustion rate and lb/MMBtu emissions.



Fuel Flowrate: The Permittee shall operate, and maintain a continuous monitoringsystem (CMS) at each fuel combustion device that records the fuel flow rate.

Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4

F. PERFORMANCE TESTING hdr

Performance Test: due 180 days after Initial Startup of EU 324 (25H4) to measureNOx emissions

Minn. R. 7017.2020, subp. 1




03700011 - 006

Facility Name:

Permit Number:

A-143


Associated Items: EU 095 Platformer Charge Heater (Grouped with EU 095/096/097)



MR 130 37H-3/4/5 NOx Analyzer

MR 131 37H-3/4/5 CO Analyzer

MR 132 37 O2 Percent





Nitrogen Oxides: less than or equal to 0.045 lbs/million Btu heat input using 3-hourRolling Average (Consent Decree driven - effective upon installation of ULNB andsuccessful performance demonstration using existing CEMS).


Carbon Monoxide: less than or equal to 50.0 tons/year using 365-day Rolling Sumeffective upon startup of EU 324 (25H-4).

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


40 CFR Section 60.104(a)(1); 40 CFR Section 60.8(c);Minn. R. 7011.1435

Total Particulate Matter: less than or equal to 0.4 lbs/million Btu heat input using3-hour Rolling Average . The PTE of each heater is 0.00745 lb/mmBtu heat inputat maximum capacity. Compliance with the fuel restriction requirement constitutescompliance with this limit.

Minn. R. 7011.1410, subp. 3. B

Sulfur Dioxide: less than or equal to 1.75 lbs/million Btu heat input using 3-hourRolling Average . Compliance with the fuel restriction constitutes compliance withthis limit.

Minn. R. 7011.1410, subp. 3. A

Opacity: less than or equal to 20 percent opacity ; except for one six-minute periodper hour of not more than 60 percent opacity. (Limit applies to each unit).Compliance with the fuel restriction requirement constitutes compliance with thislimit.

Minn. R. 7011.1410, subp. 3. B


Fuel Restriction: Authorized to burn refinery fuel gas and natural gas only. Minn. R. 7007.0800, subp. 2

Recordkeeping: Record and maintain records of each fuel combusted in the unit ona monthly basis.

Minn. R. 7007.0800, subp. 5


Alternative Monitoring Plan (AMP): The Permittee shall continue to monitor theH2S in Platformer recycle hydrogen less than or equal to 5 ppmV; If the H2S isgreater than 5 ppmV, the Permittee shall increase monitoring per flowchart in theapproved AMP.

40 CFR Section 60.104(a)(1); Minn. R. 7011.1435 A

Alternative Monitoring Plan (AMP): If the Draeger shows greater than 81 ppm H2Sin the fuel gas stream monitored under AMP, the Permittee shall increasemonitoring per flowchart in approved NSPS, subpart J AMP.


Once a Week Measurement of H2S: Once a week, the Permittee shall measureH2S in Platformer recycle hydrogen using Draeger or other length-of-stain tubes.


D. CEM REQUIREMENTS FOR NOx hdr

Emissions Monitoring: The Permittee shall calibrate, operate and maintain NOxcontinuous emissions monitoring system (CEMS).

CAAA of 1990; Minn. R. 7017.1006; Minn. R.7007.0800, subp. 4

NOx Emissions Measuring: The Permittee shall use a NOx CEMS to measure NOxemissions from SV 083 by December 31, 2006.

Minn. R. 7017.1006

Calculation: The Permittee shall calculate valid hourly average emissions fromCEMS. Effective December 31, 2006.

Minn. R. 7017.1160, subps 1,2 & 3



03700011 - 006

Facility Name:

Permit Number:

A-144

To determine compliance with the CO limit based on a 365-day rolling sum, thePermittee shall calculate and record the rolling sum each calendar day. For thefirst 364 days, the rolling sum shall be calculated each day based on total actualemissions since initial startup of EU 324 (25H-4). For the first 364 days ofoperation, daily compliance shall be demonstrated when the following formula istrue:N < 7.38 + 0.117nWhere:N = total actual CO emissions through day nn = number of days since initial startup of EU 324 (25H-4)

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

E. CEM REQUIREMENTS FOR CO hdr

Emissions Monitoring: The Permittee shall calibrate, operate and maintain COcontinuous emissions monitoring system (CEMS).

Minn. R. 7017.1006; Minn. R. 7007.0800, subp. 4

Emissions Measuring: The Permittee shall use a CO CEMS to measure COemissions from SV 083.

Minn. R. 7017.1006; Minn. R. 7007.0800, subp. 4

Calculation: The Permittee shall calculate valid hourly average emissions fromCEMS.

Minn. R. 7017.1160, subps 1, 2 & 3

F. REQUIREMENTS FOR ALL CEMS hdr

CEMS Certification Test: due within 90 days after the due date of the first excessemissions report required for the CEMS. Follow the Performance Specificationslisted in 40 CFR pt. 60, Appendix B.

Minn. R. 7017.1050, subp. 1

CEM Certification Test Pretest Meeting: due 7 days before CEM Certification Test Minn. R. 7017.1060, subp. 3


Minn. R. 7017.1170, subp. 3






Minn. R. 7017.1090, subp. 1



Minn. R. 7017.1090, subp. 2


Minn. R. 7017.1170, subp. 2


Minn. R. 7017.1130

G. O2 MONITOR REQUIREMENTS hdr



03700011 - 006

Facility Name:

Permit Number:

A-145

QA Plan: Develop and implement a written quality assurance plan that covers theO2 Monitor. The plan shall be on site and available for inspection within 30 daysafter monitor certification. The plan shall contain all of the information required by40 CFR 60, App. F, section 3.

Minn. R. 7007.0800, subp. 4

O2 QA/QC: The owner or operator of an affected facility is subject to theperformance specifications listed in 40 CFR 60, Appendix B and shall operate,calibrate, and maintain the O2 monitor according to the QA/QC procedures in 40CFR pt. 60, Appendix F as amended and maintain a written QA/QC programavailable in a form suitable for inspection.

Minn. R. 7007.0800, subp. 4

H. RECORDKEEPING REQUIREMENT hdr

Recordkeeping: Once a week, the Permittee shall record the H2S in Platformerrecycle hydrogen.


I. REPORTING REQUIREMENTS hdr

Report: due if H2S in Platformer recycle hydrogen exceeds 5 ppmv and increasedmonitoring is triggered under the AMP.

40 CFR Section 60.104(a)(1); 40 CFR Section60.105(e); 40 CFR Section 60.107(f); 40 CFR Section60.19; 40 CFR Section 60.4; Minn. R. 7007.0500,subp. 3; Minn. R. 7011.1435 A

Report: due if the Draeger shows greater than 81 ppm H2S in fuel gas streammonitored under Alternative Monitoring Plan (AMP) and increased monitoring istriggered under the AMP.







03700011 - 006

Facility Name:

Permit Number:

A-146

Subject Item: SV 093 45H61 Stack





EU 260 Incinerator for SRU4 Bypasses of TGTU1 SRU3/4 Sulfur Degassing SW TK Purge Gas

GP 112 Sulfur Recovery Units

MR 078 EMRC Temperature Thermocouple for TGTU1



MR 087 45H61 Fuel Gas Flow

MR 090 EMRC Flow Meter for TGTU1

MR 139 45 CO ppm


Sulfur Dioxide: less than or equal to 149.0 lbs/hour using 3-hour Rolling Average .The company shall use CEMS to monitor the sulfur dioxide emissions in order tocalculate pounds of sulfur dioxide per hour (lb/hr).





Sulfur Dioxide: less than or equal to 250 parts per million by volume (dry, 0%oxygen), using 12-hour Rolling Average. Limit does not apply during startup,shutdown, or malfunction.

40 CFR Section 63.1568(a)(1); 40 CFR Section60.104; 40 CFR Section 60.105; 40 CFR Section60.8(c); Minn. R. 7011.1435. A.

Sulfur Dioxide: less than or equal to 200 parts per million (dry, at 0% oxygen) using12-hour Rolling Average for SRU #3 and SRU #4 only. This limit was consolidatedbased on previous limits. While the limit is a LAER limit, the Permittee will complywith the requirements listed in 40 CFR pt. 60, subp. J for these units (monitoring,recordkeeping and reporting).

Title I Condition: LAER Limit; 40 CFR pt. 51, AppendixS

Sulfur Dioxide: less than or equal to 149.0 lbs/hour using 1-Hour Average . This isa state-only requirement and it is not enforceable by the EPA administrator orcitizens under the Clean Air Act.

Minn. R. 7009.0080


40 CFR 60.104(a)(1); Minn. R. 7011.1410, subp. 2

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


SO2 Concentration Recordkeeping: The Permittee shall record on an hourlyaverage of SO2 in ppm (dry, 0% oxygen).

Title I Condition: Recordkeeping associated withLAER Limit, 40 CFR pt. 51, Appendix S

SO2 Emission Calculations and Recordkeeping: The Permittee shall maintainrecords of the calculated SO2 emissions of hourly average of total stack SO2emissions in lb/hr.

Title I Condition: SIP for SO2 NAAQS 40 CFR pt. 50;MN State Implementation Plan (SIP); Minn. R.7009.0080;

Total SO2 Emissions Recordkeeping: The Permittee shall calculate and record thetotal SO2 emissions (including sulfur degassing and bypasses) at stack in ppm (at0% oxygen)

Title I Condition: CAAA of 1990; Minn. R. 7007.0800,subp. 5; Minn. R. 7011.1435.A.

SO2 Emission Calculation and Recordkeeping: The Permittee shall maintainrecords of the calculated SO2 emissions of total stack SO2 emissions in tons/year.


C. CEM REQUIREMENTS FOR SO2 AND CO hdr

SO2 and CO Emissions Monitoring: The Permittee shall calibrate, operate andmaintain SO2 and CO Continuous Emissions Monitoring System (CEMS).

Title I Condition: SIP for SO2 NAAQS 40 CFR pt. 50;MN State Implementation Plan (SIP); CAAA of 1990;40 CFR Section 63.1568(b)(1); Minn. R. 7017.1006

SO2 and CO Emissions Measuring: The Permittee shall use a SO2 CEMS tomeasure SO2 emissions and CO CEMS to measure CO emissions from SV 093.

40 CFR Section 63.1568(b)(1); Minn. R. 7017.1006



03700011 - 006

Facility Name:

Permit Number:

A-147








Minn. R. 7017.1170, subp. 3


Minn. R. 7017.1090, subp. 1





Minn. R. 7017.1170, subp. 2


Minn. R. 7007.1130

D. OTHER REQUIREMENTS hdr



Monitoring SRU 3 and 4 SO2 concentration: The Permittee shall monitor andrecord the total SRU 3 and 4 SO2 emissions (including sulfur degassing andbypasses) at stack ppm (at 0% oxygen).

CAAA of 1990; Minn. R. 7007.0800, subp. 5; Minn. R.7011.1435

E. O2 MONITOR REQUIREMENTS hdr


Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4

F. REPORTING REQUIREMENTS hdr

G. NATIONAL EMISSION STANDARDS FOR HAZARDOUS AIR POLLUTANTS hdr



03700011 - 006

Facility Name:

Permit Number:

A-148

The Permittee shall comply with 40 CFR pt. 63, subp. UUU by compliance date,April 11, 2005.




03700011 - 006

Facility Name:

Permit Number:

A-149

Subject Item: SV 095 Common Boilerhouse Stack






GP 001 Boiler Nos. 1,2,3 and 4


Sulfur Dioxide: less than or equal to 43.4 lbs/hour using 3-hour Rolling Average .The Permittee shall use CEMS to monitor the sulfur dioxide emissions in order tocalculate pounds of sulfur dioxide per hour (lb/hr). This is a combined limit for allthe boilers. Compliance witht the fuel restriction and H2S limit requirementconstitutes compliance with the SIP limits.


Sulfur Dioxide: less than or equal to 43.4 lbs/hour using 24-hour Rolling Average .This is a combined limit for all the boilers.


Sulfur Dioxide: less than or equal to 190.2 tons/year using 12-month RollingAverage . This is a combined limit for all the boilers.


Total Particulate Matter: less than or equal to 0.4 lbs/million Btu heat input using3-hour Rolling Average . Compliance with the fuel restriction requirementconstitutes compliance with this limit.

Minn. R. 7011.1410, subp. 3. B.

Opacity: less than or equal to 20 percent opacity using 6-minute Average ; exceptfor one six-minute period per hour of not more than 60 percent opacity. (Limitapplies to each unit.)

Minn. R. 7011.1410, subp. 3. B.

Hydrogen Sulfide: less than or equal to 0.186 grains/dry standard cubic foot using1-Hour Average (300 ppm). This is a state-only requirement and it is notenforceable by the EPA Administrator and citizens under the Clean Air Act

Minn. R. 7009.0080 (most stringent; meet the limits setby SIP and Minn. R. 7011.1410, subp. 3. A)


Fuel Restriction: Authorized to burn refinery fuel gas and natural gas only. Title I Condition: SIP for SO2 NAAQS 40 CFR pt. 50;MN State Implementation Plan (SIP)


Minn. R. 7007.0800, subp. 5


SO2 Emission Calculation and Recordkeeping: The Permittee shall maintainrecords of the calculated SO2 emissions of hourly average of total stack SO2emissions in lb/hr.

Title I Condition: Recordkeeping associated with SIPfor SO2 NAAQS, 40 CFR pt. 50; MN StateImplementation Plan (SIP)

SO2 Emission Calculation and Recordkeeping: The Permittee shall maintainrecords of the calculated SO2 emissions of total stack SO2 in tons per year.




03700011 - 006

Facility Name:

Permit Number:

A-150

Subject Item: SV 165 New Hydrocracker Feed Heater and Reboiler



MR 179 29H-1/2 NOx Monitor

MR 180 29H-1/2 CO Monitor

MR 181 29H-1/2 O2 Monitor

What to do Why to do itNitrogen Oxides: less than or equal to 46.5 tons/year using 365-day Rolling Sum(based on maximum duty of 141 mmbtu/hr on EU 294 and 100 mmbtu/hr on EU294).


Emissions Monitoring: The owner or operator shall use a NOx CEMS to measureNOx emissions from SV 165. Monitoring requirements are located under thesubject item MR 179.




03700011 - 006

Facility Name:

Permit Number:

A-151

Subject Item: EU 004 New Truck Bottom Loading (gas, distillate) including the trucks (replaces EU4)

Associated Items: CE 003 Activated Carbon Adsorption

CE 050 Flaring

CE 058 Other

GP 017 Loading Rack Activities in CFP group limit

MR 004 VOC Monitor at Bottom Loading Unit

SV 003 BT Load VRU Stack

SV 159 Stack Vent at the Enclosed Flare at Bottom Loading


Volatile Organic Compounds: less than or equal to 10 milligrams/liter of totalorganic compounds per liter of gasoline loaded.


Total VOC concentration: equal to 2350 parts per million by Volume (ppmV) using a6-hour Average at the vapor recovery unit outlet which demonstrate compliancewith the emission standard at 40 CFR Section 63.422(b).

40 CFR Section 63.422 (c); Minn. R. 7011.2025

Volatile Organic Compounds: less than or equal to 50.2 tons/year using 12-monthRolling Sum

Title I Condition: Limit to avoid classification as a majormodification under 40 CFR 52.21

Hydrogen Sulfide: less than or equal to 0.10 grains/dry standard cubic foot using3-hour Rolling Average (230 mg/dscm[162 ppm]). This limit applies to thehydrogen sulfide content of fuel gases burned in the enclosed flare.

40 CFR 60.104(a)(1); Minn. R. 7011.1490, subp. 2

Opacity: less than or equal to 20 percent opacity Minn. R. 7011.0110; Minn. R. 7011.0120

B. RECORDKEEPING AND CALCULATION REQUIREMENTS hdr

Calculation of VOC Emissions from the Loading Rack: By the 28th day of eachmonth, the Permittee shall calculate and record VOC emissions from the loadingrack using the following equation:

VOC Emissions = Q x 42 gal/bbl x LL x (1-CE/100) x (1 ton/2000 lbs)

where:Q = product throughput (thousand barrels per month)LL = 12.46 x S x P x M/T = factor for barge loading of distillate and all truck and railloading (AP-42, 5th Edition, Section 5.2)

where:S = saturation factor0.6 for Tank Trucks - Submerged Loading, dedicated normal service ( AP-42, 5thEdition)P = true vapor pressure of product loaded, psiaM = molecular weight of vapors, lb/lb-molT = temperature of product loaded, degree RCE = control efficiency of control equipment (98.2 % for the VRU [CE 003] or 97.2%for the enclosed flare [CE 050])The Permittee shall use the most recent AP-42 emission factors to calculateemissions.

Title I Condition: Calculation associated with a limit toavoid classification as a major source under 40 CFR52.21

Recordkeeping of VOC Emissions from the Loading Rack: By the 28th day of eachmonth, the Permittee shall record the following:

Total VOC emissions from the loading rack for the previous month; andThe 12-month rolling sum of VOC emissions from the loading rack for the previous12-month period.

Title I Condition: Recordkeeping associated with alimit to avoid classification as a major source under 40CFR 52.21

C. POLLUTION CONTROL EQUIPMENT REQUIREMENTS hdr

The Permittee shall operate and maintain the enclosed flare (CE 050) duringloading any time that the vapor recovery unit (CE 003) is not being operated tocontrol emissions from the Bottom Loading Rack (EU 004).

Minn. R. 7007.0800, subps. 2 and 14

See Monitoring Requirements under CE 003 and CE 050. Minn. R. 7007.0800, subp. 4

D. PERFORMANCE TEST REQUIREMENT hdr



03700011 - 006

Facility Name:

Permit Number:

A-152

Performance Test: due before end of each 60 months starting 07/22/2003 forVOCs. The first performance test required under this condition must be completedby July 22, 2008.

Minn. R. 7017.2020, subp. 1



03700011 - 006

Facility Name:

Permit Number:

A-153

Subject Item: EU 005 #1 Crude Heater atmospheric distillation

Associated Items: MR 009 11H1 Fuel Gas Flowmeter

SV 004 11H1 Stack


Sulfur Dioxide: less than or equal to 12.8 lbs/hour using 3-hour Rolling Average Title I Condition: SIP for SO2 NAAQS, 40 CFR pt. 50;MN State Implementation Plan (SIP) (most stringent,meets the limit set by Minn. R. 7011.1410, subp. 3.Item A)


Sulfur Dioxide: less than or equal to 55.9 tons/year using 12-month Rolling Average Title I Condition: SIP for SO2 NAAQS, 40 CFR pt. 50;MN State Implementation Plan (SIP)

Nitrogen Oxides: less than or equal to 23.6 tons/year using 365-day RollingAverage




Hydrogen Sulfide: less than or equal to 0.186 grains/dry standard cubic foot using1-Hour Average (300 ppm). This is a state-only requirement and it is notenforceable by the EPA Administrator and citizens under the Clean Air Act

Minn. R. 7009.0080


Minn. R. 7011.1410, subp. 3. B.


Minn. R. 7011.1410, subp. 3. B.


Fuel Restriction: Authorized to burn refinery gas and natural gas only. Title I Condition: SIP for SO2 NAAQS, 40 CFR pt. 50;MN State Implementation Plan (SIP)


Minn. R. 7007.0800, subp. 5


NOx Emission Calculation and Recordkeeping: The Permittee shall calculate andrecord daily and 365-day rolling average NOx emissions from EU 005.

Title I Condition: Recordkeeping associated withNetting limit 40 CFR Section 52.21

SO2 Emission Calculations and Recordkeeping: The Permittee shall maintainrecords of the calculated SO2 emissions of hourly average of total stack SO2emissions in lb/hr.

Title I Condition: SIP for SO2 NAAQS 40 CFR pt. 50;MN State Implementation Plan (SIP); Minn. R.7009.0080

SO2 Emission Calculations and Recordkeeping: The Permittee shall maintainrecords of the calculated SO2 emissions of total stack SO2 emissions in tons/year.


D. CMS REQUIREMENTS hdr

Fuel Flowrate: The Permittee shall calibrate, operate, and maintain continuousmonitoring system (CMS) that record the fuel flowrate at each fuel combustiondevice.



Minn. R. 7007.0800, subp. 4

E. REPORTING REQUIREMENT hdr



03700011 - 006

Facility Name:

Permit Number:

A-154

Subject Item: EU 006 #1 Crude Heater crude preflash

Associated Items: MR 105 11H2 Fuel Gas Flowmeter

SV 005 11H2 Stack


Nitrogen Oxides: less than or equal to 0.045 lbs/million Btu heat input using 3-hourRolling Average (Consent Decree driven - effective following installation of ULNBand successful performance testing)


Hydrogen Sulfide: less than or equal to 0.1 grains/dry standard cubic foot using3-hour Rolling Average (230mg/dscm[162ppm). This limit does not apply duringperiods of startup, shutdown or malfunction.

40 CFR 60.104(a); Minn. R. 7011.1410, subp. 2; (moststringent; meets limit set by Minn. R. 7011.1410, subp.,2)


Minn. R. 7011.1405, subp. 3. A.


Minn. R. 7011.1405, subp. 3. B.

Sulfur Dioxide: less than or equal to 1.75 lbs/million Btu heat input using 3-hourRolling Average . Compliance with the fuel restriction and hydrogen sulfiderequirements constitutes compliance with this limit.

Minn. R. 7011.1405, subp. 2




Minn. R. 7007.0800, subp. 5

Fuel Usage: less than or equal to 57 million Btu/hour using 8-hour Block Averagebased on the higher heating value of fuel burned. Downtime of 15 or more minutesis not to be included as operating time.


Minn. R. 7017.2025


Minn. R. 7007.0800, subp. 5

C. CMS REQUIREMENT hdr


Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4

C. PERFORMANCE TEST REQUIREMENT hdr

Performance Test: due 180 days after Initial Startup of heater following ULNBinstallation to measure NOx emissions.

Minn. R. 7017.2020, subp. 1

Performance Test: due before end of each 36 months starting 12/19/2006 tomeasure NOx emissions.

Minn. R. 7017.2020, subp. 1




03700011 - 006

Facility Name:

Permit Number:

A-155

Subject Item: EU 016 Vacuum Pre-Strip Heater

Associated Items: MR 010 12H4 Firebox O2


SV 015 12H4 Stack

What to do Why to do itA. EMISSION LIMITS

hdrNitrogen Oxides: less than or equal to 27.2 tons/year using 365-day RollingAverage

Title I Condition: Netting Limit for NOx, 40 CFR Section52.21


40 CFR Section 60.104(a)(1); 40 CFR Section60.105(e)(3)(ii); 40 CFR Section 60.8(c); Minn. R.7011.1435 A [Most stringent; meets limit set by Minn.R. 7011.1410, subp. 3]

Hydrogen Sulfide: less than or equal to 0.186 grains/dry standard cubic foot using1-Hour Average ( 300 pppm). This is a state-only requirement and is notenforceable by the EPA Administrator and citizens under the Clean Air Act.

Minn. R. 7009.0080

Sulfur Dioxide: less than 1.75 lbs/million Btu heat input using 3-hour RollingAverage . Compliance with the fuel restriction and hydrogen sulfide requirementsconstitutes compliance with this limit.

Minn. R. 7011.1410, subp. 3. A


Minn. R. 7011.1410, subp. 3. B


Minn. R. 7011.1410, subp. 3, B.




Minn. R. 7007.0800, subp. 5

Fuel Usage: less than or equal to 121.1 million Btu/hour using 8-hour BlockAverage based on the higher heating value of fuel burned. Downtime of 15 or moreminutes is not to be included as operating time.


Minn. R. 7017.2025


Minn. R. 7007.0800, subp. 5

C. MONITORING REQUIREMENT hdr

Monitoring for NOx emissions: The Permittee shall continuously monitor fuelcombustion rate and stack O2. The Permittee shall use the most recent correlationto determine NOx lb/MMBtu emissions on an hourly basis.

Minn. R. 7007.0800, subp. 4


Performance Test: due before end of each 60 months starting 11/16/2006 tomeasure NOx emissions from SV 015.

For additional applicable performance test requirements see "General PerformanceTest Requirements" in Table A, subject item "Total Facility".

Minn. R. 7017.2020, subp. 1

E. CMS REQUIREMENT hdr


Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4




03700011 - 006

Facility Name:

Permit Number:

A-156

Firebox O2: The Permittee shall operate, and maintain a CMS that records thefirebox O2.

Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4

G. RECORDKEEPING AND REPORTING REQUIREMENTS hdr


Title I Condition: Recordkeeping associated withNetting limit 40 CFR Section 52.21



03700011 - 006

Facility Name:

Permit Number:

A-157

Subject Item: EU 019 #2 Vac Heater

Associated Items: MR 013 16H1 O2 Monitor

MR 014 16H1 CO Monitor

MR 015 16H1 NOx Monitor


SV 017 16H1 Stack


Sulfur Dioxide: less than or equal to 15.3 tons/year using 365-day Rolling Average Title I Condition: Netting limit for SO2, 40 CFR Section52.21 (most stringent, meets the limit set by Minn. R.7011.1410, subp. 3. A)




40 CFR Section 60.104(a)(1); 40 CFR Section60.105(e)(3)(ii); 40 CFR Section 60.8(c); Minn. R.7011.1435 A; (most stringent, meets limit set by Minn.R. 7011.1410, subp. 3)

Hydrogen Sulfide: less than or equal to 0.186 grains/dry standard cubic foot using1-Hour Average (300 ppm). This is a state-only requirement and it is notenforceable by the EPA administrator or citizens under the Clean Air Act.

Minn. R. 7009.0080


Minn. R. 7011.1410, subp. 3. B.


Minn. R. 7011.1410, subp. 3. B.


Fuel Restriction: Authorized to burn refinery gas and natural gas only. Minn. R 7007.0800, subp. 2


Minn. R. 7007.0800, subps. 4 and 5


SO2 Emission Calculation and Recordkeeping: The Permittee shall calculate andrecord daily and 365-day rolling average SO2 emissions from EU 019.

Title I Condition: Recordkeeping associated withNetting limit 40 CFR Section 52.21(j)(3)

D. CEMS REQUIREMENTS FOR CO AND NOx hdr

Emissions Monitoring: The Permittee shall calibrate, operate and maintain CO andNOx continuous emissions monitoring system (CEMS).

Minn. R. 7017.1006; Minn. R. 7007.0800, subp. 4

CO and NOx Emissions Measuring: The Permittee shall use a CO CEMS and NOxCEMS to measure CO and NOx emissions from SV 017.

Minn. R. 7017.1006


Minn. R. 7017.1160, subps 1,2 &3








Minn. R. 7017.1170, subp. 3



03700011 - 006

Facility Name:

Permit Number:

A-158







Minn. R. 7017.1170, subp. 2


Minn. R. 7017.1130



Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4



Minn. R. 7007.0800, subp. 4

G. REPORTING REQUIREMENT hdr



03700011 - 006

Facility Name:

Permit Number:

A-159

Subject Item: EU 026 #1 Vac Heater

Associated Items: MR 026 19H1 Fuel Gas Meter

SV 025 19H1 Stack


Sulfur Dioxide: less than or equal to 6.5 lbs/hour using 3-hour Rolling Average Title I Condition: SIP for SO2 NAAQS, 40 CFR pt. 50;MN State Implementation Plan (SIP) (most stringent,meets the limit set by Minn. R. 7011.1410, subp. 3. A)




Title I Condition: Netting Limit for NOx, 40 CFR Section52.21



Hydrogen Sulfide: less than or equal to 0.186 grains/dry standard cubic foot using1-Hour Average ( 300 ppm). This is a state-only requirement and pursuant to theMinn. R. 7007.1750, it is not enforceable by the EPA administrator or citizens underthe Clean Air Act.

Minn. R. 7009.0080


Minn. R. 7011.1410, subp. 3.B.


Minn. R. 7011.1410, subp. 3.B.



Fuel Usage: less than 142.0 million Btu/hour using 8-hour Block Average For NOxemissions based on the higher heating value of fuel burned. Downtime of 15 ormore minutes is not to be included as operating time.


Minn. R. 7017.2025


Minn. R. 7007.0800, subp. 5


SO2 Emissions Calculations and Recordkeeping: The Permittee shall maintainrecords of the calculated SO2 emissions of hourly average of total stack SO2emissions in lb/hr.

Title I Condition: SIP for SO2 NAAQS 40 CFR pt. 50;MN State Implementation Plan (SIP); Minn. R.7009.0080

SO2 Emissions Calculations and Recordkeeping: The Permittee shall maintainrecords of the calculated SO2 emissions of total stack SO2 emissions in tons/year.



Title I Condition: Recordkeeping associated withNetting Limit 40 CFR Section 52.21

D. PERFORMANCE TEST REQUIREMENTS hdr



Minn. R. 7017.2020, subp. 1



Minn. R. 7007.0800, subp. 4



03700011 - 006

Facility Name:

Permit Number:

A-160


Minn. R. 7007.0800, subp. 4

E. REPORTING REQUIREMENT hdr



03700011 - 006

Facility Name:

Permit Number:

A-161

Subject Item: EU 028 #1 Coker Heater

Associated Items: MR 108 21H-1 West Fuel Gas Flowmeter

MR 109 21H-1 East Fuel Gas Flowmeter

SV 027 21H1S Stack

SV 028 21H1N Stack

What to do Why to do itA. POLLUTANT LIMITS hdr

Sulfur Dioxide: less than or equal to 5.5 lbs/hour using 3-hour Rolling Average Title I Condition: SIP for SO2 NAAQS, 40 CFR pt. 50;MN State Implementation Plan (SIP) (most stringent,meets the limit set by: Minn. R. 7011.1410, subp. 3. A)




40 CFR 60.104(a)(1); Minn. R. 7011.1410, subp. 2


Minn. R. 7011.1410, subp. 3.B.


Minn. R. 7011.1410, subp. 3.B.




Minn. R. 7007.0800, subp. 5

Heat Input: less than or equal to 147.6 million Btu/hour on an instantaneous basis.Heat input is calculated using the higher heating value (HHV) of fuel burned.

This heat input rate is the emission factor threshold (EFT) for calculating NOx andCO emissions from this unit. NOx and CO emissions from operations at or belowthe EFT are calculated using factors measured during the most recent emissionsfactor performance test. NOx and CO emissions from operations above the EFTare calculated using the emission factor in AP-42 chapter 1.4 table 1.4-1 for largewall-fired pre-NSPS boilers (corrected to the HHV for fuel type). The Permitteemay also use other factors after receipt of written MPCA approval from the MPCAEmission Inventory program for use of such factors.

Minn. R. 7007.0800, subp. 2

Recordkeeping of Heat Input: When the unit is operating the Permittee shall recordheat input at intervals no greater than 15 minutes.

Minn. R. 7007.0800, subp. 5


SO2 Emission Calculation and Recordkeeping: The Permittee shall maintainrecords of the calculated SO2 emissions of hourly average of total SO2 emissionsin lb/hr.


SO2 Emission Calculation and Recordkeeping: The Permittee shall maintainrecords of the calculated SO2 emissions of total SO2 in tons per year.



Performance Test: due 3,653 days after 12/04/2003 to measure NOx and COemissions from SV 027/028. This is the emissions factor performance test fordetermining the NOx and CO emission factors and the EFT. The EFT is calculatedas 110% of the average mmBtu/hr operating rate of all test runs. The firstperformance test required under this condition must be completed by 12/04/2013 toretain use of stack test-based factors.


Minn. R. 7017.2020, subp. 1




03700011 - 006

Facility Name:

Permit Number:

A-162




Minn. R. 7007.0800, subp. 4



03700011 - 006

Facility Name:

Permit Number:

A-163


Associated Items: MR 110 21H-2 West Fuel Gas Flowmeter

MR 111 21H-2 East Fuel Gas Flowmeter

SV 029 21H2S Stack

SV 030 21H2N Stack






40 CFR 60.104(a)(1); Minn. R. 7011.1410, subp. 2


Minn. R. 7011.1410, subp. 3. B.


Minn. R. 7011.1410, subp. 3. B.




Minn. R. 7007.0800, subp. 5


This heat input rate is the emission factor threshold (EFT) for calculating NOx andCO emissions from this unit. NOx and CO emissions from operations at or belowthe EFT are calculated using factors measured during the most recent emissionsfactor performance test. NOx and CO emissions from operations above the EFTare calculated using the emission factor in AP-42 chapter 1.4 table 1.4-1 for largewall-fired pre-NSPS boilers (corrected to the HHV for fuel type). The Permitteemay also use other factors after receipt of written MPCA approval from the MPCAEmission Inventory program for use of such factors.

Minn. R. 7007.0800, subp. 2


Minn. R. 7007.0800, subp. 5







Performance Test: due 3,653 days after 12/03/2003 to measure NOx and COemissions from SV 029/030. This is the emissions factor performance test fordetermining the NOx and CO emission factors and the EFT. The EFT is calculatedas 110% of the average mmBtu/hr operating rate of all test runs. The firstperformance test required under this condition must be completed by 12/03/2013 toretain use of stack test-based factors.


Minn. R. 7017.2020, subp. 1




03700011 - 006

Facility Name:

Permit Number:

A-164




Minn. R. 7007.0800, subp. 4



03700011 - 006

Facility Name:

Permit Number:

A-165

Subject Item: EU 032 Steam/Air Heater Decoking - 21H-1

Associated Items: CE 007 Gas Scrubber (General, Not Classified)

SV 031 21H1 Decoke Pit Stack

What to do Why to do itOperating Hours: less than or equal to 432 hours/year using 12-month Rolling Sumfor steam-air decoking operation.


Recordkeeping: The Permittee shall monitor the start and stop times for heaterdecoking and compute the hours of heater decoking operations.

Minn. R. 7007.0800, subp. 5



03700011 - 006

Facility Name:

Permit Number:

A-166

Subject Item: EU 033 Steam/Air Heater Decoking - 21H-2

Associated Items: CE 007 Gas Scrubber (General, Not Classified)

SV 031 21H1 Decoke Pit Stack




Minn. R. 7007.0800, subp. 5



03700011 - 006

Facility Name:

Permit Number:

A-167


Associated Items: MR 112 23H-1 South Fuel Gas Flowmeter

MR 113 23H-1 North Fuel Gas Flowmeter

SV 032 23H1 Stack






40 CFR 60.104(a)(1); Minn. R. 7011.1410, subp. 2


Minn. R. 7011.1410, subp. 3. B


Minn. R. 7011.1410, subp. 3. B.




Minn. R. 7007.0800, subp. 5


This heat input rate is the emission factor threshold (EFT) for calculating NOx andCO emissions from this unit. NOx and CO emissions from operations at or belowthe EFT are calculated using factors measured during the most recent emissionsfactor performance test. NOx and CO emissions from operations above the EFTare calculated using the emission factor in AP-42 chapter 1.4 table 1.4-1 for largewall-fired boilers controlled with Low NOx burners (corrected to the HHV for fueltype). The Permittee may also use other factors after receipt of written MPCAapproval from the MPCA Emission Inventory program for use of such factors.

Minn. R. 7007.0800, subp. 2


Minn. R. 7007.0800, subp. 5







Performance Test: due 3,653 days after 12/05/2003 to measure NOx and COemissions from SV 032. This is the emissions factor performance test fordetermining the NOx and CO emission factors and the EFT. The EFT is calculatedas 110% of the average mmBtu/hr operating rate of all test runs. The firstperformance test required under this condition must be completed by 12/05/2013 toretain use of stack test-based factors.


Minn. R. 7017.2020, subp. 1




03700011 - 006

Facility Name:

Permit Number:

A-168




Minn. R. 7007.0800, subp. 4



03700011 - 006

Facility Name:

Permit Number:

A-169


Associated Items: MR 027 23H-2 O2 Analyzer

MR 028 23H-2 Fuel Gas Flow Meter pass 1




SV 033 23H2 Stack


Nitrogen Oxides: less than or equal to 0.12 lbs/million Btu heat input using 365-dayRolling Average

Title I Condition: BACT Limit for NOx, 40 CFR 52.21

Carbon Monoxide: less than or equal to 0.10 lbs/million Btu heat input using 1-HourAverage

Title I Condition: BACT Limit for CO, 40 CFR 52.21


40 CFR 60.104(a)(1); Minn. R. 7011.1410, subp. 2;(most stringent, meets limit set by Minn. R. 7011.1410,subp. 3


Minn. R. 7011.1410, subp. 3


Minn. R. 7011.1410, subp. 3


Minn. R. 7011.1410, subp. 3




Minn. R. 7007.0800, subps. 4 and 5

Heat Input: less than or equal to 112.9 million Btu/hour using 8-hour Block Averagebased on the higher heating value of fuel burned. Downtime of 15 or more minutesis not included as operating time.

The unit may not be operated at a higher heat input rate unless a performance testis conducted at a higher rate and the Permittee receives written verification of thetest results from the MPCA.

Minn. R. 7007.0800, subp. 2

Recordkeeping of Heat Input: The Permittee shall calculate the average heat inputfor each 8-hour block by dividing the total heat input by the total operating time ineach 8-hour block. Downtime of 15 or more minutes is not included as operatingtime.

Minn. R. 7007.0800, subp. 5



Title I Condition: Monitoring associated with BACTLimit, 40 CFR Section 52.21(j)(3)

Monitoring for CO emissions: The Permittee shall continuously monitor fuelcombustion rate and stack O2. The Permittee shall use the most recent correlationto determine CO lb/MMBtu emissions on an hourly basis.


D. PERFORMANCE TEST REQUIREMENTS hdr

Performance Test: due before end of each 36 months starting 06/28/2007 tomeasure NOx and CO emissions from SV 033 for verifying the NOx/O2 and CO/02emissions correlations. The first correlations test required under this condition mustbe completed by 06/28/2010.


Minn. R. 7017.2020, subp. 1

E. RECORDKEEPING REQUIREMENTS hdr



03700011 - 006

Facility Name:

Permit Number:

A-170

NOx Emission Calculation and Recordkeeping: The Permittee shall calculate andrecord the 365-day average (arithmetic mean) lb/MMBtu of NOx using all of the1-hour averages obtained during the previous 365-day period.

Title I Condition: Recordkeeping associated with BACTLimit, 40 CFR Section 52.21(j)(3)

CO Emission Calculation and Recordkeeping: The Permittee shall calculate andrecord the 1-hour average (arithmetic mean) lb/MMBtu for CO emissions.


F. CMS REQUIREMENT hdr


Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4


QA Plan: Develop and implement a written quality assurance plan that covers theO2 Monitor. The plan shall be on site and available for inspection within 30 daysafter monitor certification. The plan shall contain all of the information required by40 CFR 60, App. F, section 3. This condition expires upon certification of theCEMS.

Minn. R. 7007.0800, subp. 4

O2 QA/QC: The owner or operator of an affected facility is subject to theperformance specifications listed in 40 CFR 60, Appendix B and shall operate,calibrate, and maintain the O2 monitor according to the QA/QC procedures in 40CFR pt. 60, Appendix F as amended and maintain a written QA/QC programavailable in a form suitable for inspection. This condition expires upon certificationof the CEMS.

Minn. R. 7007.0800, subp. 4



03700011 - 006

Facility Name:

Permit Number:

A-171

Subject Item: EU 037 Steam/Air Heater Decoking 23H-1

Associated Items: SV 035 P20 Decoke Pit Stack




Minn. R. 7007.0800, subp. 5



03700011 - 006

Facility Name:

Permit Number:

A-172

Subject Item: EU 038 Steam/Air Heater Decoking 23H-2

Associated Items: SV 036 25V53 Deaerator Vent Stack




Minn. R. 7007.0800, subp. 5



03700011 - 006

Facility Name:

Permit Number:

A-173

Subject Item: EU 040 #3 Crude Unit Charge Heater


MR 034 25H-1 Fuel Gas Flow Meter

MR 150 NOx Monitor at 25H1

MR 151 CO Monitor at 25H1

SV 037 25H1 Stack


Nitrogen Oxides: less than or equal to 0.045 lbs/million Btu heat input using 3-hourRolling Average (Consent Decree driven - effective following installation of ULNBand successful performance testing).









Minn. R. 7011.1410, subp. 3. A


40 CFR 60.104(a)(1); Minn. R. 7011.1410, subp. 2


Minn. R. 7011.1410, subp. 3. B


Minn. R. 7011.1410, subp. 3. B




Minn. R. 7007.0800, subp. 5

D. MONITORING REQUIREMENTS hdr

Monitoring for NOx emissions: The Permittee shall continuously monitor fuelcombustion rate and stack O2. The Permittee shall use the most recent correlationto determine NOx lb/MMBtu emissions on an hourly basis until the NOx CEMS iscertified.


Monitoring for CO emissions: The Permittee shall continuously monitor fuelcombustion rate and stack O2. The Permittee shall use the most recent correlationto determine CO lb/MMBtu emissions on an hourly basis until the CO CEMS iscertified.


E. RECORDKEEPING AND REPORTING REQUIREMENTS hdr

NOx Emission Calculation and Recordkeeping: The Permittee shall calculate andrecord the 365-day average (arithmetic mean) lb/MMBtu of NOx using all of the1-hour averages obtained during the previous 365-day period until the NOx CEMSis certified.


CO Emission Calculation and Recordkeeping: The Permittee shall calculate andrecord the 1-hour average (arithmetic mean) lb/MMBtu for CO emissions until theCO CEMS is certified.




03700011 - 006

Facility Name:

Permit Number:

A-174



F. CEM REQUIREMENTS FOR CO and NOx hdr

Emissions Monitoring for NOx: The Permittee shall install, operate and use anitrogen oxides (NOx) CEM to measure NOx emissions from SV 037.


Emission Monitoring for CO: The Permittee shall install, operate and use CO CEMto measure CO from SV 037

Minn. R. 7017.1006; Minn. R. 7007.0800, subp. 4

Installation Notification: due 60 days before installing the continuous emissionsmonitoring system.

Minn. R. 7017.1040, subp. 1


Minn. R. 7017.1050, subp. 1


CEMS QA/QC: The owner or operator of an affected facility is subject to theperformance specifications listed in 40 CFR pt. 60, Appendix B and shall operate,calibrate, and maintain each CEMS according to the QA/QC procedures in 40 CFRpt. 60, Appendix F as amended and maintain a written QA/QC program available ina form suitable for inspection.







Minn. R. 7017.1170, subp. 3


Minn. R. 7017.1090, subp. 1





Minn. R. 7017.1170, subp. 2


Minn. R. 7017.1130



03700011 - 006

Facility Name:

Permit Number:

A-175

G. CMS REQUIREMENT hdr


Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4

H. O2 MONITOR REQUIREMENTS hdr


Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4



03700011 - 006

Facility Name:

Permit Number:

A-176

Subject Item: EU 041 #3 Crude Unit Vac Pre-Fractionator Heater



MR 148 NOx Monitor at 25H3


MR 165 47/45 Mix Drum Fuel Gas Combustion O2 Monitor at 25H3

SV 038 25H3 Stack


Nitrogen Oxides: less than or equal to 0.045 lbs/million Btu heat input using 3-hourRolling Average (Consent Decree driven - effective upon installation of ULNB andsuccessful performance testing)

Title I Condition: CAAA of 1990; Minn R. 7007.0800,subp. 2






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


40 CFR 60.104(a)(1); Minn. R. 7011.1410, subp. 2


Minn. R. 7011.1410, subp. 3


Minn. R. 7011.1410, subp. 3


Minn. R. 7011.1410, subp. 3




Minn. R. 7007.0800, subp. 5


Monitoring for NOx emissions: The Permittee shall continuously monitor fuelcombustion rate and stack O2. The Permittee shall use the most recent correlationto determine NOx lb/MMBtu emissions on an hourly basis until the NOx CEMS iscertified.


Monitoring for CO emissions: The Permittee shall continuously monitor fuelcombustion rate and stack O2. The Permittee shall use the most recent correlationto determine CO lb/MMBtu emissions on an hourly basis until the CO CEMS iscertified.



NOx Emission Calculation and Recordkeeping: The Permittee shall calculate andrecord the 365-day average (arithmetic mean) lb/MMBtu of NOx using all of the1-hour averages obtained during the previous 365-day period until the NOx CEMSis certified.


CO Emission Calculation and Recordkeeping: The Permittee shall calculate andrecord the 1-hour average (arithmetic mean) lb/MMBtu of CO until the CO CEMS iscertified.




03700011 - 006

Facility Name:

Permit Number:

A-177


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

E. CEM REQUIREMENTS FOR CO AND NOx hdr

Emissions Monitoring: The Permittee shall install, operate and use a nitrogenoxides (NOx) CEM to measure NOx emissions from SV 038.

CAAA of 1990; R. 7017.1006; Minn. R. 7007.0800,subp. 4

Emission Monitoring for CO: The Permittee shall install, operate and use CO CEMto measure CO from SV 037

Minn. R. 7017.1006; Minn. R. 7007.0800, subp. 4


Minn. R. 7017.1050, subp. 1


CEMS QA/QC: The owner or operator of an affected facility is subject to theperformance specifications listed in 40 CFR pt. 60, Appendix B and shall operate,calibrate, and maintain each CEMS according to the QA/QC procedures in 40 CFRpt. 60, Appendix F as amended and maintain a written QA/QC program available ina form suitable for inspection.







Minn. R. 7017.1170, subp. 3


Minn. R. 7017.1090, subp. 1





Minn. R. 7017.1170, subp. 2


Minn. R. 7017.1130




03700011 - 006

Facility Name:

Permit Number:

A-178


Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4



Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4



03700011 - 006

Facility Name:

Permit Number:

A-179

Subject Item: EU 050 Distillate HDS Recycle Hydrogen Charge Heater

Associated Items: MR 051 27H-101 Natural Gas Supply Flow Meter

MR 052 27H-101 Fuel Gas Supply Flow Meter 2

MR 057 27H-101 Fuel Gas Supply Flow Meter 1

MR 167 27H-101 CO Monitor

MR 168 27H-101 NOx Monitor

MR 182 27H-101 O2 Monitor

SV 044 27H101 Stack



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

Nitrogen Oxides: less than or equal to 4.80 lbs/hour using 24-hour Rolling Average Title I Condition: BACT Limit for NOx, 40 CFR 52.21

Nitrogen Oxides: less than or equal to 0.08 lbs/million Btu heat input using 24-hourRolling Average . This limit does not apply during startup or shutdown.





Minn. R. 7011.1410, subp. 3


Minn. R. 7011.1410, subp. 3


Minn. R. 7011.1410, subp. 3




Minn. R. 7007.0800, subps. 5


Minn. R. 7007.0800, subp. 5


Monitoring for NOx emissions: Install, operate, and maintain NOx and O2 CEMs inaccordance with 40 CFR Part 60, Appendix B and Appendix F.


Monitoring of CO emissions: Install, operate, and maintain CO and O2 CEMs inaccordance with 40 CFR Part 60, Appendix B and Appendix F.

Title I Condition: To avoid classifcation as a majormodification under 40 CFR Section 52.21 and Minn. R.7007.3000; Minn. R. 7017.1006



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





03700011 - 006

Facility Name:

Permit Number:

A-180



Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4



03700011 - 006

Facility Name:

Permit Number:

A-181

Subject Item: EU 051 Distillate Hydrotreater Fractntr Htr


MR 053 27H-102 Fuel Gas Supply Flow Meter

MR 056 27H-102 Natural Gas Supply Flow Meter

SV 045 27H102 Stack





Nitrogen Oxides: less than or equal to 0.08 lbs/million Btu heat input using 24-hourRolling Average



40 CFR 60.104(a)(1); Minn. R. 7011.1410, subp. 2


Minn. R. 7011.1410, subp. 3. B.

Sulfur Dioxide: less than 1.75 lbs/million Btu heat input using 3-hour RollingAverage . Compliance with the fuel restriction requirement constitutes compliancewith this limit.

Minn. R. 7011.1410, subp. 3. A.


Minn. R. 7011.1410, subp. 3. B.




Minn. R. 7007.0800, subps. 5

Fuel Usage: less than or equal to 81.4 million Btu/hour using 8-hour Block Averagebased on the higher heating value of fuel burned. Downtime of 15 or more minutesis not to be included as operating time.


Minn. R. 7017.2025


Minn. R. 7007.0800, subp. 5





Title I Condition: To avoid classification as a majormodification under 40 CFR Section 52.21 and Minn. R.7007.3000; Minn. R. 7017.1006






03700011 - 006

Facility Name:

Permit Number:

A-182



E. PERFORMANCE TEST REQUIREMENT hdr



Minn. R. 7017.2020, subp. 1

Performance Test: due 180 days after Initial Startup of EU 324 (25H-4) to measureCO emissions.

Minn. R. 7017.2020, subp. 1




Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4



Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4



03700011 - 006

Facility Name:

Permit Number:

A-183

Subject Item: EU 052 #2 H2 Plant Reformer Heater



MR 054 27H-1 PSA Gas Supply Flow Meter


SV 046 27H1 Stack


Total Particulate Matter: less than or equal to 2.09 lbs/hour using 365-day RollingAverage

Title I Condition: Limit to avoid classification as a majormodification for PM; 40 CFR Section 52.21;(moststringent, meets the limit set by: Minn. R. 7011.1410,subp. 3, item A)

Particulate Matter < 10 micron: less than or equal to 2.09 lbs/hour using 365-dayRolling Average

Title I Condition: Limit to avoid classification as a majormodification for PM10; 40 CFR Section 52.21

Nitrogen Oxides: less than or equal to 47.5 lbs/hour using 24-hour Rolling Average Title I Condition: BACT limit for NOx; 40 CFR Section52.21


Title I Condition: BACT limit for NOx; 40 CFR Section52.21

Carbon Monoxide: less than or equal to 14.4 lbs/hour using 365-day RollingAverage


Hydrogen Sulfide: less than or equal to 0.1 grains/dry standard cubic foot using3-hour Rolling Average (230MG/DSCM[162 PPM]). This limit does not apply duringperiods of startup, shutdown, or malfunction.

40 CFR Section 60.104(a)(1); 40 CFR Section 60.8(c);Minn. R. 7011.1435.A. [most stringent; meets limit setby Minn. R. 7011.1410, subp. 3. B.]


Minn. R. 7011.1410, subp. 3. A.


Minn. R. 7011.1410, subp. 3. B.


Heat Input: less than or equal to 718.7 million Btu/hour using 8-hour Block Average. Calculate and record on a daily basis, the average heat input for each 8-hourblock by dividing the total heat input by the total operating time in each 8-hourblock. Down time of 15 or more minutes is not to be included as operating time.

Minn. R. 7007.0800, subp. 4; MInn. R. 7017.2025,subps. 2.B, 3.C and 3a.(B)

Fuel Restriction: Authorized to burn purge, refinery and natural gas only. Minn. R. 7007.0800, subp. 2


Minn. R. 7007.0800, subp. 5





Title I Condition: Monitoring associated with limit toavoid classification as a major modification for NOx, 40CFR Section 52.21

Quarterly Measurement of H2S: On a quarterly basis, the Permittee shall measureH2S in No. 2 H2 plant PSA purge gas using a Draeger or other length-of-strain tubewith at least 1 month between samples.


Twice per Year Measurement of H2S: Once every six (6) month, the Permitteeshall measure H2S in No. 2 H2 plant PSA purge gas using a Draeger or otherlength-of-strain tube during 1st and 3rd quarters of operation beginning in 3rdquarter 2003.


Monthly Measurement of H2S: On a monthly basis, the Permittee shall measureH2S at the outlet of the lead H2 unit feed desulfurizer using Draegers or otherlength-of -strain tubes; if PSA purge gas will also be measured that month, takeboth samples in conjunction with each other.


Alternative Monitoring Plan (AMP): The Permittee shall continue monitor the H2Sat the outlet of lead desulfurizer less than or equal to 15 ppmV; If the H2S isgreater than 15 ppmV, the Permittee shall increase monitoring per flowchart in theapproved AMP.




03700011 - 006

Facility Name:

Permit Number:

A-184



D. RECORDKEEPING REQUIREMENTS hdr

H2S Recordkeeping: During each test, the Permittee shall record the H2S in PSApurge gas and desulfurizer outlet.


NOx Emission Recordkeeping: The Permittee shall maintain records of thecalculated NOx emissions hourly average of NOx emissions in lb/hr.

Title I Condition: Recordkeeping associated with BACTLimit for NOx

CO Emission Recordkeeping: The Permittee shall maintain records of thecalculated CO emissions hourly average of CO emissions in lb/hr.

Title I Condition: Recordkeeping associated with limitto avoid classification as a major modification under 40CFR 52.21 for NOx

NOx Emission Calculation and Recordkeeping: The Permittee shall calculate andrecord the 24-hour average lb/MMBtu of NOx using all of the 1-hour averagesobtained during the previous 24-hour period.


PM/PM10 Emission Calculations and Recordkeeping: The Permittee shall calculateand record the daily and 365-day rolling average PM/PM10 emissions.

Title I Condition: Recordkeeping associated with limitto avoid classification as a major modification under 40CFR Section 52.21

E. REPORTING REQUIREMENTS hdr



F. PERFORMANCE TEST REQUIREMENT hdr

Performance Test: due before end of each 60 months starting 11/15/2000 tomeasure PM and PM10 emissions from SV 046. The first performance test underthis condition must be completed by 11/15/2005.


Minn. R. 7017.2020, subp. 1

Performance Test: due before end of each 36 months starting 11/15/2000 tomeasure NOx and CO emissions from SV 046. The first performance test requiredunder this condition must be completed by 11/15/2005.


Minn. R. 7017.2020, subp. 1



Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4



Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4



03700011 - 006

Facility Name:

Permit Number:

A-185

Subject Item: EU 053 Naphtha Hydrotreater Reactor Chg Htr




SV 047 28H1 Stack



Nitrogen Oxides: less than or equal to 0.14 lbs/million Btu heat input using 24-hourRolling Average when heater is firing less than or equal to 90% of maximum rating.The limit does not apply during startup or shutdown.


Nitrogen Oxides: less than or equal to 0.10 lbs/million Btu heat input using 24-hourRolling Average when heater is firing greater than 90% of maximum rating. Thelimit does not apply during startup or shutdown.



40 CFR 60.104(a)(1); Minn. R. 7011.1490, subp. 2


Minn. R. 7011.1410, subp. 3. B


Minn. R. 7011.1410, subp. 3. A


Minn. R. 7011.1410, subp. 3. B




Minn. R. 7007.0800, subps. 5



Minn. R. 7017.2025


Minn. R. 7007.0800, subp. 5







E. PERFORMANCE TEST REQUIREMENTS hdr

Performance Test: due before end of each 36 months starting 11/09/2004 tomeasure NOx and CO emissions from SV 046. The first performance test requiredunder this condition must be completed by 11/09/2007.


Minn. R. 7017.2020, subp. 1




03700011 - 006

Facility Name:

Permit Number:

A-186


Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4



Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4



03700011 - 006

Facility Name:

Permit Number:

A-187

Subject Item: EU 056 HDS Heater (hot oil system)

Associated Items: GP 055 Emission Units subject to Minn. R. built before June 11, 1973


SV 050 31H4 Stack


Nitrogen Oxides: less than or equal to 0.045 lbs/million Btu heat input using 3-hourRolling Average (Consent Decree driven)



Minn. R. 7011.1405, subp. 3. A.


Minn. R. 7011.1405, subp. 3. A.

Sulfur Dioxide: less than or equal to 1.75 lbs/million Btu heat input using 3-hourRolling Average . Compliance with the fuel restriction requirement constitutescomplaince with this limit.

Minn. R. 7011.1405, subp. 2




Minn. R. 7007.0800, subp. 5



Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4



Minn. R. 7017.2020, subp. 1

Performance Test Notifications and Submittals;

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 day before each Performance TestPerformance Test Report: due 45 days after each Performance TestPerformance Test Report - Microfiche Copy or CD: due 105 day after eachPerformance Test.The Notification, Test Plan, and Test Report may be submitted in alternative formatas allowed by Minn. R. 7017.2018.

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



03700011 - 006

Facility Name:

Permit Number:

A-188

Subject Item: EU 058 #5 HDS Charge Heater (naphtha)



SV 052 31H7 Stack



Minn. R. 7011.1405, subp. 3, Item A


Minn. R. 7011.1405, subp. 3, Item B


Minn. R. 7011.1405, subp. 2




Minn. R. 7007.0800, subp. 5



Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4



03700011 - 006

Facility Name:

Permit Number:

A-189

Subject Item: EU 060 #1 HDS Fractionation Heater



SV 054 31H9 Stack







Minn. R. 7011.1405, subp. 2




Minn. R. 7007.0800, subp. 5



Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4



03700011 - 006

Facility Name:

Permit Number:

A-190

Subject Item: EU 077 Powerformer Catalyst Regeneration

Associated Items: CE 066 Packed-Gas Adsorption Column

SV 068 Powerform Cat Reg Stack

What to do Why to do itNATIONAL EMISSION STANDARDS FOR HAZARDOUS AIR POLLUTANTS hdr

The Permittee shall comply with the Option Requirements in 40 CFR pt. 63, subp.UUU by compliance date April 11. 2005.




03700011 - 006

Facility Name:

Permit Number:

A-191

Subject Item: EU 084 Gas Oil HDS Charge Heater



SV 074 33H31 Stack





Title Condition: Limit to avoid classification as a majormodification under 40 CFR Section 52.21; Minn. R.7007.3000

Sulfur Dioxide: less than 37.6 lbs/hour using 3-hour Rolling Average Title I Condition: SIP for SO2 NAAQS 40 CFR pt. 50;MN State Implementation Plan (SIP)

Sulfur Dioxide: less than or equal to 37.6 lbs/gallon using 24-hour Rolling Average Title I Condition: SIP for SO2 NAAQS 40 CFR pt. 50;MN State Implementation Plan (SIP)

Sulfur Dioxide: less than or equal to 164.9 lbs/hour using 12-month Rolling Average Title I Condition: SIP for SO2 NAAQS 40 CFR pt. 50;MN State Implementation Plan (SIP)


40 CFR 60.104(a)(1); Minn. R. 7011.1410, subp. 2;(most stringent, meet the limits set by:limit taken toavoid classification as a major modification under 40CFR Section 52.21; SIP for SO2 NAAQS 40 CFR pt.50; Minn. R. 7011.1410, subp. 3. A.)


Minn. R. 7011.1410, subp. 3. B

Opacity: less than or equal to 20 percent opacity using 6-minute Average ; exceptfor one six-minute period per hour of not more than 60 percent opacity.Compliance with the fuel restriction requirement constitutes compliance with thislimit.

Minn. R. 7011.1410, subp. 3. B





Minn. R. 7017.2025


Minn. R. 7007.0800, subp. 5


Minn. R. 7007.0800, subp. 5





Recordkeeping: The Permittee shall calculate and record the hourly, daily, and365-day rolling average emission rate of nitrogen oxides.

Title I Condition: Recordkeeping associated with limitto avoid major classification as a major modificationunder 40 CFR Section 52.21; Minn. R. 7007.0800,subp. 5



SO2 Emissions Calculations and Recordkeeping: The Permittee shall maintainrecords of the calculated SO2 emissions in lb/hr and tons/year.




03700011 - 006

Facility Name:

Permit Number:

A-192




Minn. R. 7017.2020, subp. 1

F. CMS REQUIREMENTS hdr




Minn. R. 7007.0800, subp. 4


Firebox O2: The Permittee shall operate, and maintain a CMS that records thefirebox O2 at 33H-31.

Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4



03700011 - 006

Facility Name:

Permit Number:

A-193

Subject Item: EU 085 Gas Oil HDS Fractionation Charge Heater



SV 075 33H32 Stack






Carbon Monoxide: less than or equal to 0.040 lbs/million Btu heat input using365-day Rolling Average

Minn. R. 7007.0800, subp. 2

Sulfur Dioxide: less than 167.6 tons/year using 365-day Rolling Average from bothEU 084 and EU 085.



40 CFR 60.104(a)(1); Minn. R. 7011.1410, subp. 2;(most stringent, meet the limits set by: limit to avoidclassification as a major modification under 40 CFRSection 52.21; Minn. R. 7011.1410, subp. 3. A)


Minn. R. 7011.1410, subp. 3. B.


Minn. R. 7011.1410, subp. 3. B.




Minn. R. 7007.0800, subp. 5



Minn. R. 7017.2025


Minn. R. 7007.0800, subp. 5





NOx Emission Calculation and Recordkeeping: On an hourly basis, the Permitteeshall calculate and record the 3-hour (arithmetic mean) lb/MMBtu of NOx using allof the 1-hour averages obtained during the previous 3-hour period.


Recordkeeping: The Permittee shall calculate and record the hourly, daily, and365-day rolling average emission rate of nitrogen oxides.

Title I Condition: Recordkeeping associated with limitto avoid classification as a major modification under 40CFR Section 52.21; Minn. R. 7007.0800, subp. 5

CO Emission Calculation and Recordkeeping: The Permittee shall calculate andrecord the 3-hour (arithmetic mean) lb/MMBtu of CO using all of the 1-houraverages obtained during the previous 3-hour period.

Minn. R. 7007.0800, subp. 5

SO2 Emission Calculations and Recordkeeping: The Permittee shall maintainrecords of the calculated SO2 emissions in tons/year.

Minn. R. 7007.0800, subp. 5




03700011 - 006

Facility Name:

Permit Number:

A-194

Performance Test: due before end of each 36 months starting 02/28/2005 for NOxemissions. The first performance test required under this condition is to becompleted by 2/28/08.


Minn. R. 7017.2020, subp. 1



Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4


Firebox O2: The Permittee shall operate, and maintain a CMS that records thefirebox O2 at 33H-32.

Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4



03700011 - 006

Facility Name:

Permit Number:

A-195

Subject Item: EU 099 Platformer Catalyst Regeneration Vent

Associated Items: CE 067 Packed-Gas Adsorption Column

GP 057 Emission Units subject to Minn. R. built after June 11, 1973

SV 084 Plat Cat Reg Stack

What to do Why to do itNATIONAL EMISSION STANDARD FOR HAZARDOUS AIR POLLUTANTS hdr

The Permittee shall comply with the Option Requirements in 40 CFR pt. 63, subp.UUU by compliance date April 11. 2005, unless US EPA grants an extension.




03700011 - 006

Facility Name:

Permit Number:

A-196

Subject Item: EU 102 Unit 38 Gasoil HDS A-Train Heater

Associated Items: GP 057 Emission Units subject to Minn. R. built after June 11, 1973

MR 074 38H1A Fuel Gas Flow

SV 087 38H1A Stack


Nitrogen Oxides: less than or equal to 0.12 lbs/million Btu heat input using 3-hourAverage


B. PERFORMANCE TEST REQUIREMENT hdr

Performance Test: due 180 days after Initial Startup of EU 324 (25H-4) to measureNOx emissions.

Minn. R. 7017.2020, subp. 1




03700011 - 006

Facility Name:

Permit Number:

A-197

Subject Item: EU 103 Unit 38 Gasoil HDS B-Train Heater


MR 072 38H1B Fuel Gas Flow

SV 088 38H1B Stack




B. PERFORMANCE TEST REQUIREMENT hdr

Performance Test: due 180 days after Initial Startup of EU 324 (25H-4) to measureNOx emissions.

Minn. R. 7017.2020, subp. 1




03700011 - 006

Facility Name:

Permit Number:

A-198

Subject Item: EU 104 Unit 38 Gasoil HDS Fractionation Charge Heater



SV 089 38H2 Stack


Nitrogen Oxides: less than or equal to 0.045 lbs/million Btu heat input using 3-hourRolling Average (Consent Decree driven)


Nitrogen Oxides: less than or equal to 12.2 tons/year using 365-day RollingAverage effective 365 days after the completion of low NOx burner installation.



40 CFR 60.104(a)(1); Minn. R. 7011.1410, subp. 2;(most stringent, meet the limits set by: limit to avoidclassification as a major modification under 40 CFRSection 52.21; Minn. R. 7011.1410, subp. 3. A)

Total Particulate Matter: less than or equal to 0.4 lbs/million Btu heat input using3-hour Rolling Average . The PTE for this heater is 0.00745 lb/mmBtu heat inputat maximum capacity. Compliance with the fuel restriction requirement constitutescompliance with this limit.

Minn. R. 7011.1405, subp. 3. A.

Sulfur Dioxide: less than or equal to 1.75 lbs/million Btu heat input using 3-hourRolling Average . Compliance with the fuel restriction and H2S requirementsconstitutes compliance with this limit.

Minn. R. 7011.1405, subp. 2


Minn. R. 7011.1405, subp. 3. A




Minn. R. 7007.0800, subps. 5

Recordkeeping for NOx Emissions: The Permittee shall calculate and record thehourly, daily, and 365-day rolling average emission rate of nitrogen oxides.

Title I Condition: Recordkeeping associated with limitto avoid classification as a major modification under 40CFR Section 52.21; Minn. R. 7007.0800, subp. 5



Minn. R. 7017.2025


Minn. R. 7007.0800, subp. 5


Initial Performance Test: due before end of each 36 months starting 10/26/2005 fornitrogen oxides.


Minn. R. 7017.2020, subp. 1


D. CMS REQUIREMENT hdr


Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4



03700011 - 006

Facility Name:

Permit Number:

A-199

Subject Item: EU 126 Steam Boiler No. 6 at Boilerhouse

Associated Items: MR 170 71B6 NOx Monitor

MR 171 71B6 CO Monitor

MR 172 71B6 O2 Monitor

SV 095 Common Boilerhouse Stack


Nitrogen Oxides: less than or equal to 0.045 lbs/million Btu heat input using 3-hourRolling Average (Consent Decree driven - effective following installation of ULNBand successful performance testing)


Nitrogen Oxides: less than or equal to 0.20 lbs/million Btu heat input using 30-dayRolling Average (expressed as NO2), if the unit is a high heat release rate unit. A"high heat release rate" is defined as a heat release rate greater than 70,000Btu/hour-cubic foot.

The 30-day rolling average emission rate is calculated as the average of all hourlyemissions data recorded by the monitoring


Nitrogen Oxides: less than or equal to 0.10 lbs/million Btu heat input using 30-dayRolling Average (expressed as NO2), if the unit is a low heat release rate unit. A"low heat release rate" is defined as a heat release rate of 70,000 Btu/hr-cubic footor less.

The 30-day rolling average emission rate is calculated as the average of all hourlyemissions data recorded by the monitoring system during the 30 day period. A new30 day rolling average emission rate is calculated each steam generating unitoperating day.


Hydrogen Sulfide: less than or equal to 0.10 grains/dry standard cubic foot using3-hour Rolling Average (230 mg/dscm[162 ppm]). This limit applies to thehydrogen sulfide content of fuel gas burned in the units. Existing continuous H2Smonitoring systems on the existing refinery gas mix drums will be used todemonstrate compliance with this limit.

40 CFR Section 60.104(a)(1); Minn. R. 7011.1410,subp. 2; (most stringent, meet the limits set by: limit toavoid classification as a major modification under 40CFR Section 52.21; Minn. R. 7011.1410, subp. 3. A)

Hydrogen Sulfide: less than or equal to 90 parts per million using 365-day RollingAverage by volume.

Title I Condition: Limit to avoid classification as amajor modification under 40 CFR Section 52.21; Minn.R. 7007.0800, subp. 2

Sulfur Dioxide: less than or equal to 0.20 lbs/million Btu heat input using 30-dayRolling Average . This limit applies at all times, including periods of startup,shutdown, and malfunction. Compliance with the fuel restriction requirementconstitutes compliance with this limit.

40 CFR 60.42b(k)

Sulfur Dioxide: less than or equal to 1.75 lbs/million Btu heat input using 3-hourRolling Average . The total emissions of sulfur dioxide from all existing and newfuel gas combustion devices and indirect heating equipment shall be divided by thetotal heat input of all such devices and equipment to determine compliance withthis part; provided that no owner or operator shall cause to be discharged from anyone unit of new indirect heating equipment any gases which contain sulfur dioxidein excess of 3.0 pounds per million Btu heat input. Compliance with the fuelrestriction requirement constitutes compliance with this limit.

Minn. R. 7011.1410, subp. 3.A.

Carbon Monoxide: less than or equal to 400 parts per million by volume on a drybasis corrected to 3 percent oxygen using a 30-day Rolling Average.

This is a work practice standard and the CO emission level shall be maintainedbelow the standard at all times except during periods of startup, shutdown,malfunction, and when the process heater is operating at less than 50 percent ofrated capacity.

40 CFR Section 63.7500(a)(1); 40 CFR Section63.7540(a)(10)

Total Particulate Matter: less than or equal to 0.030 lbs/million Btu heat input using3-hour Rolling Average . The PTE for this heater is 0.00745 lb/mmBtu heat input atmaximum capacity. Compliance with the fuel restriction requirement constitutescompliance with this limit. This limit is more strigent than Minn. R. 7011.1410,subp.3(B)(1).

40 CFR 60.43b (h)(1); Minn. R. 7011.1410, subp.3(B)(1)


Minn. R. 7011.1410, subp. 3(B)(2)





03700011 - 006

Facility Name:

Permit Number:

A-200


Minn. R. 7007.0800, subp. 5

C. CEM REQUIREMENTS FOR NOx (see also MR170) hdr

Emissions Monitoring: The Permittee shall use a nitrogen oxides (NOx) CEMS tomeasure NOx emissions from EU 126. Specifications for the operation of themonitoring equipment are in 40 CFR Section 60.48b(c), (d), (e), (f), and AppendixB.

40 CFR Section 60.48b; Minn. R. 7017.1006

Installation of CEMS: The Permittee shall install and operate a NOx CEMS. Theinstallation and operation of the CEMs will meet the performance requirements asspecified in 40 CFR Section 60.46b.

Minn. R. 7017.1006

Records of Startup, Shutdown, or Malfunction: Any owner or operator subject to theprovisions of 40 CFR pt. 60, subp. Db, shall maintain records of the occurrence andduration of any startup, shutdown, or malfunction in the operation of an affectedfacility; any malfunction of the air pollution control equipment; or any periods duringwhich a continuous monitoring system or monitoring device is inoperative.


D. CEM REQUIREMENTS FOR CO (see also MR170) hdr

CO Emissions Measuring: The Permittee shall use a CO CEMS to measure COemissions from EU 126.

The Permittee shall maintain a CO emission level below the applicable CO workpractice standard at all times except during periods of startup, shutdown,malfunction, and when the process heater is operating at less than 50 percent ofrated capacity.

Minn. R. 7017.1006

Emissions Monitoring: The Permittee shall continuously monitor CO emissionsaccording to 40 CFR Section 63.7525(a) and Section 63.7535.


E. NOTIFICATIONS FOR NSPS AND NESHAPS hdr

F. RECORDKEEPING AND REPORTING REQUIREMENTS hdr

Maintain records of the following information:

(1)Calendar date.(2) The average hourly nitrogen oxides emission rates (expressed as NO2) (ng/J orlb/million Btu heat input) measured or predicted.(3) The 30-day average nitrogen oxides emission rates (lb/mmBtu heat input)calculated at the end of each steam generating unit operating day from themeasured or predicted hourly nitrogen oxide emission rates for the preceding 30steam generating unit operating days.(4) Identification of the steam generating unit operating days when the calculated30-day average nitrogen oxides emission rates are in excess of the nitrogen oxidesemissions standards under Section 60.44b, with the reasons for such excessemissions as well as a description of corrective actions taken.(5) Identification of the steam generating unit operating days for which pollutantdata have not been obtained, including reasons for not obtaining sufficient data anda description of corrective actions taken.

40 CFR Section 60.49b(g)

The owner or operator of an affected facility may submit electronic quarterly reportsfor NOx in lieu of submitting the written reports. The format of each quarterlyelectronic report shall be coordinated with the MPCA. The electronic report(s) shallbe submitted no later than 30 days after the end of the calendar quarter and shallbe accompanied by a certification statement from the owner or operator, indicatingwhether compliance with the applicable emission standards and minimum datarequirements of 40 CFR pt. 60, subp. Db was achieved during the reporting period.Before submitting reports in the electronic format, the owner or operator shallcoordinate with the MPCA to obtain their agreement to submit reports in thisalternative format.

40 CFR Section 60.49b(v)

The Permittee shall record and maintain records of the amounts of each fuelcombusted during each day and calculate the annual capacity factor individually foreach fuel combusted for the reporting period. The annual capacity factor isdetermined on a 12-month rolling average basis with a new annual capacity factorcalculated at the end of each calendar month.

40 CFR Section 60.49b(d)



03700011 - 006

Facility Name:

Permit Number:

A-201

Subject Item: EU 127 Plant Air Compressor Diesel Engine

Associated Items: SV 096 71C11 Diesel West Stack

SV 097 71C11 Diesel East Stack


Nitrogen Oxides: less than or equal to 17.4 lbs/hour using 24-hour Rolling Average Title I Condition: BACT limit for NOx, 40 CFR Section52.21

Sulfur Dioxide: less than or equal to 0.5 lbs/million Btu heat input using 3-hourRolling Average

Minn. R. 7011.2300, subp. 2


Minn. R. 7011.2300, subp. 1




Sulfur Content of Fuel: less than or equal to 0.05 percent by weight of diesel fuel. Title I Condition: SIP for SO2 NAAQS 40 CFR pt. 50;MN State Implementation Plan (SIP)

C. RECORDKEEPING RQUIREMENTS hdr

NOx Emission Calculation and Recordkeeping: The Permittee shall calculate andrecord the 1-hour average (arithmetic mean) in 24-hour period.

Title I Condition: Recordkeeping associated with BACTLimit, 40 CFR Section 52.21

Recordkeeping of Hours of Operation: By the 28th day of each month, thePermittee shall record and sum the hours of operation for EU 127 for each monthand for the previous 12 months and record the 12-month rolling sum.


Diesel Fuel Certification: The Permittee shall retain written documentation of eachshipment of diesel fuel oil received for the diesel engine. The written documentationshall include the following information: the sulfur content of the diesel fuel, themethod used to determine the sulfur content and certification that the sulfur contentis less than or equal to 0.05 percent by weight.

Minn. R. 7007.0800, subp. 5

C. REPORTING REQUIREMENTS hdr

D. NATIONAL EMISSION STANDARD FOR HAZARDOUS AIR POLLUTANTS hdr

The Permittee shall comply with 40 CFR pt. 63, subp. ZZZZ by the compliance dateFebruary 26, 2007.




03700011 - 006

Facility Name:

Permit Number:

A-202

Subject Item: EU 185 OSWTP-Enhanced Biological Treatment Basin 94B3C


GP 010 Tanks/Basins subject to NESHAP FF w/vapor recovery & control device

GP 065 Treatment Processes to meet destruction req. NESH FF

GP 066 VOC Emissions from WWTP

SV 125 94H1 Stack

SV 146 94H3 Stack

What to do Why to do itFor each enhanced biodegradation unit that is the first exempt waste managementunit in a treatment train, measure the benzene concentration of each waste streamentering the unit at least once per month by collecting and analyzing one or moresamples using the procedures specified in 40 CFR Section 61.355(c)(3).

40 CFR Section 61.354(b)(2)



03700011 - 006

Facility Name:

Permit Number:

A-203

Subject Item: EU 197 OSWTP - Oily Sludge Dewatering (Centrifuge)


GP 010 Tanks/Basins subject to NESHAP FF w/vapor recovery & control device


SV 125 94H1 Stack

SV 146 94H3 Stack













Visual Inspection: Each cover seal, access hatch, and all other openings shall bechecked by visual inspection quarterly to ensure that no cracks or gaps occur andthat access hatches and other openings are closed and gasketed properly.

40 CFR Section 61.357(d)(8); 40 CFR Section63.654(a); Minn. E 7011.9930, subp. E





03700011 - 006

Facility Name:

Permit Number:

A-204

Subject Item: EU 204 Steam Boiler #8

Associated Items: MR 093 71B8 O2 Analyzer to Monitor NOx Emissions

MR 094 71B8 Natural Gas Supply Flow Meter

SV 132 71B8 Stack


Nitrogen Oxides: less than 39.9 tons/year using 365-day Rolling Average Title I Condition: limit to avoid classification as a majormodification under 40 CFR Section 52.21

Nitrogen Oxides: less than or equal to 0.20 lbs/million Btu heat input using 30-dayRolling Average including periods of startup, shutdown or malfunction.

40 CFR Section 60.40b; 40 CFR Section 60.44b; Minn.R. 7011.0565

Hydrogen Sulfide: less than or equal to 0.1 grains/dry standard cubic foot using3-hour Rolling Average . Limit does not apply during startup, shutdown, ormalfunction.

40 CFR Section 60.40b(c); 40 CFR Section 60.8(c);Minn. R. 7011.0565 [most stringent, meets limit set byMinn. R. 7011.1410, subp. 3. A.]


Minn. R. 7011.1410, subp. 3. B.


Minn. R. 7011.1410, subp. 3. A.


Minn. R. 7011.1410, subp. 3. B.




Minn. R. 7007.0800, subp. 5

Fuel Usage: less than or equal to 146.6 million Btu's/hour using 8-hour BlockAverage based on the lower heating value of fuel burned. Downtime of 15 or moreminutes is not to be included as operating time.


Minn. R. 7017.2025


Minn. R. 7007.0800, subp. 5


Monitoring for NOx emissions: The Permittee shall continuously monitor fuelcombustion rate and stack O2 and use the most recent correlation to determineNOx lb/MMBtu emissions.

40 CFR Section 60.13; 40 CFR Section 60.46b; 40CFR Section 60.49b; Minn. R. 7011.0565; Minn. R.7017.1010, subp. 1


NOx Recordkeeping: The Permittee shall calculate and record daily and 365-dayrolling average the NOx emissions in tons/yr.

Title I Condition: Recordkeeping associated with limitto avoid classification as a major source under 40 CFRSection 52.21

Recordkeeping: The Permittee shall record daily total amounts of each fuelcombusted in the unit.

40 CFR Section 60.48b; 40 CFR Section 60.49b; Minn.R. 7011.0565

Recordkeeping of the Annual Capacity Factor: The Permittee shall record andmaintain records of the amounts of each fuel combusted during each day andcalculate the annual capacity factor individually for natural gas for the reportingperiod. The annual capacity factor is determined on a 12-month rolling averagebasis with a new annual capacity factor calculated at the end of each calendarmonth.

40 CFR Section 60.49b(d); Minn. R. 7011.0565

NOx Recordkeeping: Tthe Permittee shall calculate and record the daily and30-day rolling average NOx emissions in lb/MMBtu.

40 CFR Section 60.13(i); 40 CFR Section 60.46b; 40CFR Section 60.49b; Minn. R. 7011.0565

Recordkeeping: The Permittee shall record average hourly NOx emissions inlb/MMBtu for each steam operating day.

40 CFR Section 60.13(i); 40 CFR Section 60.46b; 40CFR Section 60.49b; Minn. R. 7011.0565




03700011 - 006

Facility Name:

Permit Number:

A-205

F. PERFORMANCE TEST REQUIREMENTS hdr

Performance Test: due before end of each 36 months starting 08/03/2004 tomeasure NOx emissions from SV 132. The first performance test required underthis condition must be completed by 08/03/2007.


Minn. R. 7017.2020, subp. 1



Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4



Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4



03700011 - 006

Facility Name:

Permit Number:

A-206

Subject Item: EU 212 11H-6

Associated Items: MR 005 11H-6 CO Monitor

MR 006 11H6 NOx Monitor

MR 007 O2 Monitor for 11H6


SV 131 11H6 Stack


Sulfur Dioxide: less than or equal to 25.2 tons/year using 365-day Rolling Average Title I Condition: Netting Limit for SO2; 40 CFR Section52.21; (most stringent, meets the limit set by: Minn. R.7011.1410, subp. 3, item A)

Nitrogen Oxides: less than or equal to 76.9 tons/year using 365-day Rolling Sum Title I Condition: To avoid classification as a majormodification under 40 CFR Section 52.21 and Minn. R.7007.3000


40 CFR Section 60.104(a)(1); 40 CFR Section60.105(e)(3)(ii); 40 CFR Section 60.8(c); Minn. R.7011.1435 A; (most stringent, meets the limit set byMinn. R. 7011.1410, subp. 3)

Hydrogen Sulfide: less than or equal to 0.186 grains/dry standard cubic foot using1-Hour Average (300 ppm). This is a state-only requirement and it is notenforceable by the EPA administrator or citizens under the Clean Air Act.

Minn. R. 7009.0080


Minn. R. 7011.1410, subp. 3. B.


Minn. R. 7011.1410, subp. 3. B.




Minn. R. 7007.0800, subp. 5

C. RECORDKEEPING REQUIREMENT hdr

SO2 and NOx Emission Calculation and Recordkeeping: The Permittee shallcalculate and record daily and 365-day rolling average SO2 and NOx emissionsfrom EU 212.

Title I Condition: Recordkeeping associated withNetting limit 40 CFR Section 52.21(j)(3)

D. CEMS REQUIREMENTS FOR CO AND NOx hdr

Emissions Monitoring: The Permittee shall calibrate, operate and maintain a NOxcontinuous emissions monitoring system (CEMS).


Emissions Monitoring: The Permittee shall calibrate, operate and maintain a COcontinuous emissions monitoring system (CEMS).

Minn. R. 7017.1006; Minn. R. 7007.0800, subp. 4


Minn. R. 7017.1006


Minn. R. 7017.1160, subps 1,2 &3




CAAA of 1990; 40 CFR pt. 60, Appendix F; Minn. R.7017.1170, subp. 4


CAAA of 1990; 40 CFR pt. 60, Appendix B andAppendix F; Minn. R. 7017.1170, subp. 5



03700011 - 006

Facility Name:

Permit Number:

A-207


Minn. R. 7017.1170, subp. 3







Minn. R. 7017.1170, subp. 2


Minn. R. 7017.1130



Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4



Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4

G. REPORTING REQUIREMENT hdr



03700011 - 006

Facility Name:

Permit Number:

A-208

Subject Item: EU 213 #3 H2 Heater

Associated Items: MR 043 27H-501 NOx Analyzer

MR 044 27H-501 CO Analyzer

MR 048 27H501 Firebox O2 Analyzer


MR 058 27H501 PSA Purge Gas Flow

MR 115 Natural Gas Flowmeter to Pilots

SV 136 27H501 Stack


Nitrogen Oxides: less than or equal to 19.95 lbs/hour using 30-day Rolling Average(This limit applies at all times.)


Nitrogen Oxides: less than or equal to 0.036 lbs/million Btu heat input using 30-dayRolling Average . (This limit does not apply during startup, shutdown, or duringperiods when the PSA purge gas is not available.)


Nitrogen Oxides: less than or equal to 0.042 lbs/million Btu heat input using24-hour Block Average . (This limit does not apply during startup, shutdown, orduring periods when the PSA purge gas is not available.)


Particulate Matter < 10 micron: less than or equal to 3.13 lbs/hour using 30-dayRolling Average


Sulfur Dioxide: less than or equal to 4.54 lbs/hour using 30-day Rolling Average Title I Condition: Limit to avoid classification as a majormodification, 40 CFR Section 52.21; (most stringent,meets the limit set by: Minn. R. 7011.1410, subp. 3,item A)

Hydrogen Sulfide: less than or equal to 0.1 grains/dry standard cubic foot using3-hour Rolling Average (230 mg/dscm[162 ppm). This limit does not apply duringperiods of startup, shutdown, or malfunction.

40 CFR Section 60.104(a)(1); 40 CFR Section 60.8(c);Minn. R. 7011.1435.A.


Minn. R. 7011.1410, subp. 3. B.


Minn. R. 7011.1410, subp. 3. B.


Fuel Restriction: Authorized to burn PSA purge gas, refinery fuel gas and naturalgas only.

Minn. R. 7007.0800, subp. 2

Fuel Usage: less than or equal to 430.2 million Btu/hour using 8-hour BlockAverage For PM10 emissions based on the higher heating value of fuel burned.Downtime of 15 or more minutes is not to be included as operating time.


Minn. R. 7017.2025


Minn. R. 7007.0800, subp. 5


Minn. R. 7007.0800, subp. 5


Quarterly Measurement of H2S: On a quarterly basis, the Permittee shall measureH2S in No. 3 H2 plant PSA purge gas using a Draeger or other length-of-strain tubewith at least 1 month between samples. 1st sample is due first quarter 2004, sincesample taken in October/November 2003 will be counted as first quarterly samples.




03700011 - 006

Facility Name:

Permit Number:

A-209

Twice per Year Measurement of H2S: Once every six (6) month, the Permitteeshall measure H2S in No. 3 H2 plant PSA purge gas using a Draeger or otherlength-of-strain tube during 1st and 3rd quarters of operation beginning in 3rdquarter 2004.


Monthly Measurement of H2S: On a monthly basis, the Permittee shall measureH2S at the outlet of the lead H2 unit feed desulfurizer using Draegers or otherlength-of -strain tubes; if PSA purge gas will also be measured that month, takeboth samples in conjunction with each other.


Alternative Monitoring Plan (AMP): The Permittee shall continue monitor the H2Sat the outlet of lead desulfurizer less than or equal to 15 ppmV; If the H2S isgreater than 15 ppmV, the Permittee shall increase monitoring per flowchart in theapproved AMP.




Weekly Measurement of PSA Purge Gas: The Permittee shall measure higherheating value (HHV) of PSA purge gas during the initial testing schedule. If thestandard deviation in HHV content is less than 10% after 3 months of sampling, thePermittee shall go to monthly sampling.

Title Condition: Recordkeeping associated with BACTLimit for NOx, 40 CFR Section 52.21(j)(3)

Monthly Measurement of PSA Purge Gas: The Permittee shall measure higherheating value (HHV) of PSA purge gas. If the standard deviation in HHV content isless than 10% after 3 months of weekly sampling and if the standard deviation inHHV content is less than 10% after 12 months of monthly sampling, go tosemi-annual sampling.


Every Six (6) months Measurement of PSA Purge Gas: The Permittee shallmeasure higher heating value (HHV) of PSA purge gas during the final testingschedule. After 12 months of monthly sampling, if the standard deviation in HHVcontent is less than 10%, the Permittee shall use semi-annual sampling thereafter.



H2S Recordkeeping: During each test, the Permittee shall record the H2S in PSApurge gas and desulfurizer outlet.


NOx Emission Recordkeeping: The Permittee shall maintain records of thecalculated NOx emissions hourly average of NOx emissions in lb/hr.


NOx Emission Calculation and Recordkeeping: The Permittee shall calculate andrecord the 24-hour average lb/MMBtu of NOx using all of the 1-hour averagesobtained during the previous 24-hour period.

Title I Condition: Recordkeeping associated with BACTLimit for NOx, 40 CFR Section 52.21

PM-10 Emission Calculation and Recordkeeping: The Permittee shall calculateand record daily PM-10 emissions in lb/hr

Title I Condition: Recordkeeping associated with limitto avoid classification as a major modification under 40CFR Section 52.21 for NOx

SO2 Emission Calculation and Recordkeeping: The Permittee shall calculate andrecord daily SO2 emissions in lb/hr

Title I Condition: Recordkeeping associated with limitto avoid classification as a major modification under 40CFR Section 52.21

E. CEMS REQUIREMENTS FOR NOX AND CO hdr

Emissions Monitoring: The Permittee shall calibrate, operate and maintain a NOxcontinuous emissions monitoring system (CEMS).


Emissions Monitoring: The Permittee shall calibrate, operate and maintain a COcontinuous emissions monitoring system (CEMS).

Minn. R. 7017.1006; Minn. R. 7007.0800, subp. 4


Minn. R. 7017.1006


Minn. R. 7017.1160, subps 1,2 &3









03700011 - 006

Facility Name:

Permit Number:

A-210


Minn. R. 7017.1170, subp. 3


Minn. R. 7017.1090, subp. 1





Minn. R. 7017.1170, subp. 2


Minn. R. 7007.1130

F. PERFORMANCE TEST REQUIREMENT hdr

Performance Test: due before end of each 60 months starting 02/21/2007 for PM10emissions. The second performance test required under this condition is to becompleted by 2/21/2012.


Minn. R. 7017.2020, subp. 1



Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4

H. REPORTING REQUIREMENTS hdr





03700011 - 006

Facility Name:

Permit Number:

A-211

Subject Item: EU 228 FCCU

Associated Items: CE 004 Direct Flame Afterburner w/Heat Exchanger

CE 005 Direct Flame Afterburner w/Heat Exchanger

CE 006 Electrostatic Precipitator - Medium Efficiency

MR 017 17ME-187 FCC Common Stack Opacity Analyzer

MR 018 FCC Common Stack NOx Analyzer

MR 019 FCC Common Stack SO2 Analyzer

MR 021 FCC CO(%) in Flue Gas Monitor



MR 024 EMRC Flow for 17ME-187

MR 025 EMRC Temperature Thermocouple for 17ME-187

MR 106 FCC O2 Dry Percent

MR 107 FCC CO Low

SV 019 FCC Main Stack

SV 021 FCC Bypass Stack


Sulfur Dioxide: less than or equal to 1,500 lbs/hour using 1-Hour Average . This isa state-only requirement and, pursuant to Minn. R. 7007.1750, it is not enforceableby the EPA administrator or citizens under the Clean Air Act.

SO2 MAAQS, Minn. R. 7009.0080

Sulfur Dioxide: less than or equal to 1,500 lbs/hour using 3-hour Rolling Average .The company shall use CEMS to monitor the sulfur dioxide emissions in order tocalculate pounds of sulfur dioxide per hour (lb/hr).


Sulfur Dioxide: less than or equal to 3,504 tons/year using 12-month RollingAverage . (This requirement is met by complying with the more stringentrequirement of 800 tons/year using a 365-day rolling average.)


Sulfur Dioxide: less than or equal to 800 tons/year using 365-day Rolling Average Title I Condition: Limit to avoid classification as a majormodification under 40 CFR Section 52.21; Minn. R.7007.3000

Sulfur Dioxide: less than or equal to 25 parts per million by volume (at 0% oxygen)using 365-day Rolling Average. This limit was effective on December 31, 2003,with the initial calculation for compliance with the 365-day limit to be performed onDecember 30, 2004.


Sulfur Dioxide: less than or equal to 50 parts per million by volume (at 0% oxygen)using 7-day Rolling Average. This limit does not apply during periods of startup,shutdown, or malfunction. This limit replaces the requirement for daily samples forfeed sulfur analysis to the FCCU or calculation of pounds of SO2 per 1000 poundsof coke burned. The compliance option under 40 CFR Section 60.104(b) may bechanged at any time as long as the switch is carried out in accordance with 40 CFRSection 60.108(e) including required notification under 40 CFR Section 60.107(e)and beginning daily compliance tests under 40 CFR Section 60.106 at least 7 daysprior to the change.

Title I Condition: CAAA of 1990; 40 CFR Section60.104(b)(1); Minn. R. 7007.0800, subp. 2

Total Particulate Matter: less than or equal to 1.0 lbs/1000 lbs using 3-hour RollingAverage of coke burn-off in the catalyst regenerator. This limit does not applyduring startup, shutdown, or malfunction.

40 CFR Section 60.102(a)(1); 40 CFR Section 60.8(c);Minn. R. 7011.1410, subp. 1. A. [ Meet therequirements under 40 CFR Section 63.1564(b)(5)]

Total Particulate Matter: less than or equal to 169 tons/year using 365-day RollingAverage


Particulate Matter < 10 micron: less than or equal to 142 tons/year using 365-dayRolling Average


Carbon Monoxide: less than or equal to 60 tons/year using 365-day Rolling Sum Title I Condition: Limit to avoid classification as a majormodification under 40 CFR Section 52.21; Minn. R.7007.3000



03700011 - 006

Facility Name:

Permit Number:

A-212

Carbon Monoxide: less than or equal to 500 parts per million by volume (dry basis)using a 1-hour Average. This limit does not apply during startup, shutdown, ormalfunction.

40 CFR Section 60.103; 40 CFR Section 60.105; 40CFR Section 60.8; Minn. R. 7011.1435; [Meetrequirements under 40 CFR Section 63.1565(a)(1)]

Nitrogen Oxides: less than or equal to 500 tons/year using 365-day Rolling Average. THIS LIMIT WILL BE EFFECTIVE UPON START-UP OF EITHER EU-294,EU-295 or EU-296. This is a state only requirement and is not enforceable by theEPA administrator or citizens under the Clean Air Act.

Minn. R. 4410.4300, subp. 15. A., To avoid exceedingthe mandatory Environmental Assessment WorksheetCategory for air emissions

Nitrogen Oxides: less than or equal to 650 tons/year using 365-day Rolling Average. THIS LIMIT WILL BE TERMINATED UPON START-UP OF EITHER EU-294,EU-295 or EU-296. This is a state only requirement and is not enforceable by theEPA administrator or citizens under the Clean Air Act.

Minn. R. 4410.4300, subp. 15. A., To avoid exceedingthe mandatory Environmental Assessment WorksheetCategory for air emissions

Nitrogen Oxides: less than or equal to 450 parts per million using 24-hour RollingAverage


Nitrogen Oxides: less than or equal to 859.0 lbs/hour using 24-hour RollingAverage


Nitrogen Oxides: less than or equal to 692 tons/year using 365-day Rolling Average Title I Condition: Limit to avoid classification as a majormodification for NOx under 40 CFR Section 52.21

Nitrogen Oxides: less than or equal to 41 parts per million using 365-day RollingAverage , by dry volume (at 0% oxygen). This limit is effective on October 1, 2005,with the initial calculation for compliance performed on September 30, 2006. Thislimit is established on an interim basis and is potentially subject to change basedon subsequent discussions with EPA (Consent Decree driven).


Hydrogen Sulfide: less than or equal to 0.10 grains/dry standard cubic foot using3-hour Rolling Average (230 mg/dscm[162 ppm]). This limit applies to the H2Scontent of fuel gas burned in Boiler 17H-2 (CE-004) and Boiler 17H-4 (CE 005) anddoes not apply during periods of startup, shutdown, or malfunction. Existingcontinuous H2S monitoring systems on the existing refinery fuel gas mix drums willbe used to demonstrate compliance with this limit for refinery gas combusted in theboilers.

40 CFR 60.104(a)(1); Minn. R. 7011.1490, subp. 2

Opacity: less than or equal to 30 percent opacity , except for one six-minuteaverage opacity reading in any one hour period. Limit does not apply duringstartup, shutdown, or malfunction.

40 CFR Section 60.102; 40 CFR Section 60.105; 40CFR Section 60.11; Minn. R. 7011.1410; Minn. R.7011.1435;[ Meet the requirements under 40 CFRSection 63.1564(c)(1)]

B. CEM REQUIREMENTS FOR SO2 hdr



SO2 Emissions Measuring: The Permittee shall use a sulfur dioxide CEMS tomeasure sulfur dioxide emissions from SV 019 and SV 021.

Title I Condition: CAAA of 1990; Minn. R. 7017.1006

SO2 Emissions Calculations and Recordkeeping: The Permittee shall maintainrecords of the calculated SO2 emissions of the following:

1. The Permittee shall use the SO2 CEMS to calculate and record each 1-houraverage concentration (dry, 0% oxygen, ppmv of SO2 from the FCCU;

2. The Permittee shall calculate and record the 7-day average (arithmetic mean)concentration of SO2 using all of the 1-hour average concentration values obtainedduring the pervious seven successive 24-hour periods; and

3. The Permittee shall calculate and record the 365-day average (arithmetic mean)concentration of SO2 using all of the 1-hour average concentration values obtainedduring the previous 365-day period.

Title I Condition: SIP for SO2 NAAQS 40 CFR pt. 50;MN State Implementation Plan (SIP); Minn. R.7017.1006; 40 CFR Section 52.21

C. COMS REQUIREMENTS hdr

Continuous Opacity Monitoring System (COMS): The Permittee shall calibrate,operate and maintain a continuous monitoring system for the measurement ofopacity.

40 CFR Section 60.105(a); Minn. R. 7011.1435. A.;Minn. R. 7017.1010, subp. 1.A.C.; Minn. R. 7011.1420,subp. 1.A. (1); [Meet the requirements 40 CFR Section63.1564(c)(1)]

Emissions Monitoring: The owner or operator shall use a COMS to measureopacity emissions from SV 019.


QA Plan Required: Develop and implement a written quality assurance plan whichcovers each COMS. The plan shall be on site and available for inspection within30 days after monitor certification. The plan shall contain the written procedureslisted in Minn. R. 7017.1210, subp. 1.

Minn. R. 7017.1210



03700011 - 006

Facility Name:

Permit Number:

A-213

Continuous Operation: COMS must be operated and data recorded during allperiods of emission unit operation including periods of emission unit start-up,shutdown, or malfunction except for periods of acceptable monitor downtime. Thisrequirement applies whether or not a numerical emission limit applies during theseperiods. A COMS must not be bypassed except in emergencies where failure tobypass would endanger human health, safety, or plant equipment.

Acceptable monitor downtime includes reasonable periods as listed in Items A, B,C and D of Minn. R. 7017.1090, subp. 2.

Minn. R. 7017.1090, subp. 1; 40 CFR Section 60.13(e)

COMS Daily Calibration Drift (CD) Check: The CD shall be quantified and recordedat zero (low-level) and upscale (high-level) opacity at least once daily. The COMSmust be adjusted whenever the calibration drift (CD) exceeds twice thespecification of PS-1 of 40 CFR 60, Appendix B.

Minn. R. 7017.1210, subp. 2; 40 CFR Section 60.13(d)

COMS Calibration Error Audit: due before end of each half-year following COMSCertification Test Conduct three point calibration error audits at least 3 monthsapart but no greater than 8 months apart. Filter values used shall be determined inaccordance with 40 CFR pt. 60, Appendix B.

40 CFR pt. 60, Appendix B; Minn. R. 7017.1210, subp.3

All COMS shall complete a minimum of one cycle of sampling and analyzing foreach successive 10-second period and one cycle of data for each successive6-minute period.

Minn. R. 7017.1200, subp. 1, 2 & 3; 40 CFR Section60.13(e)(1); 40 CFR Section 60.13(h)

Recordkeeping: The owner or operator must retain records of all COMS monitoringdata and support information for a period of five years from the date of themonitoring sample, measurement or report. Records shall be kept at the source.

Minn. R. 7017.1130

D. CEM REQUIREMENTS FOR CO hdr

Continuous Emission Monitoring System (CEMS): The Permittee shall calibrate,operate and maintain a continuous emissions monitoring system for themeasurement of CO emissions from SV 019.


Carbon Monoxide Calculations and Recordkeeping: The Permittee shall maintainrecords of the calculated CO emissions in pounds per hour (lb/hr).

Minn. R. 7017.1006

Carbon Monoxide Recordkeeping: The Permittee shall maintain records of thecalculated hourly average of CO in ppm, on a dry basis.


E. CMS REQUIREMENTS FOR CO hdr

Continuous Monitoring System (CMS): The Permittee shall calibrate, operate andmaintain a CMS for the measurement of CO emissions from the FCC Regenerator.

40 CFR Section 63.1565(b)(1); Minn.R. 7017.1006

FCC Regenerator Monitoring: The Permittee shall monitor the CO in FCC flue gasat outlet of the FCC Regenerator whenever the FCC CO boilers are bypassed.


CMS QA/QC: Twice a week, the Permittee shall calibrate CO flue gas analyzerinstalled at the outlet duct of the FCC Regenerator.


CMS QA/QC: On an annual basis, the Permittee shall conduct a simple test tocompare data from the flue gas analyzer whenever a relative accuracy test isconducted on the CO CEMS on the ESP stack.


F. CEM REQUIREMENTS FOR NOX hdr

Continuous Emission Monitoring System (CEMS): The Permittee shall calibrate,operate and maintain a continuous monitoring system for the measurement ofnitrogen oxide (NOx).


NOx Emissions Measuring: The Permittee shall use NOx CEMS to measurenitrogen oxide emissions from SV 019.


NOx Emissions Calculation and Recordkeeping: The Permittee shall use the NOxCEMS to calculate and record NOx emissions from SV 019 in units of parts permillion (ppm) and in units of pounds of NOx per hour (lb/hr).

Title I Condition: Recordkeeping and Calculations forBACT limit for NOx, 40 CFR 52.21

NOx Emissions Recordkeeping: The Permittee shall record the daily and 365-dayrolling average of NOx emissions for EU 228.

Minn. R. 7007.0800, subp. 5

G. GENERAL REQUIREMENTS FOR ALL CEMS hdr









03700011 - 006

Facility Name:

Permit Number:

A-214


Minn. R. 7017.1170, subp. 3


Minn. R. 7017.1090, subp. 1





Minn. R. 7017.1170, subp. 2


Minn. R. 7007.1130

H. PERFORMANCE TESTING REQUIREMENTS hdr

Performance Test: due 180 days after 10/31/2005 for PM and PM10 emissionsfrom SV 019. (Note: Testing completed on November 7, 2005)

For additional applicable performance test requirements see "General PerformanceTest Requirements" in Table A, subject item, "Total Facility".

40 CFR Section 60.106; Minn. R. 7011.1435; Minn. R.7007.0800, subp. 4

Performance Test: due before end of each half-year following Performance Test forPM and PM10 emissions.

Minn. R. 7017.2020, subp. 1

I. OTHER REQUIREMENTS hdr



Monitoring FCC for ppm SO2 limit: If the Permittee is complying with FCC 50 ppmvSO2 limit, when FCC SO2 or O2 emissions data is not obtained because of CMSsystem breakdowns, repairs, calibration checks and zero and span adjustments,the Permittee shall obtain emissions data via alternate means to provide aminimum of 18 hours per day in at least 22 out of 30 rolling successive calendardays:i) The test methods as described in 40 CFR Section 60.106(k);ii) A spare continuous monitoring system; oriii) Other monitoring systems as approved by the MPCA.

40 CFR Section 60.105(a)(13); 40 CFR Section60.106; Minn. R. 7011.1435

Monitoring FCC SO2 concentration: If the Permittee is complying with FCC SO2concentration limit of 50 ppmv (dry, 0% oxygen), the Permittee shall monitor SO2emissions in ppmvd SO2 (dry, 0% oxygen)

CAAA of 1990; Minn. R. 7007.0800, subp. 5; Minn. R.7011.1435

Testing to Change Compliance Option: If the Permittee is changing FCC SO2compliance option, the Permittee shall begin conducting daily tests as specifiedunder 40 CFR Section 60.108(d) immediately upon electing to become subject to adifferent provision of 40 CFR Section 60.104(b)

40 CFR Section 60.108; Minn. R. 7011.1425; Minn. R.7011.1430; Minn. R. 7011.1435

J. O2 MONITOR REQUIREMENTS hdr



03700011 - 006

Facility Name:

Permit Number:

A-215


Minn. R. 7007.0800, subp. 4


Minn. R. 7007.0800, subp. 4

K. BYPASS MONITORING FOR PM EMISSIONS hdr

CO Bypassed Emissions Recordkeeping: The Permittee shall record that theFCCU emissions exceed 1.0 lbs PM/1000 lb coke burn, when the FCCU CO boilersare bypassed.

Alternative Monitoring Plan to Comply with 40 CFRSection 60.13

CO Bypassed Emissions Report: The Permittee shall submit a report to the MPCA,that the FCCU emission exceed 1.0 lbs PM/1000 lbs coke burn, that emissions areapproximately 3 lbs PM/1000 lbs coke burn and that emissions exceed 30%opacity, when the FCCU CO boilers are bypassed.

Alternative Monitoring Plan to Comply with 40 CFRSection 60.13

L. NATIONAL EMISSION STANDARDS FOR HAZARDOUS AIR POLLUTANTS hdr

The Permittee shall comply with 40 CFR pt. 63, subp. UUU by compliance date,April 11, 2005.




03700011 - 006

Facility Name:

Permit Number:

A-216

Subject Item: EU 241 #1 H2 Plant Reformer/Heater



SV 073 33H1 2 Stack (33H4)








Sulfur Dioxide: less than or equal to 1.75 lbs/million Btu heat input using 3-hourRolling Average

Minn. R. 7011.1405, subp. 2




Minn. R. 7007.0800, subp. 5




Minn. R. 7017.2020, subp. 1




03700011 - 006

Facility Name:

Permit Number:

A-217

Subject Item: EU 245 Merox Off Gas Incinerator (old SRU 1/2 incinerator)


MR 069 34H3 SO2 Analyzer

MR 071 EMRC Temperature Thermocouple for 34H-3

MR 147 34H3 Flow Meter for Exhaust Gases

SV 078 34H2 Stack (34H3 is stack)


Sulfur Dioxide: less than or equal to 230 lbs/hour using 3-hour Rolling Average Title I Condition: SIP for SO2 NAAQS, 40 CFR pt. 50;MN State Implementation Plan (SIP)




SO2 Emission Calculation and Recordkeeping: The Permittee shall maintainrecords of the calculated SO2 emissions of hourly averages of total SO2 emissionsin lb/hr.




C. CEM REQUIREMENTS FOR SO2 hdr



SO2 Emissions Measuring: The Permittee shall use a sulfur dioxide CEMS tomeasure sulfur dioxide emissions from SV 042.

Minn. R. 7017.1006

CEMS QA/QC: The Permittee of an affected facility is subject to the performancespecifications listed in 40 CFR 60, Appendix B and shall operate, calibrate, andmaintain each CEMS according to the QA/QC procedures in 40 CFR pt. 60,Appendix F as amended and maintain a written QA/QC program available in a formsuitable for inspection.







Minn. R. 7017.1170, subp. 3


Minn. R. 7017.1090, subp. 1



03700011 - 006

Facility Name:

Permit Number:

A-218




QA Plan: Develop and implement a written quality assurance plan that covers theCEMS. The plan shall be on site and available for inspection within 30 days aftermonitor certification. The plan shall contain all of the information required by 40CFR 60, App. F, section 3. The CEMS manufactures recommended spare partsshall be kept onsite unless the Commissioner approves exclusions.

Minn. R. 7017.1170, subp. 2


Minn. R. 7007.1130

D. REPORTING REQUIREMENTS hdr



03700011 - 006

Facility Name:

Permit Number:

A-219

Subject Item: EU 254 Unit 94H3-Thermal Oxidizer Back-up


CE 051 Other


SV 146 94H3 Stack

What to do Why to do itLIMIT APPLIES TO THE OSWTP DURING OPERATION OF EITHER EU 254 OREU 282). EU 282 IS THE PRIMARY OSWTP OXIDIZER; EU 254 IS THEBACKUP.)

SEE ALL REQUIREMENTS UNDER EU 282.

hdr



03700011 - 006

Facility Name:

Permit Number:

A-220

Subject Item: EU 276 Central Buffer Zone Offgas


MR 002 Natural Gas Flow to 86H41

MR 099 SVE System: Temperature Monitor for Central Buffer

SV 143 86H41 Stack




B. OPERATIONAL REQUIREMENTS FOR POLLUTION CONTROL EQUIPMENT hdr

Total Organic Compounds: greater than or equal to 95 percent by weight asdemonstrated by performance test.

40 CFR Section 61.349(a)(2)(i)(A); Minn. R.7017.2025; Minn. R. 7011.9930. E.

Temperature: Maintain temperature 28 degree Celsius below the most recentperformance test design temperature as a 3-hour rolling average.

40 CFR Section 61.354(c)(1); 40 CFR Section61.356(j)(4); Minn. R. 7017.2025; Minn. R. 7011.9930.E.

The Permittee must design the control device to meet performance standard:Reduce the organic emissions vented to it by 95 weight percent or greater;

40 CFR Section 61.349(a)(2)(i)(A); Minn. R.7011.9930. E.


Alternative Monitoring Plan (AMP): If the Draeger shows greater than 81 ppm H2Sin the fuel gas stream monitored under AMP, the Permittee shall increasemonitoring per flowchart in approved NPSP, subpart J AMP.

40 CFR Section 60.105(a)(4); Minn. R. 7011.1435.A.

Twice per Season Measurement of H2S: Twice per season, the Permittee shallmeasure H2S in soil vapor extraction offgas at the thermal oxidizer inlet during theoperating season using a Draeger or other-length-of-stain tube beginning in the2003 operating season and continuing each operating season until soil vaporextraction operation ceases.

40 CFR Section 60.105(a)(4); Minn. R. 7011.1435. A.

The Permittee shall install, calibrate, maintain, and operate according to themanufacturer's specifications a device to continuously monitor the control deviceoperation as specified in 40 CFR Section 61.354(c)(1), unless alternativemonitoring procedures or requirements are approved for that facility by theAdministrator. The Permittee shall inspect at least once each operating day thedata recorded by the monitoring equipment (e.g., temperature monitor or flowindicator) to ensure that the control device is operating properly.

40 CFR Section 61.354(c)(1); Minn. R. 7011.9930. E.


Daily Records: The Permittee shall maintain continuous records of the temperatureof the gas stream in the combustion zone of the incinerator and records of all3-hour periods of operation during which the average temperature of the gasstream in the combustion zone is more than 28 °C (50 °F) below the designcombustion zone temperature.

40 CFR Section 61.356(j)(4); Minn. R. 7011.9930.E.

CMS Records: The Permittee shall maintain records of monitoring data, monitoringsystem calibration checks, and the occurrence and duration of any period duringwhich the monitoring system is malfunctioning or inoperative. These records shallbe maintained at the source for a minimum of 2 years and made available, uponrequest, for inspection by the Administrator.

40 CFR Section 61.14(f); Minn. R. 7011.9900



03700011 - 006

Facility Name:

Permit Number:

A-221

Performance test was used to determine control device performance; therefore, thePermittee will maintain the following records:

(i) A description of how it is determined that the test is conducted when the wastemanagement unit or treatment process is operating at the highest load or capacitylevel. This description shall include the estimated or design flow rate and organiccontent of each vent stream and definition of the acceptable operating ranges ofkey process and control parameters during the test program.

(ii) A description of the control device including the type of control device, controldevice manufacturer's name and model number, control device dimensions,capacity, and construction materials.

(iii) A detailed description of sampling and monitoring procedures, includingsampling and monitoring locations in the system, the equipment to be used,sampling and monitoring frequency, and planned analytical procedures for sampleanalysis

(iv) All test results.

40 CFR Section 61.356(f)(3)(i-iv); 40 CFR Section61.356(j)(4); Minn. R. 7011.9930. E.

Record H2S: The Permittee shall record H2S in Soil Vapor Extraction offgas duringeach test.



Quarterly Report: The Permittee shall prepare and submit quarterly reports for each3-hour period of operation during which the average temperature of the gas streamin the combustion zone of a thermal vapor incinerator, as measured by thetemperature monitoring device, is more than 28 °C (50 °F) below the designcombustion zone temperature.

40 CFR Section 61.357(d)(7)(iv)(A); Minn. R.7011.9930. E.; Minn. R. 7017.1010, subp. 3



03700011 - 006

Facility Name:

Permit Number:

A-222

Subject Item: EU 277 West Buffer Zone Offgas

Associated Items: CE 033 Other


MR 100 SVE System: Temperature Monitor for West Buffer

MR 140 Natural Gas 88H-2 SVE Oxidizer

SV 142 88H2 Stack




B. OPERATIONAL REQUIREMENTS FOR POLLUTION CONTROL EQUIPMENT hdr

Total Organic Compounds: greater than or equal to 95 percent by weight asdemonstrated by performance test.

40 CFR Section 61.349(a)(2)(i)(A); Minn. R.7017.2025; Minn. R. 7011.9930. E.

Temperature: Maintain temperature 28 degree Celsius below the most recentperformance test design temperature as a 3-hour rolling average.

40 CFR Section 61.354(c)(1); 40 CFR Section61.356(j)(4); Minn. R. 7017.2025; Minn. R. 7011.9930.E.

The Permittee must design the control device to meet performance standard:Reduce the organic emissions vented to it by 95 weight percent or greater;

40 CFR Section 61.349(a)(2)(i)(A); Minn. R.7011.9930. E.


Alternative Monitoring Plan (AMP): If the Draeger shows greater than 81 ppm H2Sin the fuel gas stream monitored under AMP, the Permittee shall increasemonitoring per flowchart in approved NPSP, subpart J AMP.

40 CFR Section 60.105(a)(4); Minn. R. 7011.1435.A.

Twice per Season Measurement of H2S: Twice per season, the Permittee shallmeasure H2S in soil vapor extraction offgas at the thermal oxidizer inlet during theoperating season using a Draeger or other-length-of-stain tube beginning in the2003 operating season and continuing each operating season until soil vaporextraction operation ceases.


The Permittee shall install, calibrate, maintain, and operate according to themanufacturer's specifications a device to continuously monitor the control deviceoperation as specified in 40 CFR Section 61.354(c)(1), unless alternativemonitoring procedures or requirements are approved for that facility by theAdministrator. The Permittee shall inspect at least once each operating day thedata recorded by the monitoring equipment (e.g., temperature monitor or flowindicator) to ensure that the control device is operating properly.

40 CFR Section 61.354(c)(1); Minn. R. 7011.9930. E.


Daily Records: The Permittee shall maintain continuous records of the temperatureof the gas stream in the combustion zone of the incinerator and records of all3-hour periods of operation during which the average temperature of the gasstream in the combustion zone is more than 28 °C (50 °F) below the designcombustion zone temperature.

40 CFR Section 61.356(j)(4); Minn. R. 7011.9930.E.

CMS Records: The Permittee shall maintain records of monitoring data, monitoringsystem calibration checks, and the occurrence and duration of any period duringwhich the monitoring system is malfunctioning or inoperative. These records shallbe maintained at the source for a minimum of 2 years and made available, uponrequest, for inspection by the Administrator.

40 CFR Section 61.14(f); Minn. R. 7011.9900



03700011 - 006

Facility Name:

Permit Number:

A-223

Performance test was used to determine control device performance; therefore, thePermittee will maintain the following records:

(i) A description of how it is determined that the test is conducted when the wastemanagement unit or treatment process is operating at the highest load or capacitylevel. This description shall include the estimated or design flow rate and organiccontent of each vent stream and definition of the acceptable operating ranges ofkey process and control parameters during the test program.

(ii) A description of the control device including the type of control device, controldevice manufacturer's name and model number, control device dimensions,capacity, and construction materials.

(iii) A detailed description of sampling and monitoring procedures, includingsampling and monitoring locations in the system, the equipment to be used,sampling and monitoring frequency, and planned analytical procedures for sampleanalysis

(iv) All test results.

40 CFR Section 61.356(f)(3)(i-iv); 40 CFR Section61.356(j)(4); Minn. R. 7011.9930. E.

Record H2S: The Permittee shall record H2S in Soil Vapor Extraction offgas duringeach test.



Quarterly Report: The Permittee shall prepare and submit quarterly reports for each3-hour period of operation during which the average temperature of the gas streamin the combustion zone of a thermal vapor incinerator, as measured by thetemperature monitoring device, is more than 28 °C (50 °F) below the designcombustion zone temperature.

40 CFR Section 61.357(d)(7)(iv)(A); Minn. R.7011.9930. E.; Minn. R. 7017.1010, subp. 3



03700011 - 006

Facility Name:

Permit Number:

A-224

Subject Item: EU 282 OSWTP - Thermal Oxidizer



CE 051 Other

MR 101 94H1 & 94H3 Natural Gas Flow

MR 102 94H-1 Thermocouple for Fire Box Temperature

MR 103 Temperature Monitor (Stack) for 94H-3 Thermal Oxidizer



MR 145 EMRC Flow Meter for 94H1 Exhaust Gases


SV 125 94H1 Stack

SV 146 94H3 Stack

What to do Why to do itA. EMISSION LIMITS(LIMITS APPLY TO THE OSWTP DURING OPERATION OF EITHER EU 254 OREU 282). EU 282 IS THE PRIMARY OSWTP OXIDIZER; EU 254 IS THEBACKUP.)

hdr




Operational Restriction: The Permittee shall only operate one oxidizer at a time. Title I Condition: SIP for SO2 NAAQS, 40 CFR pt. 50;MN State Implementation Plan (SIP)

Sulfur Dioxide: less than or equal to 38.0 tons/year using 365-day Rolling Sum foremissions from the combustion of waste gas. This limit shall be effective upon thecompletion of initial certification of the SO2 CEMS.

For the first 365 days after initial certification of the SO2 CEMS, SO2 emissions intons/year are limited as determined by the following equation:E = 38.0 [0.15 + 0.85(D/365)]whereE = SO2 emissions in total tons since startupD = number of day after startup


Hydrogen Sulfide: less than or equal to 0.10 grains/dry standard cubic foot using3-hour Rolling Average (230 mg/dscm[162 ppm]). This limit applies to the H2Scontent of fuel gas burned in CE 028 and CE 029 and does not apply duringperiods of startup, shutdown, upset and malfunction provided that during suchperiods good air pollution control practices are implemented.

40 CFR Section 60.104(a)(1); 40 CFR Section60.105(e)(3)(ii); 40 CFR Section 60.8(c); Minn. R.7011.1420, subp. 2; Minn. R. 7011.1435 A

Opacity: less than or equal to 20 percent opacity Minn. R. 7011.0110; Minn. R. 7011.0120

Fuel Usage: less than or equal to 625 million cubic feet/year using 365-day RollingSum of natural gas consumption.


Fuel Restriction: The Permittee shall burn natural gas only. Title I Condition: SIP for SO2 NAAQS, 40 CFR pt. 50;MN State Implementation Plan (SIP)

B. RECORDKEEPING AND CALCULATIONS REQUIREMENTS hdr

Hourly SO2 Emissions: The Permittee shall use the SO2 CEMS and the waste gasflow meters to calculate and record each 1-hour average SO2 lb/hr emission ratefrom EU 282 OR EU 254.

Minn. R. 7007.0800, subp. 5

Daily SO2 Emissions: The Permittee shall calculate and record daily and a365-day rolling average of the SO2 emissions from EU 282 OR EU 254 for theprevious 365-day period.

Minn. R. 7007.0800, subp. 5

Monthly SO2 Emissions: The Permittee shall calculate and record the monthly and12-month rolling average SO2 emissions from EU 282 OR EU 254.

Minn. R. 7007.0800, subp. 5



03700011 - 006

Facility Name:

Permit Number:

A-225

Fuel Usage Recordkeeping: The Permittee shall calculate and record daily and365-day rolling sum of the total natural gas comumption from EU 282 OR EU 254for the previous 365-day period.

Minn. R. 7007.0800, subp. 5

C. OTHER REQUIREMENT hdr


Minn. R. 7007.0800, subp. 2; MPCA StipulationAgreement May 1998

D. MONITORING REQUIREMENT hdr

E. CEM REQUIREMENTS FOR SO2 hdr

SO2 Emissions: The Permittee shall use the combination of the waste gas flowmeter(s) and SO2 CEMS to measure SO2 emissions from SV 125 or SV 146.

40 CFR Section 60.105(a)(4); Minn. R. 7007.0800,subp. 4

H2S in the Gas: The Permittee shall use the H2S AMP to provide a record of H2Scontent in ppm or mg/dscm as referenced in U.S. EPA Region 5 approval dated10/31/05.


Flow Meter Calibration: The Permittee shall calibrate all required flow metersaccording to manufacturer's specifications, but no less than annually. Maintaindocumentation showing that the calibrations have been completed.

Minn. R. 7007.0800, subp. 4








40 CFR pt. 60, Appendix F, Section 4.1; 40 CFR60.13(d)(1); Minn. R. 7017.1170, subp. 3


Minn. R. 7017.1090, subp. 1





Minn. R. 7017.1170, subp. 2


Minn. R. 7007.1130

Records of Startup, Shutdown or Malfunction: Any owner or operator subject to theprovisions of NSPS shall maintain records of the occurrence and duration of anystartup, shutdown, or malfunction in the operation of an affected facility; anymalfunction of the air pollution control equipment; or any periods during which a




03700011 - 006

Facility Name:

Permit Number:

A-226

F. POLLUTION CONTROL EQUIPMENT hdr

Temperature: greater than or equal to 1300 degrees F using 3-hour RollingAverage for 94H-1(EU 282) and 1315 degree F using a 3-hour Rolling Average for94H-3 (EU 254). The temperature shall be measured at the outlet of the oxidizer inthe stack.

Minn. R. 7007.0800, subp. 2; Minn. R. 7017.2025

The Permittee shall maintain and operate a thermocouple monitoring device thatcontinuously indicates and records the combustion chamber temperature of thethermal 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 averagecombustion chamber temperature.

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

Minn. R. 7007.0800, subps. 4 and 5

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

Minn. R. 7007.0800, subps. 2 and 14

Daily Monitoring: The Permittee shall verify the operation of the temperaturerecording device at least once each operating day to verify that it is working andrecording properly. The Permittee shall maintain a written or electronic record of thedaily verifications.

Minn. R. 7007.0800, subp. 4 and 5

Quarterly Inspections: At least once per calendar quarter, the Permittee shallinspect the control equipment internal and external system components, includingbut not limited to the refractory, heat exchanger, and electrical systems. ThePermittee shall maintain a written record of the inspection and any correctiveactions taken resulting from the inspection.

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

Corrective Actions: If the temperature is below the minimum specified by this permitor if the thermal 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 thermal oxidizer. The Permittee shall keep a record of the type anddate of any corrective action taken.

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

G. REPORTING hdr



03700011 - 006

Facility Name:

Permit Number:

A-227

Subject Item: EU 294 Hydrocracker Feed Heater

Associated Items: GP 003 ULSD Project CO Emissions

GP 004 ULSD Project VOC Emissions




SV 165 New Hydrocracker Feed Heater and Reboiler





Hydrogen Sulfide: less than or equal to 0.10 grains/dry standard cubic foot using3-hour Average (230 mg/dscm[162 ppm]). This limit applies to the hydrogen sulfidecontent of fuel gas burned in the units. Existing continuous H2S monitoringsystems on the existing refinery gas mix drums will be used to demonstratecompliance with this limit.

40 CFR Section 60.104(a)(1); Minn. R. 7011.1410,subp. 2; (most stringent, meets the limit set by: Minn.R. 7011.1410, subp. 3, item A)

Sulfur Dioxide: less than or equal to 1.75 lbs/million Btu heat input using 3-hourRolling Average . The total emissions of sulfur dioxide from all existing and newfuel gas combustion devices and indirect heating equipment shall be divided by thetotal heat input of all such devices and equipment to determine compliance withthis part; provided that no owner or operator shall cause to be discharged from anyone unit of new indirect heating equipment any gases which contain sulfur dioxidein excess of 3.0 pounds per million Btu heat input.

Minn. R. 7011.1410, subp. 3.A.


Minn. R. 7011.1410, subp. 3.B.

Opacity: less than or equal to 20 percent opacity ; except for one six-minute periodper hour of not more than 60% opacity. Compliance with the fuel restrictionrequirement constitutes compliance with this limit.

Minn. R. 7011.1410, subp. 3.B.


Fuel Restriction: Burn refinery fuel gas and/or natural gas only in the unit. Title I Condition: Limit to avoid classification as a majormodification under 40 CFR Section 52.21


Minn. R. 7007.0800, subp. 5

D. NOTIFICATIONS FOR NSPS AND NESHAPS hdr

E. CEM REQUIREMENTS FOR CO hdr

The Permittee shall install, operate and maintain a continuous emission monitoringsystem(CEMS) for CO according to the following procedures:

(1) The CEMS must be installed, operated, and maintained according toPerformance Specification (PS) 4A of 40 CFR pt. 60, Appendix B, and according tothe site-specific monitoring plan developed according to 40 CFR Section63.7505(d);

(2) The Permittee must conduct a performance evaluation of the CEMS accordingto the requirements in 40 CFR Section 63.8 and according to PS 4A of 40 CFR pt.60, Appendix B.

(3) The CEMS must complete a minimum of one cycle of operation(sampling,analyzing, and data recording) for each successive 15-minute period.

(4) The CEMS data must be reduced as specified in 40 CFR Section 63.8(g)(2).

40 CFR Section 63.7525(a)



03700011 - 006

Facility Name:

Permit Number:

A-228

(5) Must calculate and record a 30-day Rolling Average emission rate on a dailybasis. A new 30-day Rolling Average emission rate is calculate as the average ofall of the hourly CO emission data for the preceding 30 operating days.

(6) For purposes of calculating data averages, the Permittee must not use the datarecorded during periods of monitoring malfunctions, associated repairs,out-of-control periods, required quality assurance or control activities, or when yourprocess heater is operating at less than 50 percent of its rated capacity. ThePermittee must use all the data collected during all other periods in assessingcompliance. Any period for which the monitoring system is out-of-control and dataare not available for required calculations constitutes a deviation from themonitoring requirements.

CONTINUED40 CFR Section 63.7525(a)



CO Emissions Measuring: The Permittee shall use a CO CEMS to measure COemissions from SV165.


Minn. R. 7017.1006

CEM Certification Test: due 60 days after achieving maximum capacity but not laterthat 180 days after initial startup. Follow the procedures in 40 CFR pt. 60,Appendix B

40 CFR Section 63.8(e)


CMS Quality Control (QC) Program: The Permittee shall development andimplement a CEMS QC program and keep records of such procedures of 40 CFRpt. 60, Appendix B. 40 CFR pt. 60, Appendix F shall be used to determineout-of-control periods for CEMS.



Minn. R. 7017.1170, subp. 2








40 CFR Section 63.8(c)(6); Minn. R. 7017.1170, subp.3


40 CFR Section 63.8(c)(4); Minn. R. 7017.1090, subp.1; Minn. R. 7017.1002, subp 10. A.-C



03700011 - 006

Facility Name:

Permit Number:

A-229

Acceptable monitor downtime includes reasonable periods due to the followingcauses:


40 CFR Section 63.8(c)(4); Minn. R. 7017.1090, subp.1; Minn. R. 7017.1002, subp. 10. A.-C (CONTINUED)

Startup, Shutdown and Malfunction(SSM) Plan: The Permittee shall develop andimplement a written startup, shutdown, and malfunction plan which complies with40 CFR Section 63.6(e)(3).

40 CFR Section 63.6(e)(3)

Operation and Maintenance (O & M) of CEMS: The Permittee shall ensure theimmediate repair or replacement of parts to correct routine or predictablemalfunctions as defined in the source's startup, shutdown, and malfunction plan. Ifthe plan is followed and the monitor repaired immediately, this action shall bereported in the source's semiannual startup, shutdown, and malfunction report.Those malfunction which are not addressed in the plan shall be reported within 24hours after commencing actions inconsistent with the plan.


Repair and Replacement Report: due semiannually if facility followed themalfunction plan; or due within 24 hours after commencing actions inconsistent withthe plan with a follow-up report within 2 weeks after commencing action whichcontains information listed in 40 CFR Section 63.8(c)(ii).


F. RECORDKEEPING AND REPORTING REQUIREMENTS hdr

NOx Calculation and Recordkeeping: The Permittee shall calculate and record thedaily and 365-day rolling sum NOx emissions from EU 294 and EU 295. Emissionsshall be calculated using 0.045 lb/mmBtu until until the CEMS is certified.

Title I Condition: Recordkeeping associated with a limittaken to avoid classification as a major modificationunder 40 CFR Section 52.21

Recordkeeping: The Permittee must keep records of CO levels according to 40CFR Section 63.7555(b).

40 CFR Section 63.7540(a)(10)


Minn. R. 7017.1130


40 CFR Section 63.10(d)(5)(i)-(ii); 40 CFR Section63.654(b); 40 CFR Section 63.9(i); Minn. R.7011.7280; Minn. R. 7019.0100, subp. 2A-D



03700011 - 006

Facility Name:

Permit Number:

A-230

Subject Item: EU 295 Hydrocracker Reboiler











Hydrogen Sulfide: less than or equal to 0.10 grains/dry standard cubic foot using3-hour Average (230 mg/dscm[162 ppm]). This limit applies to the hydrogen sulfidecontent of fuel gas burned in the units. Existing continuous H2S monitoringsystems on the existing refinery gas mix drums will be used to demonstratecompliance with this limit.

40 CFR Section 60.104(a)(1); Minn. R. 7011.1410,subp. 2; (most stringent, meets the limit set by: Minn.R. 7011.1410, subp. 3, item A)


Minn. R. 7011.1410, subp. 3.A.


Minn. R. 7011.1410, subp. 3.B.


Minn. R. 7011.1410, subp. 3.B.


Fuel Restriction: Burn refinery fuel gas and/or natural gas only in the unit. Title I Condition: Limit to avoid classification as a majormodification under 40 CFR Section 52.21


Minn. R. 7007.0800, subp. 5

C. NOTIFICATIONS FOR NSPS AND NESHAPS hdr










03700011 - 006

Facility Name:

Permit Number:

A-231


(6) For purposes of calculating data averages, the Permittee must not use the datarecorded during periods of monitoring malfunctions, associated repairs,out-of-control periods, required quality assurance or control activities, or when yourprocess heater is operating at less than 50 percent of its rated capacity. ThePermittee must use all the data collected during all other periods in assessingcompliance. Any period for which the monitoring system is out-of-control and dataare not available for required calculations constitutes a deviation from themonitoring requirements.






Minn. R. 7017.1006







Minn. R. 7017.1170, subp. 2








40 CFR Section 63.8(c)(6); Minn. R. 7017.1170, subp.3


40 CFR Section 63.8(c)(4); Minn. R. 7017.1090, subp.1; Minn. R. 7017.1002, subp 10. A.-C



03700011 - 006

Facility Name:

Permit Number:

A-232



40 CFR Section 63.8(c)(4); Minn. R. 7017.1090, subp.2; Minn. R. 7017.1002, subp. 10. A.-C







E. RECORDKEEPING AND REPORTING REQUIREMENTS hdr

NOx Calculation and Recordkeeping: The Permittee shall calculate and record thedaily and 365-day rolling sum NOx emissions from EU 294 and EU 295. Emissionsshall be calculated using 0.045 lb/mmBtu until a performance test is completed.The Permittee shall then use the most recent correlation to determine NOxlb/MMBtu to calculate NOx emissions.



40 CFR Section 63.7540(a)(10)


Minn. R. 7017.1130





03700011 - 006

Facility Name:

Permit Number:

A-233

Subject Item: EU 296 No. 4 Hydrogen Plant Reformer



SV 166 New Hydrogen Plant Reformer Furnace


Nitrogen Oxides: less than or equal to 157.7 tons/year using 365-day Rolling Sum Title I Condition: Limit to avoid classification as amajor modification under 40 CFR Section 52.21; Minn.R. 7007.0800, subp. 2

Hydrogen Sulfide: less than or equal to 0.10 grains/dry standard cubic foot using3-hour Average (230 mg/dscm[162 ppm]). This limit applies to the hydrogen sulfidecontent of fuel gas burned in the units. Existing continuous H2S monitoringsystems on the existing refinery gas mix drums will be used to demonstratecompliance with this limit. For the PSA purge gas combusted in the unit, anAlternative Monitoring Plan shall be submitted to EPA as required by the"Monitoring" requirements in this section.






Minn. R. 7011.1410, subp. 3.A.


Minn. R. 7011.1410, subp. 3.B.


Minn. R. 7011.1410, subp. 3.B.


Fuel Restriction: Burn refinery fuel gas, natural gas or PSA purge gas only in theunit.



Minn. R. 7007.0800, subp. 2

C. CEM REQUIREMENTS FOR NOx hdr

Emissions Monitoring: The Permittee shall use a nitrogen oxides (NOx) CEMS tomeasure NOx emissions from SV 166.

Minn. R. 7017.1006; Minn. R. 7007.0800, subp. 5

Installation of CEMS: The Permittee shall install and operate a NOx CEMS. Minn. R. 7017.1006

CEM Certification Test: due 90 days after Startup of operation of the unit. Minn. R. 7017.1050, subp. 1





03700011 - 006

Facility Name:

Permit Number:

A-234








(6) For purposes of calculating data averages, the Permittee must not use the datarecorded during periods of monitoring malfunctions, associated repairs,out-of-control periods, required quality assurance or control activities, or when yourprocess heater is operating at less than 50 percent of its rated capacity. ThePermittee must use all the data collected during all other periods in assessingcompliance. Any period for which the monitoring system is out-of-control and dataare not availabe for required calculations constitutes a deviation from themonitoring requirements.






Minn. R. 7017.1006














E. ALL CEMS REQUIREMENTS hdr



03700011 - 006

Facility Name:

Permit Number:

A-235


Minn. R. 7017.1170, subp. 3






Minn. R. 7017.1090, subp. 1





Minn. R. 7017.1170, subp. 2


Minn. R. 7007.1130

F. NOTIFICATIONS FOR NSPS AND NESHAPS hdr

G. MONITORING hdr

H. RECORDKEEPING AND REPORTING REQUIREMENTS hdr

NOx Calculation and Recordkeeping: The Permittee shall calculate and record thedaily and 365-day rolling sum NOx emissions from EU 296 and EU 295. Emissionsshall be calculated using 0.045 lb/mmBtu until the CEMS is certified.



40 CFR Section 63.7540(a)(10)





03700011 - 006

Facility Name:

Permit Number:

A-236

Subject Item: EU 312 No. 6 Cooling Tower Diesel Pump

Associated Items: SV 171 No. 6 Cooling Tower Diesel Pump


Sulfur Dioxide: less than or equal to 0.5 lbs/million Btu heat input using 3-hourRolling Average . This requirement is less stringent than the fuel restriction fordiesel fuel sulfur content.

Minn. R. 7011.2300, subp. 2


Minn. R. 7011.2300, subp. 1




Sulfur Content of Fuel: less than or equal to 0.05 percent by weight of diesel fuel. Title I Condition: Limit to avoid classification as a majormodification under 40 CFR Section 52.21; (moststringent, meets the limit set by: Minn. R. 7011.2300,subp. 2)

Visible Emissions (VEs): The Permittee shall check SV 171 for visible emissionswithin 180 days of initial startup.

Minn. R. 7007.0800, subp. 4

C. RECORDKEEPING RQUIREMENTS hdr

Diesel Fuel Certification: The Permittee shall retain written documentation of eachshipment of diesel fuel oil received for the diesel engines. The writtendocumentation shall include the following information: the sulfur content of thediesel fuel, the method used to determine the sulfur content and certification thatthe sulfur content is less than or equal to 0.05 percent by weight.

Minn. R. 7007.0800, subp. 5

Recordkeeping of Hours of Operation: By the 15th day of each month, thePermittee shall record the hours of operation and 12-month rolling sum for theprevious month.

Title I Condition: Recordkeeping associated with thelimit to avoid classification as a major modificationunder 40 CFR Section 52.21

Recordkeeping of Visible Emissions (VEs): The Permittee shall keep records ofthe time and date of the visible emissions inspection, whether or not any VEs wereobserved, and if corrective action was needed.

Minn. R. 7007.0800, subp. 5

Recordkeeping of Corrective Actions: If VEs are observed to be over 10% afteroperating temperatures are attained, the Permittee shall take corrective action assoon as possible to reduce the VEs. If visible emissions continue over 10%opacity, perform a method 9 test with a certified observer. The Permittee shallkeep a record of the corrective actions taken. If the VEs exceed the permitted limit,report as a deviation on the semiannual report.

Minn. R. 7007.0800, subp. 5

D. NATIONAL EMISSION STANDARDS FOR HAZARDOUS AIR POLLUTANTS hdr

The Permittee shall comply with 40 CFR pt. 63, subp. ZZZZ by the compliancedate, February 26, 2007.




03700011 - 006

Facility Name:

Permit Number:

A-237

Subject Item: EU 313 Steam Boiler No. 9

Associated Items: SV 173 Boiler No. 9 Stack


Nitrogen Oxides: less than or equal to 46.3 tons/year using 365-day Rolling Sum Title I Condition: Limit to avoid classification as amajor modification under 40 CFR Section 52.21; Minn.R. 7007.0800, subp. 2

Nitrogen Oxides: less than or equal to 0.20 lbs/million Btu heat input using 30-dayRolling Average (expressed as NO2), if the unit is a high heat release rate unit. A"high heat release rate" is defined as a heat release rate greater than 70,000Btu/hour-cubic foot.

40 CFR Section 60.44(b)(a)

Nitrogen Oxides: less than or equal to 0.10 lbs/million Btu heat input using 30-dayRolling Average (expressed as NO2), if the unit is a low heat release rate unit. A"low heat release rate" is defined as a heat release rate of 70,000 Btu/hr-cubic footor less.

The 30-day rolling average emission rate is calculated as the average of all hourlyemissions data recorded by the monitoring system during the 30 day period. A new30 day rolling average emission rate is calculated each steam generating unitoperating day.

40 CFR Section 60.44(b)(a)




Hydrogen Sulfide: less than or equal to 90 parts per million using 365-day RollingAverage by volume.

Title I Condition: Limit to avoid classification as amajor modification under 40 CFR Section 52.21; Minn.R. 7007.0800, subp. 2

Hydrogen Sulfide: less than or equal to 0.10 grains/dry standard cubic foot using3-hour Rolling Average (230 mg/dscm[162 ppm]). This limit applies to thehydrogen sulfide content of fuel gas burned in the units. Existing continuous H2Smonitoring systems on the existing refinery gas mix drums will be used todemonstrate compliance with this limit.



Minn. R. 7011.1410, subp. 3.A.


Minn. R. 7011.1410, subp. 3.B.


Minn. R. 7011.1410, subp. 3.B.


Fuel Restriction: Burn refinery fuel gas or natural gas only in the unit. Title I Condition: Limit to avoid classification as a majormodification under 40 CFR Section 52.21


Minn. R. 7007.0800, subp. 2

C. CEM REQUIREMENTS FOR NOx hdr

Emissions Monitoring: The Permittee shall use a nitrogen oxides (NOx) CEMS tomeasure NOx emissions from SV 173. Specifications for the operation of themonitoring equipment are in 40 CFR Section 60.48b(c), (d), (e), (f), and AppendixB.


Installation of CEMS: The Permittee shall install and operate a NOx CEMS. Theinstallation and operation of the CEMs will met the performance requirements asspecified in 40 CFR Section 60.46b.

Minn. R. 7017.1006

CEM Certification Test: due 60 days after achieving maximum capacity but no laterthan 180 days after initial startup of operation of the unit.




03700011 - 006

Facility Name:

Permit Number:

A-238







Minn. R. 7017.1006

The Permittee shall install, operate and maintain a continuous emission monitoringsystem (CEMS) for CO according to the following procedures:







(6) For purposes of calculating data averages, the Permittee must use the datarecorded during periods of monitoring malfunctions, associated repairs,out-of-control periods, required quality assurance or control activities, or when yourprocess heater is operating at less than 50 percent of its rated capacity. ThePermittee must use all the data collected during all other periods in assessingcompliance. Any period for which the monitoring system is out-of-control and dataare not availabe for required calculations constitutes a deviation from themonitoring requirements.




CEM Certification Test: due 60 days after achieving maximum capacity but not laterthat 180 days after initial startup. Follow the procedures in 40 CFR pt. 60,Appendix B.













03700011 - 006

Facility Name:

Permit Number:

A-239



E. ALL CEMS REQUIREMENTS hdr


Minn. R. 7017.1170, subp. 3






40 CFR Section 63.8(c)(1); 40 CFR Section 60.13(e);Minn. R. 7017.1090, subp. 1





Minn. R. 7017.1170, subp. 2


Minn. R. 7007.1130

F. NOTIFICATIONS FOR NSPS AND NESHAPS hdr

G. RECORDKEEPING AND REPORTING REQUIREMENTS hdr

NOx Calculation and Recordkeeping: The Permittee shall calculate and record thedaily NOx emissions and 365-day rolling sum of NOx emissions.


Maintain records of the following information:

(1)Calendar date.(2) The average hourly nitrogen oxides emission rates (expressed as NO2) (ng/J orlb/million Btu heat input) measured or predicted.(3) The 30-day average nitrogen oxides emission rates (lb/mmBtu heat input)calculated at the end of each steam generating unit operating day from themeasured or predicted hourly nitrogen oxide emission rates for the preceding 30steam generating unit operating days.(4) Identification of the steam generating unit operating days when the calculated30-day average nitrogen oxides emission rates are in excess of the nitrogen oxidesemissions standards under Section 60.44b, with the reasons for such excessemissions as well as a description of corrective actions taken.(5) Identification of the steam generating unit operating days for which pollutantdata have not been obtained, including reasons for not obtaining sufficient data anda description of corrective actions taken.

40 CFR Section 60.49b(g)



03700011 - 006

Facility Name:

Permit Number:

A-240

The owner or operator of an affected facility may submit electronic quarterly reportsfor NOx in lieu of submitting the written reports. The format of each quarterlyelectronic report shall be coordinated with the MPCA. The electronic report(s) shallbe submitted no later than 30 days after the end of the calendar quarter and shallbe accompanied by a certification statement from the owner or operator, indicatingwhether compliance with the applicable emission standards and minimum datarequirements of 40 CFR pt. 60, subp. Db was achieved during the reporting period.Before submitting reports in the electronic format, the owner or operator shallcoordinate with the MPCA to obtain their agreement to submit reports in thisalternative format.

40 CFR Section 60.49b(v)

The Permittee shall record and maintain records of the amounts of each fuelcombusted during each day and calculate the annual capacity factor individually foreach fuel combusted for the reporting period. The annual capacity factor isdetermined on a 12-month rolling average basis with a new annual capacity factorcalculated at the end of each calendar month.

40 CFR Section 60.49b(d)



03700011 - 006

Facility Name:

Permit Number:

A-241

Subject Item: EU 324 #3 Crude Unit Vacuum Heater

Associated Items: MR 152 NOx Monitor at 25H4


MR 154 O2 Monitor at 25H4

MR 155 Fuel Gas Flow Meter at 25H4

SV 176 25H4 Stack


Nitrogen Oxides: less than or equal to 32.1 tons/year using 365-day Rolling Sum Title I Condition: To avoid classification as a majormodification under 40 CFR Section 52.21 and Minn. R.7007.3000

Carbon Monoxide: less than or equal to 7.1 tons/year using 365-day Rolling Sum . Title I Condition: To avoid classification as a majormodification under 40 CFR Section 52.21 and Minn. R.7007.3000

Hydrogen Sulfide: less than or equal to 0.10 grains/dry standard cubic foot using3-hour Rolling Average (230 mg/dscm[162 ppm]). This limit applies to the H2Scontent of the fuel gas burned in the unit. Compliance determined with the H2Smonitor at the 45 unit refinery fuel gas mix drum (see GP 111).

40 CFR 60.104(a)(1); Minn. R. 7011.1410, subp. 2

Sulfur Dioxide: less than or equal to 1.75 lbs/million Btu heat input using 3-hourRolling Average . Compliance with the hydrogen sulfide limit constitutescompliance with this limit.

Minn. R. 7011.1410, subp. 3(A); Minn. R. 7011.1420,subp. 2(B)

Total Particulate Matter: less than or equal to 0.4 lbs/million Btu heat input using3-hour Rolling Average . The PTE for this heater is 0.00745 lbs/million Btu heatimput based on the AP-42 emission factor for natural gas. Compliance with the fuelrestriction constitutes compliance with this limit.

Minn. R. 7011.1410, subp. 3(B)(1)

Opacity: less than or equal to 20 percent using 6-minute Average exept for onesix-minute period per hour of not more than 60 percent opacity. Compliance withthe fuel restriction requirement constitutes compliance with this limit.

Minn. R. 7011.1410, subp. 3(B)(2)

Carbon Monoxide: less than or equal to 400 parts per million using 30-day RollingAverage , on a dry basis, corrected to 3 percent oxygen. This limit applies at alltimes except during periods of startup, shutdown, and malfunction, and when theprocess heater is operating at less than 50 percent of rated capacity.

40 CFR Sections 63.7500(a)(1), 63.7505 (a),63.7540(a)(10)(ii); 40 CFR Section 63.6(f)(1)



To determine compliance with the NOx limit based on a 365-day rolling sum, thePermittee shall calculate and record the rolling sum each calendar day. For thefirst 364 days of operation, the rolling sum shall be calculated each day based ontotal actual emissions since initial startup. For the first 364 days of operation, dailycompliance shall be demonstrated when the following formula is true:N < 4.74 + 0.075nWhere:N = total actual NOx emissions through day n (tpy)n = number of days since initial startup


To determine compliance with the CO limit based on a 365-day rolling sum, thePermittee shall calculate and record the rolling sum each calendar day. For thefirst 364 days of operation, the rolling sum shall be calculated each day based ontotal actual emissions since initial startup. For the first 364 days of operation, dailycompliance shall be demonstrated when the following formula is true:N < 1.048 + 0.0166nWhere:N = total actual CO emissions through day n (tpy)n = number of days since initial startup


Operate and maintain the process heater, including air pollution control andmonitoring equipment, according to the provisions in 40 CFR Section 63.6(e)(1)(i).


Develop a written startup, shutdown, and malfunction plan (SSMP) according to theprovisions in 40 CFR Section 63.6(e)(3).


C. NOTIFICATIONS hdr

Submit all of the notifications in 40 CFR Sections 63.7(b) and (c), 63.8(e), (f)(4) and(6), and 63.9(b) through (h) that apply by the dates specified.


D. CONTINUOUS EMISSION MONITORING SYSTEMS (CEMS) hdr



03700011 - 006

Facility Name:

Permit Number:

A-242

Install, operate, and maintain NOx, CO, and O2 CEMS in accordance with 40 CFRPart 60, Appendix B and Appendix F. See additional CEMS requirements underMR 152, 153, and 154.

Title I Condition: To avoid classification as a majormodification under 40 CFR Section 52.21 and Minn. R.7007.3000; Minn R. 7017.1006

CEM Certification Test: due 180 days after Startup of the process heater conductedaccording to the requirements in 40 CFR Section 63.8 and PerformanceSpecification 4A of 40 CFR Part 60, Appendix B.

40 CFR Sections 63.7510(g) and 63.7525(a)(2)

Install, operate, and maintain a continuous emission monitoring system (CEMS) forcarbon monoxide, according to the following procedures, upon startup of theprocess heater.1) The CEMS must be installed, operated, and maintained according to thePerformance Specification (PS) 4A of 40 CFR Part 60, Appendix B.2) Conduct a performance evaluation of the CEMS according to the requirements in40 CFR Section 63.8 and according to PS 4A of 40 CFR Part 60, Appendix B3) The CEMS must complete a minimum of one cycle of operation (sampling,analyzing, and data recording) for each successive 15-minute period.4) The CEMS data must be reduced as specified in 40 CFR Section 63.8(g)(2).

40 CFR Sections 63.7510(c), 63.7525(a), and63.7535(c)

5) Calculate and record a 30-day rolling average emission rate on a daily basis. Anew 30-day rolling average emission rate is calculated as the average of all thehourly CO emission data for the preceeding 30 operating days.6) Data recorded during periods of monitoring malfunctions, associated repairs,out-of-control periods, required quality assurance or control activities, or when theprocess heater is operating at less than 50 percent of its rated capacity must not beused for purposes of calculating data averages. Data collected during all otherperiods must be used in assessing compliance. Any period for which themonitoring system is out of control and data are not available for requiredcalculations constitutes a deviation from the monitoring requirements.

40 CFR Sections 63.7510(c) 63.7525(a), and63.7535(c)(continued)

Monitor carbon monoxide continuously (or collect data at all required intervals) atall times the process heater is operating except during monitor malfunctions,associated repairs, and required quality assurance or control activities (including,as applicable, calibration checks and required zero and span adjustments).

40 CFR Sections 63.7535(b) and 63.7540(a)(10)(i)

Consistent with 40 CFR Sections 63.6(e) and 63.7(e)(1), deviations of the carbonmonoxide limit (ppm) that occur during a period of startup, shutdown, ormalfunction are not violations if the Permittee demonstrates to the EPAAdministrator's satisfaction that they were operating in accordance with 40 CFRSection 63.6(e)(1). The EPA Administrator will determine whether deviations thatoccur during a period of startup, shutdown, or malfunction are violations, accordingto the provisions in 40 CFR Section 63.6(e).


E. REPORTING hdr

Submit semiannual compliance reports in accordance with 40 CFR Section63.7550(b). The compliance reports shall contain the following information.1) Company name and address.2) Statement by a responsible official with that official's name, title, and signature,certifying the truth, accuracy, and completeness of the contents of the report3) Date of report and beginning and ending dates of the reporting period.4) If you had a startup, shutdown, or malfunction during the reporting period andyou took actions consistent with your SSMP, the compliance report must includethe information in 40 CFR Section 63.10(d)(5)(i).

40 CFR Sections 63.7550(a), (b), and (c)

5) If there are not deviations from the carbon monoxide limit, a statement that therewere no deviations from the carbon monoxide limit during the reporting period.6) If there were no periods during which the CEMS was out of control as specifiedin 40 CFR Section 63.8(c)(7), a statement that there were no periods during whichthe CEMS was out of control during the reporting period.

40 CFR Sections 63.7550(a), (b), and (c)(continued)

Submit semiannual deviation reports for each deviation from the carbon monoxidelimit in accordance with 40 CFR Section 63.7550(f). This includes periods ofstartup, shutdown, and malfunction. In addition to the information required in thesemiannual compliance reports, the deviation reports shall contain the followinginformation.1) The date and time that each malfunction started and stopped and description ofthe nature of the deviation (i.e., what you deviated from).2) The date and time that each CEMS was inoperative, except for zero (low-level)and high-level checks.3) The date, time, and duration that each CEMS was out of control, including theinformation in 40 CFR Section 63.8(c)(8).

40 CFR Sections 63.7540(b), 63.7550(e) and (f)



03700011 - 006

Facility Name:

Permit Number:

A-243

4) The date and time that each deviation started and stopped, and whether eachdeviation occurred during a period of startup, shutdown, or malfunction or duringanother period.5) A summary of the total duration of the deviation during the reporting period andthe total duration as a percent of the total source operating time during thatreporting period.6) A breakdown of the total duration of the deviations during the reporting periodinto those that are due to startup, shutdown, control equipment problems, processproblems, other known causes, and other unknown causes.7) A summary of the total duration of CEMS downtime during the reporting periodand the total duration of CEMS downtime as a percent of the total source operatingtime during that reporting period.

40 CFR Sections 63.7540(b), 63.7550(e) and (f)(continued)

8) An identification of the parameter that was monitored at the process heater forwhich there was a deviation (i.e., carbon monoxide).9) A brief description of the source for which there was a deviation10) A brief description of each CEMS for which there was a deviation.11) The date of the latest CEMS certification or audit for the system for which therewas a deviation.12) A description of any changes in the CEMS, processes, or controls since the lastreporting period the source for which there was a deviation.

40 CFR Sections 63.7540(b), 63.7550(e) and (f)(continued)

F. RECORDKEEPING hdr

Daily Recordkeeping: The Permittee shall maintain daily records of all monitoringdata and calculations for nitrogen oxides, carbon monoxide, oxygen, and type andamount of each fuel combusted to show continuous compliance with the applicableemission limits.


Keep records in a form suitable and readily available for expeditious review,according to 40 CFR Section 63.10(b)(1). As Specifed in 40 CFR Section63.10(b)(1), keep each record for 5 years following the date of each occurrence,measurement, maintenance, corrective action, report, or record. Keep each recordon site for at least 2 years after the date of each occurrence, measurement,maintenance, corrective action, report, or record, according to 40 CFR Section63.10(b)(1). Records may be kept off site for the remaining 3 years.


Keep the following records.1) A copy of each notification and report that you submitted to comply with 40 CFRPart 63, Subpart DDDDD, including all documentation supporting any InitialNotification or Notification of Compliance Status or semiannual compliance reportthat you submitted, according to the requirements in 40 CFR Section63.10(b)(2)(xiv)2) The records in 40 CFR Section 63.6(e)(3)(iii) through (v) related to startup,shutdown, and malfunction.3) Records of performance tests, fuel analyses, or other compliancedemonstrations, peformance evaluations, and opacity observations as required in40 CFR Section 63.10(b)(2)(viii).


For each CEMS, keep the following records.1) Records described in 40 CFR Section 63.10(b)(2)(vi) through (xi)2) Previous (i.e., superseded) versions of the performance evaluation plan asrequired in 40 CFR Section 68.3(d)(3).3) Request alternatives to relative accuracy test for CEMS as required in 40 CFRSection 63.8(f)(6)(i).4) Records of the date and time that each deviation started and stopped, andwhether the deviation occurred during a period of startup, shutdown, or malfunctionor during another period.


Keep records of all monitoring data and calculated averages for carbon monoxideto show continuous compliance with the carbon monoxide limit.



Fuel Flowrate: The Permittee shall calibrate, operate, and maintain a continuousmonitoring system (CMS) that records the fuel flowrate at each fuel combustiondevice.

Minn. R. 7007.0800, subp. 4

CMS QA/QC: The Permittee shall follow manufacturer recommendations forpreventative maintenance and periodic monitoring to ensure CMS reliabilityincluding, but not limited to, annual calibrations of fuel gas flow meters.

Minn. R. 7007.0800, subp. 4



03700011 - 006

Facility Name:

Permit Number:

A-244

Subject Item: CE 002 Direct Flame Afterburner

Associated Items: EU 209 Track 8 Rail Loading


GP 106 Control Equipment Used to Meet Requirements of MACT CC

MR 001 Pilot indicator for ZTOF at rail loading

What to do Why to do itFuel Usage: less than or equal to 0.10 grains/dry standard cubic foot using 3-hourRolling Average . Limit does not apply during startup, shutdown, or malfunction.

40 CFR Section 60.104(a)(1); 40 CFR Section 60.8(c);Minn. R. 7011.1435, subp. A

Operating Parameter: shall operate the vapor processing system in a manner not toexceed the operating parameter value for the parameter or to go below theoperating parameter value for the parameter and established using the proceduresin 40 CFR Section 63.425(b). In cases where an alternative parameter is approved,each owner or operator shall operate the vapor processing system in a manner notto exceed or not to go below, as appropriate, the alternative operating parametervalue. Operation of the vapor processing system in a manner exceeding or goingbelow the operating parameter value shall constitute a violation of the emissionstandard in 40 CFR Section 63.422(b).

40 CFR Section 63.427(b); 40 CFR Section 63.6(f)(1);40 CFR Section 63.650(a)

Monitor: In place of the SO2 monitor, the Permittee shall follow the AlternativeMonitoring Plan as approved or modified.

40 CFR Section 60.105(a)(4); Minn. R. 7011.1435,subp. A

Submit Quarterly Air Quality and Excess Emissions Report: Cover letter,certification, and summary of exceedances shall be submitted in hardcopy format;all other information may be submitted electronically. Certify per 7007.0500, subp.3.

40 CFR Section 60.105(e)(3)(ii); 40 CFR Section60.107(f); 40 CFR Section 60.19(b)-(d); 40 CFRSection 60.4(a); Minn. R. 7007.0500, subp. 3; Minn. R.7011.1435, subp. A





03700011 - 006

Facility Name:

Permit Number:

A-245

Subject Item: CE 003 Activated Carbon Adsorption




MR 004 VOC Monitor at Bottom Loading Unit

What to do Why to do itConstruction/Design Requirement: each vapor collection system shall be designedto prevent any total organic compound vapors from passing to another loadingrack.


Compliance Requirement: loadings of liquid product into gasoline tank trucks shallbe limited to vapor tight gasoline tank trucks using the procedures in 40 CFRSection 60.502(e)(1)-(5).


Record keeping Requirement: the owner or operator shall obtain documentationthat states that the truck to be gasoline loaded is vapor tight.


Record keeping Requirement: the owner or operator shall require the tank IDnumber to be recorded as each gasoline tank truck is loaded at the affected facility.


Compliance Requirement: the owner or operator shall cross check each tank IDnumber obtained in paragraph (e)(2) with the file of tank vapor tightnessdocumentation within 2 weeks after the corresponding tank is loaded.


Reporting Requirement: the owner or operator shall notify the owner or operator ofeach non-vapor-tight gasoline tank truck within one (1) week after the loading hasoccurred.


Compliance Requirement: the owner or operator shall take steps assuring that thenon-vapor-tight gasoline tank truck will not be reloaded until vapor tightnessdocumentation for that tank is obtained.


Operation Requirement: the owner or operator shall act to assure that loadings ofgasoline tank trucks at the affected facility are made into tanks equipped with vaporcollection equipment that is compatible with the terminals vapor collection system.


Operation Requirement: the owner or operator shall act to assure that the terminalsand the tank trucks vapor collection systems are connected during each loading ofa gasoline tank truck at the affected facility.

40 CFR Section 60.502(g)

Design/Construction Requirement: the vapor collection and liquid loadingequipment shall be designed and operated to prevent gauge pressure in thedelivery tank from exceeding 450 mm of water during product loading.

40 CFR Section 60.502(h)

Design/Construction Requirement: no pressure-vacuum vent in the bulk gasolineterminals vapor collection system shall begin to open at a system pressure lessthan 450 mm of water.

40 CFR Section 60.502(i)

Performance Test Requirement: in conducting the performance tests required bythis subpart, the owner or operator shall use the test methods in Appendix A of thispart, except as provided in 40 CFR Section 60.8(b); the three-run requirement of 40CFR Section 60.8(f) does not apply to this subpart.


Compliance Requirement: Each owner or operator subject to the emission standardin 40 CFR Section 63.422(b) shall conduct a performance test on the vaporprocessing system according to the test methods and procedures of 40 CFRSection 60.503 except that a reading of 500 ppm shall be used to determine thelevel of leaks to be repaired under 40 CFR Section 60.503(b).


Recordkeeping Requirement: Record each startup, shutdown or malfunction of theair pollution control equipment.


Performance Test Requirement: For each performance test conducted under 40CFR Section 63.425(a), the owner or operator shall determine a monitoredoperating parameter value for the vapor processing system by continuouslyrecording the operating parameter during the performance test and determiningoperating parameter values based on the results of the test; a rationale forselecting the parameter values shall be provided to the Administrator.


Recordkeeping Requirement: For performance tests performed after the initial test,the owner or operator shall document the reasons for any change in the operatingparameter value since the previous performance test.


Operation Requirement: Operation of air pollution control system to achieveemission limit or operational parameter.


Recordkeeping Requirement: Records of the annual tests of gasoline cargo tanksto be conducted as specified in 40 CFR Section 63.425(e)-(h).




03700011 - 006

Facility Name:

Permit Number:

A-246

Recordkeeping Requirement: Records of continuous monitoring data required by40 CFR Section 63.427(a), or of the alternative parameter if approved under 40CFR Section 63.427(b) shall be kept in a readily accessible location.


Monitoring Requirement: Install, calibrate, certify, operate and maintain accordingto the manufacturer's specification a CEMS capable of measuring organiccompounds concentration.

40 CFR Section 63.427(a)(1)

Startup, Shutdown, and Malfunction Plan: The owner or operator shall develop andimplement a written startup, shutdown, and malfunction plan that describes, indetail, procedures for operating and maintaining the source during periods ofstartup, shutdown, and malfunction and a program of corrective action formalfunctioning process and air pollution control equipment used to comply with therelevant standard. As required under 40 CFR Section 63.8(c)(1)(i), the plan shallidentify all routine or otherwise predictable CMS malfunctions. The plan shall bedeveloped by the compliance date and shall meet the purposes specified in 40CFR Section 63.6(e)(3)(i)(A) through (C).

40 CFR Section 63.6(e)(3)(i)

Operation and maintenance of continuous monitoring systems: The owner oroperator shall ensure the immediate repair or replacement of CMS parts to correct"routine" or otherwise predictable CMS malfunctions as defined in the source'sstartup, shutdown, and malfunction plan required by 40 CFR Section 63.6(e)(3).The owner or operator shall keep the necessary parts for routine repairs of theaffected equipment readily available. If the plan is followed and the CMS is repairedimmediately, this action shall be reported in the semiannual startup, shutdown, andmalfunction report required under 40 CFR Section 63.10(d)(5)(i).

40 CFR Section 63.8(c)(1)(i)

Operation and maintenance of continuous monitoring systems: For thosemalfunctions or other events that affect the CMS and are not addressed by thestartup, shutdown, and malfunction plan, the owner or operator shall report actionsthat are not consistent with the startup, shutdown, and malfunction plan within 24hours after commencing such actions. The owner or operator shall send a follow-upreport within two (2) weeks after commencing actions inconsistent with the plan thateither certifies that corrections have been made or includes a corrective action planand schedule. The owner or operator shall provide proof that repair parts havebeen ordered or any other records that would indicate that the delay in makingrepairs is beyond his or her control.


Operation and maintenance of continuous monitoring systems: All CMS shall beinstalled such that representative measurements of emissions or processparameters from the affected source are obtained. In addition, CEMS shall belocated according to procedures contained in the applicable performancespecification(s).


Operation and maintenance of continuous monitoring systems: All CMS shall beinstalled, operational, and the data verified as specified in the relevant standardeither prior to or in conjunction with conducting performance tests under 40 CFRSection 63.7. Verification of operational status shall, at a minimum, includecompletion of the manufacturer's written specifications or recommendations forinstallation, operation, and calibration of the system.


Operation and maintenance of continuous monitoring systems: Except for systembreakdowns, out-of-control periods, repairs, maintenance periods, calibrationchecks, and zero (low-level) and high-level calibration drift adjustments, the CEMS,shall be in continuous operation and shall meet minimum frequency of operationrequirements by completing a minimum of one cycle of operation (sampling,analyzing, and data recording) for each successive 15-minute period.


Quality Control Program: The owner or operator shall develop a quality controlprogram meeting the requirements of 40 CFR Section 63.8(d)(2) and (3) within 60days of the effective date. The program shall follow the procedures of 40 CFR pt.60, Appendix F.

Minn. R. 7007.0800, subp. 2

General Recordkeeping Requirements: The owner or operator shall maintain filesof all information (including all reports and notifications) required by 40 CFR pt. 63recorded in a form suitable and readily available for expeditious inspection andreview including all information required by 40 CFR Section 63.10(b). The files shallbe kept for at least five (5) years following the date of each occurrence,measurement, maintenance, corrective action, report or record.






03700011 - 006

Facility Name:

Permit Number:

A-247


Associated Items: FS 128 88-Butane

MR 003 Pilot Thermocouple for Butane Storage Tank 086TK


What to do Why to do itOpacity: less than or equal to 0 percent opacity from flares except a total 5 minutesin any 2 consecutive hours; limit does not apply during startup, shutdown, ormalfunction.

40 CFR Section 60.11(c); 40 CFR Section 60.18(c)(1);40 CFR Section 60.18(c)(2)

Operation Limit: Flares must meet maximum velocity and minimum heat contentrequirements.

40 CFR Section 60.18(c)(2); 40 CFR Section60.18(c)(3)

All flares must be steam-assisted, air-assisted, or non-assisted. 40 CFR Section 60.18(c)(3)


40 CFR Section 60.18(c)(2); 40 CFR Section 60.18(e)

Submit Quarterly Air Quality and Excess Emissions Report. Cover lettercertification, and summary of exceedances shall be submitted in hardcopy format;all other information may be submitted electronically. Certify per Minn. R.7007.0500, subp. 3.

40 CFR Section 60.18(c)(1); 40 CFR Section60.18(c)(2); 40 CFR Section 60.4(a); 40 CFR Section(b)





03700011 - 006

Facility Name:

Permit Number:

A-248













EU 192 OSWTP - Aerobic Digester


EU 282 OSWTP - Thermal Oxidizer





MR 102 94H-1 Thermocouple for Fire Box Temperature




What to do Why to do itSubject to 40 CFR Section 61 subps. A and FF requirements. Compliance with 40CFR Section 61 subp. FF and 40 CFR Section 61, subp. A requirements as listedin this permit fully satisfies 40 CFR Section 60, subps. A and QQQ, 40 CFR Section63, subps. A and CC requirements.

40 CFR Section 60.11(d); 40 CFR Section60.690-60.699; 40 CFR Section 60.692-5(e)(4)-(5); 40CFR Section 60.697(f); 40 CFR Section 63.640(o)(1);Minn. R. 7011.1435, subp. C



03700011 - 006

Facility Name:

Permit Number:

A-249


Associated Items: EU 254 Unit 94H3-Thermal Oxidizer Back-up

EU 282 OSWTP - Thermal Oxidizer




MR 103 Temperature Monitor (Stack) for 94H-3 Thermal Oxidizer



What to do Why to do itSubject to 40 CFR Section 61 subps. A and FF requirements. Compliance with 40CFR Section 61 subp. FF and 40 CFR Section 61, subp. A requirements as listedin this permit fully satisfies 40 CFR Section 60, subps. A and QQQ, 40 CFR Section63, subps. A and CC requirements.

40 CFR Section 60.11(d); 40 CFR Section60.690-60.699; 40 CFR Section 60.692-5(e)(4)-(5); 40CFR Section 60.697(f); 40 CFR Section 63.640(o)(1);Minn. R. 7011.1435, subp. C



03700011 - 006

Facility Name:

Permit Number:

A-250

Subject Item: CE 050 Flaring



What to do Why to do itThe Permittee shall operate and maintain the enclosed flare during fuel loading anytime that the vapor recovery unit (CE003) is not being operated to controlemissions from the Bottom Loading Rack (EU004).

Minn. R. 7007.0800, subp. 2 and 14

When operating the enclosed flare to control emissions from the loading rack, thePermittee must either comply with all applicable testing and monitoringrequirements of 40 CFR Section 60, subp. J or submit an alternative monitoringplan to the United States Environmental Protection Agency (US EPA). If US EPAapproval of an alternative monitoring plan is received prior to initial startup of theenclosed flare, the Permittee shall follow the alternative monitoring plan todemonstrate compliance with the hydrogen sulfide emission limit established in 40CFR Section 60.104(a)(1) and Minn. R. 7011.1490, subp. 2. If US EPA approval ofan alternative monitoring plan is not received prior to initial startup of the enclosedflare, the Permittee must comply with all applicable monitoring and testingrequirements of 40 CFR Section 60, subp. J.

40 CFR Section 60.8(b)(4); 40 CFR Section 60.7(h)(2)

Enclosed Flare Minimum Temperature: For each performance test conductedunder 40 CFR Section 63.425(a) when operating the enclosed flare, the Permitteeshall determine a minimum temperature for the enclosed flare using the followingprocedure:

(1) During the performance test, continuously record the enclosed flare operatingtemperature;

(2) Determine a minimum enclosed flare operating temperature based on theparameter data monitored during the performance test, supplemented byengineering assessments and the manufacturer's recommendations; and

(3) Provide for the MPCA's approval the rationale for the selected minimumenclosed flare operating temperature, and monitoring frequency and averaging timeincluding data and calculations used to develop the value and a description of whythe minimum enclosed flare operating temperature, monitoring frequency, andaveraging time demonstrate continuous compliance with the emission standard in40 CFR Section 63.422(b).


Temperature: greater than or equal to 300 degrees F using an 1-hour BlockAverage. Downtime of 15 minutes or less is not to be included as operating time.During all gasoline loading procedures, the flame stack temperature indicator maynor operate at a lower temperature as listed, unless a performance test isconducted at a different temperature and the MPCA staff determines compliance atthat new temperature.

MInn. R. 7007.0800, subp. 2

Continuous Monitoring: For the enclosed flare (CE050), the Permittee shall install,calibrate, certify, operate, and maintain, according to the manufacturer'sspecifications, a continuous parameter monitoring system (CPMS) capable ofmeasuring temperature in the fire box or in the duct work immediately downstreamfrom the fire box in a position before any substantial heat exchange occurs.


CPMS Continuous Operation: Except for system breakdowns, repairs, andcalibration checks, the CPMS shall be in continuous operation whenever theenclosed flare is operating.


Enclosed Flare Operation: The Permittee shall operate the enclosed flare to ensurethat the enclosed flare operating temperature is greater than or equal to theminimum enclosed flare operating temperature established using the procedures in40 CFR Section 63.425(b). Operation of the enclosed flare at a temperature belowthe minimum enclosed flare operating temperature shall constitute a violation of theemission standard in 40 CFR Section 63.422(b).




03700011 - 006

Facility Name:

Permit Number:

A-251

Recordkeeping and Reporting:

(1) Keep an up-to-date, readily accessible record of the enclosed flare operatingtemperature. This record shall indicate the time intervals during which loadings ofgasoline cargo tanks have occurred or, alternatively, shall record the operatingparameter data only during such loadings. The date and time of day shall also beindicated at reasonable intervals on this record.

(2) Record and report, simultaneously with the notification of compliance statusrequired under 40 CFR Section 63.9(h), all data and calculations, engineeringassessments, and manufacturer's recommendations used in determining theoperating parameter value under 40 CFR Section 63.425(b).

Records shall be maintained for a period of at least 5 years.

40 CFR Section 63.428(c); 40 CFR Section 63.10(b)(1)

Quality Control Program: The Permittee shall develop and implement a qualitycontrol program for the continuous parameter monitoring system used to measurethe enclosed flare operating temperature. The quality control program shall meet allapplicable requirements of 40 CFR Section 63.8(d)(2) and (d)(3).

40 CFR Section 63.8(d)(2) and (d)(3)

Operation and Maintenance: The Permittee shall maintain and operate thecontinuous parameter monitoring system in a manner consistent with good airpollution control practices and shall meet all applicable requirements of 40 CFRSection 63.8(c).


Startup, Shutdown, and Malfunction Plan: Develop and implement a written startup,shutdown, and malfunction plan which complies with 40 CFR Section 63.6(e)(3).


Repair or Replacement Report: The Permittee shall ensure the immediate repair orreplacement of parts to correct routine or predictable malfunctions as defined in thesource's startup, shutdown, and malfunction plan. If the plan is followed and themonitor repaired immediately, this action shall be reported in the source'ssemiannual startup, shutdown, and malfunction report. Those malfunctions whichare not addressed in the plan shall be reported within 24 hours after commencingactions inconsistent with the plan.


The Permittee shall record all times during which the enclosed flare is operated.These records shall be retained for a period of 5 years.

Minn. R. 7007.0800, subp. 2 and 14



03700011 - 006

Facility Name:

Permit Number:

A-252

Subject Item: FS 001 Unburied Sewer Lines

Associated Items: GP 067 All equipment included in individual drain system, including drains and junction boxes subject to NESHAPs FF

GP 102 Units where carbon canisters may be used to meet NESHAP FF Requirements

GP 109 Closed Vent System for NESH FF Equipment

What to do Why to do itEach opening shall be maintained in a closed, sealed position (e.g., covered by alid that is gasketed and latched) at all times that waste is in the drain system exceptwhen it is necessary to use the opening for waste sampling or removal, or forequipment inspection, maintenance, or repair.



Each sewer line shall not be open to the atmosphere and shall be covered orenclosed in a manner so as to have no visual gaps or cracks in joints, seals, orother emission interfaces.

40 CFR Section 61.346(b)(3); 40 CFR Section63.654(a); Minn. R. 7011.9930, subp. E













Each drain using water seal controls shall be checked by visual or physicalinspection initially and thereafter quarterly for indications of low water levels orother conditions that would reduce the effectiveness of water seal controls.

(ii) Each drain using a tightly sealed cap or plug shall be visually inspected initiallyand thereafter quarterly to ensure caps or plugs are in place and properly installed.

(iii) Each junction box shall be visually inspected initially and thereafter quarterly toensure that the cover is in place and to ensure that the cover has a tight sealaround the edge.

(iv) The unburied portion of each sewer line shall be visually inspected initially andthereafter quarterly for indication of cracks, gaps, or other problems that couldresult in benzene emissions

40 CFR Section 61.346(a)(2); 40 CFR Section61.346(b)(4); 40 CFR Section 61.356(g); 40 CFRSection 61.357(d)(8); 40 CFR Section 63.654(a); Minn.R. 7011.9930, subp. E




Repair problems found during NESHAP visual emissions: when a broken seal orgasket or other problem is identified, or when detectable emissions are measured,first efforts at repair shall be made as soon as practicable, but not later than 15calendar days after identification..

40 CFR Section 61.346(a)(3); 40 CFR Section61.346(b)(5); 40 CFR Section 61.357(d)(8); 40 CFRSection 63.654(a); Minn. R. 7011.9930, subp. E



03700011 - 006

Facility Name:

Permit Number:

A-253

Records: Maintain a record for each visual inspection required that identifies aproblem (such as a broken seal, gap or other problem) which could result inbenzene emissions. The record shall include the date of the inspection, wastemanagement unit and control equipment location where the problem is identified, adescription of the problem, a description of the corrective action taken, and the datethe corrective action was completed.

40 CFR Section 61.356(g)-(h); 40 CFR CFR Section63.654(a); Minn. R. 7011.9930, subp. E

Records: Maintain a record for each test of no detectable emissions. The recordshall include the following information: date the test is performed, background levelmeasured during test, and maximum concentration indicated by the instrumentreading measured for each potential leak interface. If detectable emissions aremeasured at a leak interface, then the record shall also include the wastemanagement unit, control equipment, and leak interface location where detectableemissions were measured, a description of the problem, a description of thecorrective action taken, and the date the corrective action was completed.

CONTINUED40 CFR Section 61.356(g)-(h); 40 CFR CFR Section63.654(a); Minn. R. 7011.9930, subp. E



Inspect: Sewer lines shall not be open to the atmosphere and shall be covered orenclosed in a manner so as to have no visual gaps or cracks in joints, seals, orother emission interfaces.

The portion of each unburied sewer line shall be visually inspected initially andsemiannually thereafter for indication of cracks, gaps, or other problems that couldresult in VOC emissions.

40 CFR Section 60.692-2(c)(1)-(2); Minn. R.7011.1435, subp. C

Repairs: Whenever cracks, gaps, or other problems are detected, repairs shall bemade as soon as practicable, but not later than 15 calendar days afteridentification.

40 CFR Section 60.692-2(c)(3); Minn. R. 7011.1435,subp. C

Delay of Repairs: Delay of repair of facilities that are subject to the provisions ofthis subpart will be allowed if the repair is technically impossible without a completeor partial refinery or process unit shutdown.

40 CFR Section 60.692-6(a); Minn. R. 7011.1435,subp. C

Record information from sewer line inspections:shall be recorded for inspectionswhen a problem is identified that could result in VOC emissions.


Record: A copy of the design specifications for all equipment shall be kept for thelife of the source in a readily accessible location.





If an emission point cannot be repaired or corrected without a process unitshutdown, the expected date of a successful repair shall be recorded.




40 CFR Section 60.697(e)(1)-(4)



03700011 - 006

Facility Name:

Permit Number:

A-254

Subject Item: FS 009 Coke Pile

What to do Why to do itCoke Fugitive Dust Control Plan: The plan shall include a statement of objectives,identify the roads associated with transporting petroleum coke, describe primaryand contingent control measures and practices, describe the employee trainingprogram and identify the records to be kept to demonstrate plan implementation.The Commissioner may require additions or changes to the plan when grantingapproval. The Permittee will be given an opportunity to comment on any requiredaddition or change. The plan may be amended by the Permittee with theCommissioner's approval. If the Commissioner determines that the Permittee isout of complaince with Minn. R. 7011.0150, 40 CFR Section 52.21 and/or the cokefugitive dust control plan, then the Permittee may be required to amend the controlplan.

Title I Condition: To avoid classification as a majormodification under 40 CFR Section 52.21;Minn. R. 7011.0150

Comply with the Coke Fugitive Dust Control Plan: Prior to the MPCA approval ofthe Coke Fugitive Dust Control Plan (control plan), the Permittee shall follow theactions and recordkeeping in the control plan as proposed. Upon approval of thecontrol plan, the Permittee shall follow the actions and recordkeeping specified inthe control plan as approved.

Title I Condition: To avoid classification as a majormodification under 40 CFR Section 52.21;Minn. R. 7011.0150



03700011 - 006

Facility Name:

Permit Number:

A-255

Subject Item: FS 027 15-Coker Gasoline

Associated Items: GP 067 All equipment included in individual drain system, including drains and junction boxes subject to NESHAPs FF

GP 069 Type II Drains subject to NESH FF and also subject to NSPS QQQ

GP 076 Junction Boxes subject to NESH FF when equipped with carbon canisters

GP 082 Fugitive Compressors LDAR Requirements

GP 087 Fugitive LDAR All Equipment in VOC or HAP Service

GP 090 Fugitive LDAR Equipment Designated Non-detectable emissions (NDE)

GP 091 Fugitive LDAR Open-ended Lines

GP 095 Fugitive LDAR Pumps In Heavy Liquid Service

GP 096 Fugitive LDAR Light Liquid Pumps

GP 099 Fugitive LDAR Sample Stations

GP 100 Fugitive LDAR Heavy Liquid Valves

GP 101 Fugitive LDAR Valves in Light Liquid Service



What to do Why to do itEach valve that is in VHAP service subject to NESHAPs J/V shall be monitoredmonthly to detect leaks by Method 21. Leak detection and followup to leakdetection shall follow refinery consolidated LDAR program.

40 CFR pt. 70 (consolidated LDAR requirementsbased on various applicable provisions of 40 CFR pt.60, subps. A and GGG; 40 CFR pt. 61, subps. A, J andV; 40 CFR pt. 63, subps. A and CC; Clean FuelsPermit (106A-92-I/O-32)); 40 CFR 61.242-7



03700011 - 006

Facility Name:

Permit Number:

A-256

Subject Item: FS 045 23- Delayed Coker & Gasoline Plant

Associated Items: GP 058 Equipment subject to both NESH FF controls and NSPS QQQ

GP 067 All equipment included in individual drain system, including drains and junction boxes subject to NESHAPs FF

GP 068 Type I Drains receiving NESH FF Wastewater and equipped with plugs

GP 069 Type II Drains subject to NESH FF and also subject to NSPS QQQ

GP 071 Type I Drains subject to NSPS QQQ (sealed w/plug)

GP 075 Type II Drains subject to NSPS inactive (water seal)

GP 076 Junction Boxes subject to NESH FF when equipped with carbon canisters

GP 077 Junction Boxes receiving Wastewater from NSPS QQQ Units not subject to NESHAPs FF

GP 082 Fugitive Compressors LDAR Requirements

GP 087 Fugitive LDAR All Equipment in VOC or HAP Service

GP 090 Fugitive LDAR Equipment Designated Non-detectable emissions (NDE)

GP 091 Fugitive LDAR Open-ended Lines

GP 092 Fugitive LDAR Light Liquid or Heavy Liquid Pressure Relief Valves

GP 093 Fugitive LDAR PSV to Atmosphere

GP 094 Fugitive LDAR PSV with Upstream Rupture Disks

GP 095 Fugitive LDAR Pumps In Heavy Liquid Service

GP 096 Fugitive LDAR Light Liquid Pumps

GP 099 Fugitive LDAR Sample Stations

GP 100 Fugitive LDAR Heavy Liquid Valves

GP 101 Fugitive LDAR Valves in Light Liquid Service



What to do Why to do itReplace or correct remaining open-ended lines in the 23 coker identified in theJanuary 6, 2006, correspondence from FHR to MPCA to ensure compliance with40 CFR Section 60.482-6a by the end of the next turnaround involving replacementof the #3 coke drums, anticipated to occur in Fall 2012.




03700011 - 006

Facility Name:

Permit Number:

A-257

Subject Item: MR 027 23H-2 O2 Analyzer

Associated Items: CM 013 #3 Coker Heater: 0.12 lbs NOx/mmBtu (365-day ave.) EU 035

CM 014 #3 Coker Heater: 0.10 lbs CO/mmBtu (1-hr ave.) EU 035

EU 035 #3 Coker Heater

SV 033 23H2 Stack

What to do Why to do itInstallation Notification: due 60 days before installing the continuous emissionsmonitoring system. The notification shall include plans and drawings of the system.

Minn. R. 7017.1040, subp. 1

CEM Certification Test: due 90 days after Excess Emissions/Downtime Reports(EER's) are first required for the CEMS. The first EER is due 30 days after the endof the calendar quarter following permit issuance. Follow the PerformanceSpecifications listed in 40 CFR pt. 60, Appendix B.

Minn. R. 7017.1050, subp. 1

CEMS Certification Test Plan: due 30 days before CEMS Certification TestCEMS Certification Test Pretest Meeting: due 7 days before CEMS CertificationTestCEMS Certification Test Report: due 45 days after CEMS Certification TestCEMS Certification Test Report - Microfiche Copy: due 105 days after CEMSCertification TestThe Notification, Test Plan, and Test Report may be submitted in alternate formatas allowed by Minn. R. 7017.1120, subp. 2

Minn. R. 7017.1060, subp. 1-3; and Minn. R.7017.1080, subp. 1-4


Minn. R. 7017.1090

Monitoring Data: All data points collected by a CEMS shall be used to calculateindividual hourly emission averages unless another applicable requirement requiresmore frequent averaging. In order for an hour of data to be considered, it mustcontain the following minimum number of data points:A. four data points, equally spaced, if the emission unit operated during the entirehour;B. two data points, at least 15 minutes apart, during periods of monitor calibrationor routine maintenance;C. one data point if the emission unit operated for 15 minutes or less during thehour.

Minn. R. 7017.1160, subp. 1 and 2

QA Plan: Develop and implement a written quality assurance plan that covers eachCEMS. The plan shall be on site and available for inspection within 30 days aftermonitor certification. The plan shall contain all of the information required by 40CFR Part 60, Appendix F, section 3. The plan shall include the manufacturer'sspare parts list for each CEMS and require that those parts be kept at the facilityunless the Commissioner gives written approval to exclude specific spare partsfrom the list.

Minn. R. 7017.1170, subp. 2

Requirement: CEMS Daily Calibration Drift (CD) Test: The CD shall be quantifiedand recorded at zero (low-level) and upscale (high-level) gas concentrations atleast once daily according to the procedures listed in Minn. R. 7017.1170, subp. 3and 40 CFR Section 60.13(d)(1) for each pollutant concentration, each diluentmonitor, and for each monitor range. The CEMS shall be adjusted whenever theCD exceeds twice the specification of 40 CFR pt. 60, Appendix B. If no span valueis specified in the applicable requirement or in a compliance document, thePermittee shall use a span value equivalent to 1.5 times the emission limit. 40 CFRpt. 60, Appendix F, shall be used to determine out-of-control periods for CEMS.Follow the procedures in 40 CFR pt. 60, Appendix F.

Minn. R. 7017.1170, subp. 3

Cylinder Gas Audit: due before end of each calendar half-year following CEMCertification Test, except that a CGA is not required during any calendar half yearin which a RATA was performed. <The initial CGA must be performed within 80days following certification of the CEMS>. The CGAs shall be conducted at leastthree months apart but no more than eight months apart. A CGA shall beconducted according to the procedures in 40 CFR pt. 60, Appendix F, section 5.1.2.If the monitored emission unit was operated for less than 24 hours during thecalendar half year, a CGA is not required for that calendar half year.

Minn. R. 7017.1170, subp. 4



03700011 - 006

Facility Name:

Permit Number:

A-258

CEMS Relative Accuracy Test Audit (RATA): due before end of each calendar yearfollowing CEM Certification Test. A RATA is not required in any calendar year if aRATA conducted in the previous year demonstrated a relative accuracy value ofless than 15 percent or if the associated emissions unit operated less than 48hours during the calendar year. If the exception is used, the next RATA shall beconducted during the first half of the following calendar year. RATAs shall beconducted at least 3 months apart according to 40 CFR pt. 60, Appendix F, section5.1.1.

Minn. R. 7017.1170, subp. 5


Minn. R. 7017.1130



03700011 - 006

Facility Name:

Permit Number:

A-259

Subject Item: MR 152 NOx Monitor at 25H4

Associated Items: EU 324 #3 Crude Unit Vacuum Heater

SV 176 25H4 Stack


Minn. R. 7017.1040, subp. 1

CEM Certification Test: due 180 days after Initial Startup of the Monitor but no morethan 90 days after the due date of the first excess emissions report required for theCEMS. Follow the Performance Specifications listed in 40 CFR pt. 60, Appendix B.

Minn. R. 7017.1050, subp. 1

CEMS Certification Test Plan: due 30 days before CEMS Certification Test. Minn. R. 7017.1060, subp.1 & 2

CEMS Certification Test Pretest Meeting: due 7 days before CEMS CertificationTest.

Minn. R. 7017.1060, subp. 3

CEMS Certification Test Report - Microfiche Copy: due 105 days after CEMSCertification Test.

Minn. R. 7017.1080, subp. 3


Minn. R. 7017.1170, subp. 3

Cylinder Gas Audit: due before end of each calendar half-year following CEMCertification Test. Conduct CGA at least 3 months apart and not greater than 8months apart. Follow the procedures in 40 CFR pt. 60, Appendix F.

Minn. R. 7017.1170, subp. 4

CEMS Relative Accuracy Test Audit (RATA): due before end of each year followingCEM Certification Test. If the relative accuracy is 15% or less the next CEMSRATA is not due for 24 months. Follow the procedures in 40 CFR pt. 60, AppendixB and Appendix F.

Minn. R. 7017.1170, subp. 5

Relative Accuracy Test Audit (RATA) Notification: due 30 days before CEMSRelative Accuracy Test Audit (RATA).

Minn. R. 7017.1180, subp. 2



Minn. R. 7017.1090, subp. 1


Minn. R. 7007.1130

QA Plan: Develop and implement a written quality assurance plan that covers eachCEMS. The plan shall be on site and available for inspection within 30 days aftermonitor certification. The plan shall contain all of the information required by40CFR 60, App. F, section 3. The CEMS manufacturer's recommended spareparts shall be kept at the facility unless the Commissioner approves exclusions.

Minn. R. 7017.1170, subp. 2



03700011 - 006

Facility Name:

Permit Number:

A-260

Subject Item: MR 153 CO Monitor at 25H4


SV 176 25H4 Stack


Minn. R. 7017.1040, subp. 1

CEM Certification Test: due 180 days after Initial Startup of the Monitor but no laterthan 90 days after the due date of the first excess emissions report required for theCEMS. Follow the Performance Specifications listed in 40 CFR pt. 60, Appendix B.

Minn. R. 7017.1050, subp. 1



Minn. R. 7017.1060, subp. 3


Minn. R. 7017.1080, subp. 3


Minn. R. 7017.1170, subp. 3


Minn. R. 7017.1170, subp. 4


Minn. R. 7017.1170, subp. 5


Minn. R. 7017.1180, subp. 2



Minn. R. 7017.1090, subp. 1


Minn. R. 7007.1130


Minn. R. 7017.1170, subp. 2



03700011 - 006

Facility Name:

Permit Number:

A-261

Subject Item: MR 154 O2 Monitor at 25H4


SV 176 25H4 Stack


Minn. R. 7017.1040, subp. 1


Minn. R. 7017.1050, subp. 1



Minn. R. 7017.1060, subp. 3


Minn. R. 7017.1080, subp. 3


Minn. R. 7017.1170, subp. 3


Minn. R. 7017.1170, subp. 4


Minn. R. 7017.1170, subp. 5


Minn. R. 7017.1180, subp. 2



Minn. R. 7017.1090, subp. 1


Minn. R. 7007.1130


Minn. R. 7017.1170, subp. 2



03700011 - 006

Facility Name:

Permit Number:

A-262

Subject Item: MR 156 41 Unit Fuel Gas Mix Drum Total Sulfur

Associated Items: EU 063 Fuel Gas Supply System (47 unit) BACKUP: Monitoring Point for FG H2S

GP 116 Refinery Fuel Gas SO2 and PM10 Emissions


Minn. R. 7017.1040, subp. 1


Minn. R. 7017.1050, subp. 1



Minn. R. 7017.1060, subp. 3


Minn. R. 7017.1080, subp. 3

CEMS Daily Calibration Drift (CD) Test: The CD shall be quantified and recorded atzero (low-level) and upscale (high-level) gas concentrations at least once daily.The CEMS shall be adjusted whenever the CD exceeds twice the specification of40 CFR pt. 60, Appendix B. 40 CFR pt. 60, Appendix F, shall be used to determineout-of-control periods for CEMS. Follow the procedures in 40 CFR pt. 60, AppendixF, using certified reference materials since EPA Protocol 1 gases do not exist.

Minn. R. 7017.1170, subp. 3


Minn. R. 7017.1170, subp. 4


Minn. R. 7017.1170, subp. 5


Minn. R. 7017.1180, subp. 2



Minn. R. 7017.1090, subp. 1


Minn. R. 7007.1130


Minn. R. 7017.1170, subp. 2



03700011 - 006

Facility Name:

Permit Number:

A-263

Subject Item: MR 161 47/45 Mix Drum Fuel Gas Combustion SO2 Monitor at 25H3

Associated Items: GP 116 Refinery Fuel Gas SO2 and PM10 Emissions


Minn. R. 7017.1040, subp. 1


Minn. R. 7017.1050, subp. 1



Minn. R. 7017.1060, subp. 3


Minn. R. 7017.1080, subp. 3


Minn. R. 7017.1170, subp. 3


Minn. R. 7017.1170, subp. 4


Minn. R. 7017.1170, subp. 5


Minn. R. 7017.1180, subp. 2



Minn. R. 7017.1090, subp. 1


Minn. R. 7007.1130


Minn. R. 7017.1170, subp. 2



03700011 - 006

Facility Name:

Permit Number:

A-264

Subject Item: MR 162 47/45 Mix Drum Fuel Gas SO2 Monitor at 29H1/2



Minn. R. 7017.1040, subp. 1


Minn. R. 7017.1050, subp. 1



Minn. R. 7017.1060, subp. 3


Minn. R. 7017.1080, subp. 3


Minn. R. 7017.1170, subp. 3


Minn. R. 7017.1170, subp. 4


Minn. R. 7017.1170, subp. 5


Minn. R. 7017.1180, subp. 2



Minn. R. 7017.1090, subp. 1


Minn. R. 7007.1130


Minn. R. 7017.1170, subp. 2



03700011 - 006

Facility Name:

Permit Number:

A-265

Subject Item: MR 165 47/45 Mix Drum Fuel Gas Combustion O2 Monitor at 25H3

Associated Items: EU 041 #3 Crude Unit Vac Pre-Fractionator Heater

GP 116 Refinery Fuel Gas SO2 and PM10 Emissions

SV 038 25H3 Stack


Minn. R. 7017.1040, subp. 1


Minn. R. 7017.1050, subp. 1



Minn. R. 7017.1060, subp. 3


Minn. R. 7017.1080, subp. 3


Minn. R. 7017.1170, subp. 3


Minn. R. 7017.1170, subp. 4


Minn. R. 7017.1170, subp. 5


Minn. R. 7017.1180, subp. 2



Minn. R. 7017.1090, subp. 1


Minn. R. 7007.1130


Minn. R. 7017.1170, subp. 2



03700011 - 006

Facility Name:

Permit Number:

A-266

Subject Item: MR 166 47/45 Mix Drum Fuel Gas Combustion O2 Monitor at 29H1/2



Minn. R. 7017.1040, subp. 1


Minn. R. 7017.1050, subp. 1



Minn. R. 7017.1060, subp. 3


Minn. R. 7017.1080, subp. 3


Minn. R. 7017.1170, subp. 3


Minn. R. 7017.1170, subp. 4


Minn. R. 7017.1170, subp. 5


Minn. R. 7017.1180, subp. 2



Minn. R. 7017.1090, subp. 1


Minn. R. 7007.1130


Minn. R. 7017.1170, subp. 2



03700011 - 006

Facility Name:

Permit Number:

A-267

Subject Item: MR 167 27H-101 CO Monitor

Associated Items: EU 050 Distillate HDS Recycle Hydrogen Charge Heater


Minn. R. 7017.1040, subp. 1


Minn. R. 7017.1050, subp. 1



Minn. R. 7017.1060, subp. 3


Minn. R. 7017.1080, subp. 3


Minn. R. 7017.1170, subp. 3


Minn. R. 7017.1170, subp. 4


Minn. R. 7017.1170, subp. 5


Minn. R. 7017.1180, subp. 2



Minn. R. 7017.1090, subp. 1


Minn. R. 7007.1130


Minn. R. 7017.1170, subp. 2



03700011 - 006

Facility Name:

Permit Number:

A-268

Subject Item: MR 168 27H-101 NOx Monitor



Minn. R. 7017.1040, subp. 1


Minn. R. 7017.1050, subp. 1



Minn. R. 7017.1060, subp. 3


Minn. R. 7017.1080, subp. 3


Minn. R. 7017.1170, subp. 3


Minn. R. 7017.1170, subp. 4


Minn. R. 7017.1170, subp. 5


Minn. R. 7017.1180, subp. 2



Minn. R. 7017.1090, subp. 1


Minn. R. 7007.1130


Minn. R. 7017.1170, subp. 2



03700011 - 006

Facility Name:

Permit Number:

A-269

Subject Item: MR 170 71B6 NOx Monitor


What to do Why to do itEmissions Monitoring: The Permittee shall use a nitrogen oxides (NOx) CEMS tomeasure NOx emissions from EU 126. Specifications for the operation of themonitoring equipment are in 40 CFR Section 60.48b(c), (d), (e), (f), and AppendixB.


Installation of CEMS: The Permittee shall install and operate a NOx CEMS. Theinstallation and operation of the CEMs will met the performance requirements asspecified in 40 CFR Section 60.46b.

Minn. R. 7017.1006

Install Notification: due 60 days before installation of the continuous emissionmonitoring system. The notification shall include plans and drawings of the system.

Minn. R. 7017.1040, subp. 1

CEM Certification Test: due 60 days after achieving maximum capacity but no laterthan 180 days after initial startup of operation of the unit.






Minn. R. 7017.1170, subp. 3


Minn. R. 7017.1170, subp. 4


Minn. R. 7017.1170, subp. 5


Minn. R. 7017.1180, subp. 2



Minn. R. 7017.1090, subp. 1


Minn. R. 7007.1130


Minn. R. 7017.1170, subp. 2



03700011 - 006

Facility Name:

Permit Number:

A-270

Subject Item: MR 171 71B6 CO Monitor


What to do Why to do itCO Emissions Measuring: The Permittee shall use a CO CEMS to measure COemissions from EU 126.


Minn. R. 7017.1006

The Permittee shall install, operate and maintain a continuous emission monitoringsystem (CEMS) for CO according to the following procedures:







(6) For purposes of calculating data averages, the Permittee must use the datarecorded during periods of monitoring malfunctions, associated repairs,out-of-control periods, required quality assurance or control activities, or when yourprocess heater is operating at less than 50 percent of its rated capacity. ThePermittee must use all the data collected during all other periods in assessingcompliance. Any period for which the monitoring system is out-of-control and dataare not availabe for required calculations constitutes a deviation from themonitoring requirements.




Install Notification: due 60 days before installation of the continuous emissionmonitoring system. The notification shall include plans and drawings of the system.

Minn. R. 7017.1040, subp. 1

CEM Certification Test: due 60 days after achieving maximum capacity but not laterthat 180 days after initial startup. Follow the procedures in 40 CFR pt. 60,Appendix B.













03700011 - 006

Facility Name:

Permit Number:

A-271




Minn. R. 7017.1170, subp. 3


Minn. R. 7017.1170, subp. 4


Minn. R. 7017.1170, subp. 5


Minn. R. 7017.1180, subp. 2

Continuous Operation: CEMS must be operated and data recorded during allperiods of EU126 operation including periods of emission unit start-up, shutdown,or malfunction except for periods of acceptable monitor downtime. Thisrequirement applies whether or not a numerical emission limit applies during theseperiods. A CEMS must not be bypassed except in emergencies where failure tobypass would endanger human health, safety, or plant equipment.


Minn. R. 7017.1090, subp. 1


Minn. R. 7007.1130


Minn. R. 7017.1170, subp. 2

Acceptable monitor downtime is a violation of 7017.1091, subp. 1, except forreasonable periods of monitor downtime due to the following causes:





03700011 - 006

Facility Name:

Permit Number:

A-272

Subject Item: MR 179 29H-1/2 NOx Monitor




What to do Why to do itContinuous Operation: CEMS must be operated and data recorded during allperiods of emission unit operation including periods of emission unit start-up,shutdown, or malfunction except for periods of acceptable monitor downtime. Thisrequirement applies whether or not a numerical emission limit applies during theseperiods. A CEMS must not be bypassed except in emergencies where failure tobypass would endanger human health, safety, or plant equipment.

Minn. R. 7017.1090


Minn. R. 7017.1160, subp. 1 and 2


Minn. R. 7017.1170, subp. 2


Minn. R. 7017.1170, subp. 3


Minn. R. 7017.1170, subp. 4


Minn. R. 7017.1170, subp. 5


Minn. R. 7017.1130



03700011 - 006

Facility Name:

Permit Number:

A-273

Subject Item: MR 180 29H-1/2 CO Monitor




What to do Why to do itContinuous Operation: CEMS must be operated and data recorded during allperiods of emission unit operation including periods of emission unit start-up,shutdown, or malfunction except for periods of acceptable monitor downtime. Thisrequirement applies whether or not a numerical emission limit applies during theseperiods. A CEMS must not be bypassed except in emergencies where failure tobypass would endanger human health, safety, or plant equipment.

Minn. R. 7017.1090


Minn. R. 7017.1160, subp. 1 and 2


Minn. R. 7017.1170, subp. 2


Minn. R. 7017.1170, subp. 3


Minn. R. 7017.1170, subp. 4


Minn. R. 7017.1170, subp. 5


Minn. R. 7017.1130



03700011 - 006

Facility Name:

Permit Number:

A-274

Subject Item: MR 181 29H-1/2 O2 Monitor





Minn. R. 7017.1040, subp. 1


Minn. R. 7017.1050, subp. 1




Minn. R. 7017.1090


Minn. R. 7017.1160, subp. 1 and 2


Minn. R. 7017.1170, subp. 2


Minn. R. 7017.1170, subp. 3


Minn. R. 7017.1170, subp. 4



03700011 - 006

Facility Name:

Permit Number:

A-275


Minn. R. 7017.1170, subp. 5


Minn. R. 7017.1180, subp. 2

Excess Emissions/Downtime Reports (EERs): due 30 days after end of eachcalendar quarter following Permit Issuance. Submit Deviations Reporting FormDRF-1 as amended. The EER shall indicate all periods of monitor bypass and allperiods of exceedances of the limit including exceedances allowed by an applicablestandard, i.e. during startup, shutdown, and malfunctions. The EER must besubmitted even if there were no excess emissions, downtime or bypasses duringthe quarter.

Minn. R. 7017.1110, subp. 1 and 2


Minn. R. 7017.1130



03700011 - 006

Facility Name:

Permit Number:

A-276

Subject Item: MR 182 27H-101 O2 Monitor


SV 044 27H101 Stack


Minn. R. 7017.1040, subp. 1


Minn. R. 7017.1050, subp. 1




Minn. R. 7017.1090


Minn. R. 7017,1160, subp. 1 and 2


Minn. R. 7017.1170, subp. 2


Minn. R. 7017.1170, subp. 3


Minn. R. 7017.1170, subp. 4


Minn. R. 7017.1170, subp. 5



03700011 - 006

Facility Name:

Permit Number:

A-277


Minn. R. 7017.1180. subp. 2

Excess Emissions/Downtime Reports (EERs): due 30 days after end of eachcalendar quarter following Permit Issuance. Submit Deviations Reporting FormDRF-1 as amended. The EER shall indicate all periods of monitor bypass and allperiods of exceedances of the limit including exceedances allowed by an applicablestandard, i.e. during startup, shutdown, and malfunctions. The EER must besubmitted even if there were no excess emissions, downtime or bypasses duringthe quarter.

Minn. R. 7017.1110, subp. 1 and 2


Minn. R. 7017.1130

TABLE B: SUBMITTALSFacility Name: Flint Hills Resources LP - Pine Bend

Permit Number: 03700011 - 006

01/21/09B-1

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.

Send any application for a permit or permit amendment to:

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

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

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 by the Acid Rain Program to:

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

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

TABLE B: ONE TIME SUBMITTALS OR NOTIFICATIONSFacility Name: Flint Hills Resources LP - Pine Bend


01/21/09B-2

What to send When to send Portion of Facility AffectedAnnual Report due 30 days after 12/31/2005. The annual

report applies to all annual reports: dueJanuary 30th of each year.

Total Facility

Application for Permit Reissuance due 180 days before expiration of ExistingPermit

Total Facility

CEM Certification Test Notification due 30 days before CEM Certification Test EU282, EU294, EU295, EU296, EU313

CEM Certification Test Plan due 30 days before CEM Certification Test EU040, EU041, EU282, EU294, EU295,EU296, EU313, MR170, MR171, SV083

CEM Certification Test Report - MicroficheCopy

due 105 days after CEM Certification Test EU040, EU041, EU282, EU294, EU295,EU296, EU313, SV083


due 105 days after CEM Certification Test Acompact disk (CD) is an approved alternativeformat.

MR170


due 105 days after CEM Certification Test. Acompact disk (CD) is an approved alternativeformat.

MR171

CEM Certification Test Report due 45 days after CEM Certification Test EU040, EU041, EU282, EU294, EU295,EU296, EU313, MR152, MR153, MR154,MR156, MR161, MR162, MR165, MR166,MR167, MR168, MR170, MR171, SV083

Computer Dispersion Modeling Protocol due 1096 days after 10/31/2005 for PM10.This protocol will describe the proposedmodeling methodology and input data, inaccordance with MPCA modeling guidance forTitle V air dispersion modeling analyses. Theprotocol will be based on projected operatingconditions under the next permit term. This isa state-only requirement and is notenforceable by the EPA Administrator orcitizens under the Clean Air Act.

Total Facility

Computer Dispersion Modeling Results due 1462 days after 10/31/2005 for PM10.To be submitted after the MPCA has reviewedand approved the modeling protocol.

Total Facility

Initial Compliance Status Report due 180 days after Startup of the heater. EU126, EU294, EU295, EU313

Initial Compliance Status Report due 30 days after 04/11/2005 EU228, SV042, SV093

Monitoring Plan due 180 days after 04/30/2005 submit anamendment to its current "AlternativeMonitoring Plan" consistent with 40 CFRSection 60.13(i) for monitoring fuel gas H2Scontent in accordance with U. S. EPAguidance. Proceed in accordance withexisting U. S. EPA guidance until theAlternative Monitoring is approved by U. S.EPA.

EU282

Monitoring Plan due 180 days after Initial Startup or within 60days after achieving the maximum productionrate at which EU 296 will be operated, submita request for an NSPS subpart J fuel gascombustion device "Alternative MonitoringPlan" for monitoring fuel gas H2S content inaccordance with EPA guidance. Proceed inaccordance with existing EPA guidance untilthe Alternative Monitoring is approved byEPA.

EU296

Notification of compliance status due 60 days after Initial Compliance StatusReport (CEMS Performance Evaluation) forCO according the 40 CFR Section 63.7525(a)and 40 CFR Section 63.7510(c).

EU126, EU294, EU295, EU313

Notification of compliance status due 60 days after Initial Performance Test forCO.

EU296

Notification of compliance status due before 04/11/2005 EU228, SV042, SV093

Notification of the Actual Date of Initial Startup due 15 days after Initial Startup EU126, EU294, EU295, EU296, EU313,EU324

TABLE B: ONE TIME SUBMITTALS OR NOTIFICATIONSFacility Name: Flint Hills Resources LP - Pine Bend


01/21/09B-3

Notification of the Anticipated Date of InitialStartup

due 30 days before Anticipated Date of InitialStartup and no more than 60 days beforesuch date.(2) A notification of the actual date of initialstartup of the source within 15 days after thatdate. This citation is for FS135.

Total Facility

Notification of the Date Construction Began due 30 days after Notification of the DateConstruction Began. Submit the name andnumber of the unit and the date constructionbegan.

EU324

Notification of the Date Construction Began due 30 days after Start Of Construction EU126, EU313

Notification of the Date Construction Began due 30 days after Start Of Construction foraffected facilities (under NSPS QQQ & GGGa,and NESHAPS J/V). This citation is forFS135.

Total Facility

Notification due 15 days after Notify of permanentlyshutdown Boilers No. 1, 2, 3 and 4.

GP001

Notification due 60 days after Equipment Installation(continuous emissions monitoring system)

EU296

Notification due 60 days after Equipment Installation(continuous emissions monitoring system).The notification shall include plans anddrawings of the system.

EU313

Notification due 60 days after Equipment Installation(continuous emissions monitoring system.)

EU296

Notification due 60 days after Equipment InstallationCEMs. The notification shall include plansand drawings of the system.

EU313

Notification due 60 days before Equipment Installation(CEMS). The notification shall include plansand drawings of the system.

EU294, EU295

Performance Test Notification (written) due 30 days before Performance Test EU006, EU051, EU102, EU103, EU104,EU241, SV066, SV082

Performance Test Plan due 30 days before Performance Test EU006, EU051, EU102, EU103, EU104,EU241, SV066, SV082

Performance Test Report - Microfiche Copy due 105 days after Performance Test. ACD-ROM copy of the test report shall beaccepted as an alternative to the microfichecopy, provided that the test report on theCD-ROM is in PDF or TIF format to ensurecompatability.

EU006, EU051, EU102, EU103, EU104,EU241, SV066, SV082

Performance Test Report due 45 days after Performance Test EU006, EU051, EU102, EU103, EU104,EU241, SV066, SV082

Relative Accuracy Test Audit (RATA)Notification

due 30 days before CEMS Relative AccuracyTest Audit (RATA)

EU019, EU040, EU041, EU212, EU213,EU228, EU245, EU282, EU294, EU295,EU296, EU313, GP111, GP112, MR027,MR179, MR180, SV042, SV083, SV093

Testing Frequency Plan due 60 days after Initial Performance Test forCO emissions. The plan shall specify atesting frequency based on the test data andMPCA guidance. Future performance testsbased on one-year (12 month), 36 month, and60 month intervals, or as applicable, shall berequired upon written approval of the MPCA.

EU051, SV066

Testing Frequency Plan due 60 days after Initial Performance Test forNOx emissions. The plan shall specify atesting frequency based on the test data andMPCA guidance. Future performance testsbased on one-year (12 month), 36 month, and60 month intervals, or as applicable, shall berequired upon written approval of the MPCA.

EU006, SV082

Testing Frequency Plan due 60 days after Performance Test for NOxemissions. The plan shall specify a testingfrequency based on the test data and MPCAguidance. Future performance tests based onone-year (12 month), 36 month, and 60 monthintervals, or as applicable, shall be requiredupon written approval of the MPCA.

EU102, EU103

TABLE B: RECURRENT SUBMITTALSFacility Name: Flint Hills Resources LP - Pine Bend


01/21/09B-4

What to send When to send Portion of Facility AffectedCylinder Gas Audit (CGA) Results Summary due 30 days after end of each calendar

quarter following Cylinder Gas AuditMR027, MR179, MR180

Cylinder Gas Audit (CGA) Results Summary due 30 days after end of each calendarquarter following end of the calendar quarterin which the Audit was performed

EU019, EU212, EU213, EU228, EU245,EU282, EU294, EU295, GP111, GP112,MR152, MR153, MR154, MR156, MR161,MR162, MR165, MR166, MR167, MR168,MR170, MR171, MR181, MR182, SV042,SV093

Excess Emissions/Downtime Reports (EER's) due 30 days after end of each calendarquarter following CEM Certification Test(Submit Deviations Reporting Form DRF-1 asamended). The EER shall indicate all periodsof monitor bypass and all periods ofexceedances of the limit includingexceedances allowed by an applicablestandard, i.e. during startup, shutdown, andmalfunctions.

MR152, MR153, MR154, MR156, MR161,MR162, MR165, MR166, MR167, MR168,MR170, MR171

Excess Emissions/Downtime Reports (EER's) due 30 days after end of each calendarquarter following CEM Certification Test forCO emissions. (Submit Deviations ReportingForm DRI-1 as amended) or form as approvedby MPCA. The downtime portion of the EERshall include a report on all periods that theCEMS was out-of-control. The EER shallindicated all periods of monitor bypass and allperiods of exceedances of the limit inlcudingexceedances allowed by an applicablestandard, i.e. during startup, shutdown andmalfunctions.

EU296

Excess Emissions/Downtime Reports (EER's) due 30 days after end of each calendarquarter following CEM Certification Test forCO emissions. (Submit Deviations ReportingForm DRI-1 as amended) or other form asapproved by the MPCA. The downtimeportion of the EER shall include a report on allperiods that the CEMS was out-of-control.The EER shall indicated all periods of monitorbypass and all periods of exceedances of thelimit including exceedances allowed by anapplicable standard, i.e. during startup,shutdown and malfunctions.

EU294, EU295

Excess Emissions/Downtime Reports (EER's) due 30 days after end of each calendarquarter following CEM Certification Test forNOx and CO emissions. (Submit DeviationsReporting Form DRF-1 as amended) or formas approved by the MPCA. The EER shallindicate all periods of monitor bypass and allperiods of exceedances of the limit includingexceedances allowed by an applicablestandard, i.e. during startup, shutdown, andmalfunctions.

EU313

Excess Emissions/Downtime Reports (EER's) due 30 days after end of each calendarquarter following COMS Certification Test(Submit Deviations Reporting Form DRF-1 asamended) or other form as approved byMPCA. The EER shall indicate all periods ofmonitor bypass and all periods ofexceedances of the limit includingexceedances allowed by an applicablestandard, i.e. during startup, shutdown, andmalfunctions.

EU228

Excess Emissions/Downtime Reports (EER's) due 30 days after end of each calendarquarter following Excess Emissions/DowntimeReports (EER's). Cover letter, certification,and summary of exceedances shall besubmitted in hardcopy format; all otherinformation may be submitted electronically.Shall be certified perm Minn. R. 7007.0500,subp. 3

EU276, EU277



01/21/09B-5

Excess Emissions/Downtime Reports (EER's) due 30 days after end of each calendarquarter following Initial Startup of the Monitor(Submit Deviations Reporting Form DRF-1 asamended) or other form as approved by theMPCA. The EER shall indicate all periods ofmonitor bypass and all periods ofexceedances of the limit includingexceedances allowed by an applicablestandard, i.e. during startup, shutdown, andmalfunctions.

EU040

Excess Emissions/Downtime Reports (EER's) due 30 days after end of each calendarquarter following Initial Startup of the Monitor(Submit Deviations Reporting Form DRF-1 asamended). The EER shall indicate all periodsof monitor bypass and all periods ofexceedances of the limit includingexceedances allowed by an applicablestandard, i.e. during startup, shutdown, andmalfunctions.

GP111, SV083

Excess Emissions/Downtime Reports (EER's) due 30 days after end of each calendarquarter following Initial Startup of the Monitor.Submit Deviations Reporting Form DRF-1 asamended. The EER shall indicate all periodsof monitor bypass and all periods ofexceedances of the limit includingexceedances allowed by an applicablestandard, i.e. during startup, shutdown, andmalfunctions. The EER must be submittedeven if there were no excess emissions,downtime or bypasses during the quarter.

MR027, MR179, MR180

Excess Emissions/Downtime Reports (EER's) due 30 days after end of each calendarquarter following Startup (Submit DeviationsReporting Form DRF-1 as amended) or otherform as approved by the MPCA. The EERshall indicate all periods of monitor bypassand all periods of exceedances of the limitincluding exceedances allowed by anapplicable standard, i.e. during startup,shutdown, and malfunctions.

EU245

Excess Emissions/Downtime Reports (EER's) due 30 days after end of each calendarquarter following Startup (Submit DeviationsReporting Form DRF-1 as amended). TheEER shall indicate all periods of monitorbypass and all periods of exceedances of thelimit including exceedances allowed by anapplicable standard, i.e. during startup,shutdown, and malfunctions.

SV042, SV093

Excess Emissions/Downtime Reports (EER's) due 30 days after end of each calendarquarter starting 04/30/2005 (SubmitDeviations Reporting Form DRF-1 asamended) or other form as approved by theMPCA. The EER shall indicate all periods ofmonitor bypass and all periods ofexceedances of the limit includingexceedances allowed by an applicablestandard, i.e. during startup, shutdown, andmalfunctions.

EU282

Excess Emissions/Downtime Reports (EER's) due 30 days after end of each calendarquarter starting 12/31/2004 (SubmitDeviations Reporting Form DRF-1 asamended) or other as approved by the MPCA.The EER shall indicate all periods of monitorbypass and all periods of exceedances of thelimit including exceedances allowed by anapplicable standard, i.e. during startup,shutdown, and malfunctions.

EU296



01/21/09B-6

Excess Emissions/Downtime Reports (EER's) due 30 days after end of each calendarquarter starting 12/31/2004 (SubmitDeviations Reporting Form DRF-1 asamended) or other form as approved by theMPCA. The EER shall indicate all periods ofmonitor bypass and all periods ofexceedances of the limit includingexceedances allowed by an applicablestandard, i.e. during startup, shutdown, andmalfunctions.

EU041, EU228

Quarterly Report due 30 days after end of each calendarquarter starting 10/31/2005 (applies to allquarterly reports: due January 30th, April30th, July 30th and October 30th of eachcalendar year.)

Total Facility

Relative Accuracy Test Audit (RATA) ResultsSummary

due 30 days after end of each calendarquarter following CEMS Relative AccuracyTest Audit (RATA)

EU040, EU041, EU212, EU213, EU228,EU245, EU282, EU294, EU295, EU296,EU313, GP112, MR027, MR152, MR153,MR154, MR156, MR161, MR162, MR165,MR166, MR167, MR168, MR170, MR171,MR179, MR180, MR181, MR182, SV042,SV083, SV093

Relative Accuracy Test Audit (RATA) ResultsSummary

due 30 days after end of each quarterfollowing CEMS Relative Accuracy Test Audit(RATA)

EU019, GP111

Report due before end of each quarter followingExcess Emissions/Downtime Reports (EER's)results of 7-day Draeger testing if morefrequent monitoring is triggered by a)exceeding process parameter value or b)Draeger exceeds 81 ppm.

EU276, EU277

Report due before end of each quarter followingExcess Emissions/Downtime Reports (EER's)results of Draeger Testing.

EU276, EU277

Report due before end of each quarter followingExcess Emissions/Downtime Reports (EER's).Cover letter certification, and summary ofexceedances shall be submitted in hardcopyformat; all other information may be submittedelectronically. Shall be certified per Minn. R.7007.0500, subp. 3

EU204

Report due before end of each quarter followingExcess Emissions/Downtime Reports (EER's);if Draeger shows greater than 81 ppm H2S infuel gas stream monitored under AMP andincreased monitoring is triggered under AMP.

EU276, EU277

Report due before end of each quarter followingExcess Emissions/Downtime Reports (EER's);if H2S at outlet of lead desulfurizer exceeds15 ppmV and increased monitoring istriggered under the AMP.

EU052, EU213

Report due before end of each quarter followingExcess Emissions/Downtime Reports (EER's);if there are any excceedances of the CO andPM/PM10 limit.

EU052

Report due before end of each quarter followingExcess Emissions/Downtime Reports (EER's);if there are any excceedances of the SO2limits.

EU034

Report due before end of each quarter followingExcess Emissions/Downtime Reports (EER's);if there are any exceedances of diesel hoursof operation.

EU127, GP011

Report due before end of each quarter followingExcess Emissions/Downtime Reports (EER's);if there are any exceedances of MMhp-hr permonth and per year.

GP012



01/21/09B-7

Report due before end of each quarter followingExcess Emissions/Downtime Reports (EER's);if there are any exceedances of NOx emissionlimits

EU052

Report due before end of each quarter followingExcess Emissions/Downtime Reports (EER's);if there are any exceedances of NOx emissionlimits.

EU204, EU213

Report due before end of each quarter followingExcess Emissions/Downtime Reports (EER's);if there are any exceedances of NOx lb/hrlimit.

EU127

Report due before end of each quarter followingExcess Emissions/Downtime Reports (EER's);if there are any exceedances of PM-10emission limit.

EU213

Report due before end of each quarter followingExcess Emissions/Downtime Reports (EER's);if there are any exceedances of the SO2 limit.

EU212

Report due before end of each quarter followingExcess Emissions/Downtime Reports (EER's);if there are any exceedances of the SO2 orNOx limit.

EU019, EU026

Report due before end of each quarter followingExcess Emissions/Downtime Reports (EER's);if there are any exceedances of VOCtons/year limit per month and per year.

GP009

Report due before end of each quarter followingExcess Emissions/Downtime Reports (EER's);if there are any exceedances.

EU005, EU016, EU035, EU040, EU041,EU050, EU051, EU053, EU084, EU085,SV066

Report due before end of each quarter followingExcess Emissions/Downtime Reports (EER's);there are any exceedances of the VOC limit.

GP066

Compliance Status Report due 30 days after end of each calendarhalf-year following Notification of compliancestatus. The first compliance report is dueJanuary 31, 2006.

EU126, EU294, EU295, EU296, EU313

COMS Calibration Error Audit ResultsSummary

due 30 days after end of each calendarhalf-year following COMS Calibration ErrorAudit

EU228

Cylinder Gas Audit (CGA) Results Summary due 30 days after end of each calendarhalf-year following Cylinder Gas Audit

EU040, EU041, EU296, EU313, SV083

Report due 30 days after end of each calendarhalf-year following permit issuance for LDARSemiannual Report. This report is dueJanuary 30 and July 30 of each year.

Total Facility

Semiannual Deviations Report due 30 days after end of each calendarhalf-year starting 10/31/2005 . 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 yearstarting 10/31/2005 (for the previous calendaryear). The certification shall be submitted ona form approved by the Commissioner, both tothe Commissioner and to the US EPAregional office in Chicago. This report coversall deviations experienced during the calendaryear.

Total Facility

Report due before end of each year starting04/07/2005 (90 days after start of rule) forNESHAP Annual TAB/2Mg Report. ThePermittee shall prepare and submit NESHAPTAB/2Mg Report for the Total Facility.

Total Facility



01/21/09B-8

Report due before year starting 04/07/2005 (90 daysafter start of rule) for NESHAP AnnualCorrective Actions Report. The Permitteeshall prepare and submit NESHAP annualcorrective action report. This report is for TotalFacility, GP 010, GP 059, GP 060, GP 062,GP 065, GP 068, GP 069, GP 076, GP 102,GP 104, GP 108, GP 109, EU 197 and EU277.

Total Facility

Appendix Material Facility Name: Flint Hills Resources LP- Pine Bend Refinery Permit Number: 03700011-006 None

Appendix Material Facility Name: Flint Hills Resources LP- Pine Bend Refinery Permit Number: 03700011-001

APPENDIX A Insignificant Activities and Likely Applicable Requirements

Operator ID Description of Activity Applicable Insignificant Activity

Likely Applicable Requirement

WATER AND WASTE MANAGEMENT ACTIVITIES (including but not limited to): IA001 - WMgmt

00PINEBEND084

All Hazardous Waste (RCRA) container storage areas

MN R. 7007.1300, subp. 3I(2)

Minn. R. 7011.0150

IA002 - WMgmt

00PINEBEND085

All Solid Waste Container Storage Areas

MN R. 7007.1300, subp. 3I(2)

Minn. R. 7011.0150

IA004 - WMgmt

00PINEBEND086

Polishing Ponds MN R. 7007.1300, subp. 3I(2)

Minn. R. 7011.0150

IA005 - WMgmt

00PINEBEND087

Clarifiers: 94V6A, 94V6B, 94V23A and 94V23B

MN R. 7007.1300, subp. 3I(2)

Minn. R. 7011.0150

IA006 - WMgmt

00PINEBEND088

Effluent Sampling Station - polishing ponds

MN R. 7007.1300, subp. 3I(2)

Minn. R. 7011.0150

IA007 - WMgmt

94ME163 S7 Sump MN R. 7007.1300, subp. 3I(2)

Minn. R. 7011.0150

IA011 - WMgmt

94B5 North Firewater Basin, B-5 MN R. 7007.1300, subp. 3I(2)

Minn. R. 7011.0150

IA012 - WMgmt

00PINEBEND089

21 and 23 Unit Clarifiers MN R. 7007.1300, subp. 3I(2)

Minn. R. 7011.0150

IA013 - WMgmt

00PINEBEND090

23 Unit Water Recovery Tank

MN R. 7007.1300, subp. 3I(2)

Minn. R. 7011.0150

IA014 - WMgmt

00PINEBEND091

Coker Water and Coker Water Management Area

MN R. 7007.1300, subp. 3I(2)

Minn. R. 7011.0150

IA015 - WMgmt

00PINEBEND092

Stormwater and Firewater Storage

MN R. 7007.1300, subp. 3I(2)

Minn. R. 7011.0150

IA016 - WMgmt

00PINEBEND093

Effluent Discharge MN R. 7007.1300, subp. 3I(2)

Minn. R. 7011.0150

REFINERY GENERAL IA017 – RG

00PINEBEND055

Cleaning (blasting) of Vessels, Piping and Structural Steel in Refinery

MN R. 7007.1300, subp. 2.B(2)

Minn. R. 7011.0150

IA018 – RG

00PINEBEND056

Cleaning (blasting) of pumps, compressors, valves, flanges and misc materials (paint shop)

MN R. 7007.1300, subp. 2.B(2)

Minn. R. 7011.0150

IA019 – RG

00PINEBEND057

Painting of Vessels, Piping and Structural Steel in Refinery

MN R. 7007.1300, subp. 2.B(1)

Minn. R. 7011.0150

IA020 – RG

103UNIT Barge Pipeline and Associated Equipment

MN R. 7007.1300, subp. 3.I(2)

Minn. R. 7011.0150

IA021 – RG

00PINEBEND058

Spent Acid Pipeline and Associated Equipment

MN R. 7007.1300, subp. 3.I(2)

Minn. R. 7011.0710/ Minn. R. 7011.0715

IA022 – RG

00PINEBEND059

MAPCO Pipeline and Associated Equipment

MN R. 7007.1300, subp. 3.I(2)

Minn. R. 7011.0710

IA023 – RG

00PINEBEND060

Barge Dock Oil Collection Pits

MN R. 7007.1300, subp. 3.I(2)

Minn. R. 7011.0710

IA024 – RG

00PINEBEND061

Painting of Pumps, Compressors, Valves, Flanges and Misc Materials (Paint Shop)

MN R. 7007.1300, subp. 2.B(1)

Minn. R. 7011.0710

IA025 – RG

00PINEBEND062

General Cleaning & Maintenance Activities - Pumps, Valves, Compressors, Exchangers, other equipment

MN R. 7007.1300, subp. 2.B(2)

Minn. R. 7011.0150

IA026 – RG

00PINEBEND063

Process Unit Filter Changing

MN R. 7007.1300, subp. 3.I(2)

Minn. R. 7011.0150

IA027 – RG

00PINEBEND064

Fire Training Grounds and Fire Fighting Activities

MN R. 7007.1300, subp. 3.I(2)

Minn. R. 7011.0150

IA028 – RG

00PINEBEND065

Vehicle Maintenance MN R. 7007.1300, subp. 2.B(2)

IA029 – RG

00PINEBEND066

Wood Working/Wood Construction Activities

MN R. 7007.1300, subp. 3.I(2)

Minn. R. 7011.0150

IA030 – RG

00PINEBEND067

Indirect Sources - Mobil Sources (Refinery Vehicles and Equipment

MN R. 7007.1300, subp. 2.J(3)

N/A

IA031 – RG

00PINEBEND068

Heat Exchanger/Bundle Cleaning

MN R. 7007.1300, subp. 3.I(2)

Minn. R. 7011.0150

IA032 – RG

00PINEBEND069

Paving MN R. 7007.1300, subp. 2.B(1)

Minn. R. 7011.1505

IA033 – RG

00PINEBEND070

Retarring of Roofs MN R. 7007.1300, subp. 2.B(1)

Minn. R. 7011.0150

IA034 – RG

00PINEBEND071

Washer/Dryer in Safety Fire Barn

MN R. 7007.1300, subp. 2.B(1)

Minn. R. 7011.0710

IA035 – RG

00PINEBEND072

Test Pumps (Diesel Driven, pneumatic)

MN R. 7007.1300, subp. 3.I(2)

Minn. R. 7011.0150

IA036 – RG

00PINEBEND073

Furnaces - Building HVAC MN R. 7007.1300, subp. 3.I(2)

Minn. R. 7011.0150

IA037 – RG

00PINEBEND074

Stress Relieving MN R. 7007.1300, subp. 3.I(2)

Minn. R. 7011.0150

IA038 – RG

00PINEBEND075

Fabricating MN R. 7007.1300, subp. 3.I(2)

Minn. R. 7011.0710

IA039 – RG

00PINEBEND076

Welding, Soldering, Brazing Activities

MN R. 7007.1300, subp. 3.H(4)

Minn. R. 7011.0150

IA040 – RG

00PINEBEND077

Oxgen/Acetylene Torches MN R. 7007.1300, subp. 3.H(4)

Minn. R. 7011.0150

IA041 – RG

00PINEBEND078

Space Heaters (Kerosene, Natural Gas, Propane)

MN R. 7007.1300, subp. 3.I(2)

Minn. R. 7011.0510

IA042 – RG

00PINEBEND079

Parts Washers /Degreasers MN R. 7007.1300, subp. 3.I(2)

Minn. R. 7011.0710/ Minn. R. 7011.0715

IA043 – RG

00PINEBEND080

Air Compressors other than Listed as EUs

MN R. 7007.1300, subp. 3.I(2)

Minn. R. 7011.0710

IA044 – RG

00PINEBEND081

Chlorine Cylinders MN R. 7007.1300, subp. 3.I(2)

Minn. R. 7011.0710

IA045 – RG

00PINEBEND082

Cylinders for CEM QA/QC MN R. 7007.1300, subp. 3.I(2)

Minn. R. 7011.0710

IA046 – RG

00PINEBEND083

Activated Carbon Handling MN R. 7007.1300, subp. 3.I(2)

Minn. R. 7011.0710

IA047 – RG

52ME91 Knock Engine #1 MN R. 7007.1300, subp. 4(B)

Minn. R. 7011.2300

IA048 – RG


Minn. R. 7011.2300

IA049 – RG


Minn. R. 7011.2300

IA050 – RG

52ME2A Knock Engine #4 MN R. 7007.1300, subp. 4(B)

Minn. R. 7011.2300

IA051 – RG

52ME2B Knock Engine #5 MN R. 7007.1300, subp. 4(B)

Minn. R. 7011.2300

IA052 – RG

52ME65A Knock Engine #6 MN R. 7007.1300, subp. 4(B)

Minn. R. 7011.2300

IA053 – RG

52ME65B Knock Engine #7 MN R. 7007.1300, subp. 4(B)

Minn. R. 7011.2300

IA054 – RG

00PINEBEND051

Combustion Promoter Transfer/Dumping Activities

MN R. 7007.1300, subp. 3.I(2)

Minn. R. 7011.0710

IA055 – RG

00PINEBEND052

Spent Acid Loading MN R. 7007.1300, subp. 3.I(2)

Minn. R. 7011.0710/ Minn. R. 7011.0715

IA056 – RG

00PINEBEND053

Sulfur Loading MN R. 7007.1300, subp. 3.I(2)

Minn. R. 7011.0710

IA058 – RG

00UNIT Refinery Deaerator Vents (not including 25V52, 25V53, 27V509 and 33V41)

MN R. 7007.1300, subp. 3.I(2)

Minn. R. 7011.0710

IA059 – RG

32UNIT1 Powerformer Catalyst Regeneration

MN R. 7007.1300, subp. 3.I(2)

Minn. R. 7011.0710

ROADS AND PARKING LOTS IA060 - RP 00UNIT_4 All roads in refinery - paved

or unpaved MN R. 7007.1300, subp. 3.J

Minn. R. 7011.0150

IA061 - RP 00PARKING003

All parking lots in refinery - gravel or paved

MN R. 7007.1300, subp. 3.J

Minn. R. 7011.0150

IA062 - RP 00UNIT_3 All Laydown Areas MN R. 7007.1300, subp. 3.J

Minn. R. 7011.0150

LABORATORY IA063 - LAB

113UNIT_1 FHR Environmental Laboratory

Minn. R. 7007.1300, subp. 3.G.

Minn. R. 7011.0710

STORAGE TANKS IA-100 - Tanks

00PINEBEND097

All insignificant activity - tanks and vessels

Minn. R. 7007.1300, subp. 3(I)(2)

Minn. R. 7011.1505

Minn. R. 7007.1300, subp. 4(B)


Appendix B Stack Parameters Relied Upon in the Modeling to Demonstrate

Compliance with the National Ambient Air Quality Standards for Sulfur Dioxide (SO2) – Amendment 8 to the Administrative Order

Title I Conditions (Paper Copy Only)


Appendix C Supporting and Administrative Requirements Associated

With the State Implementation Plan (SIP) (Paper Copy Only)


Appendix D Consent Decree

(Paper Copy Only)


Appendix E Flint Hills Resources ULSD Project

Projected Emissions Increases (Paper Copy Only)

Technical Support Document, Permit Action Number: 03700011-006 Page 1 of 35 Date: 2/25/2009

TECHNICAL SUPPORT DOCUMENT For

AIR EMISSION PERMIT NO. 03700011-006 This technical support document is for 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 determination to issue the permit. 1. General Information

1.1 Applicant and Stationary Source Location:

Applicant/Address Stationary Source/Address (SIC Code: 2911)

Flint Hills Resources, LP PO Box 64596 St. Paul, MN 55164-0596

Flint Hills Resources, LP Pine Bend Facility 12555 Clark Road Rosemount, Dakota County, MN 55068

Contacts: Mr. Lowell Miller Stolte (MSAT) Phone: 651-437-0831 Ms. Beth Freymiller (NOX Coker Test) Phone: 651-437-0961

Ms. Dzung Farell (SWT) Phone: 651-480-3865 Mr. Michael Krautkremer (No. 3 Coker) Phone: 651-480-3914

1.2 Description of the Facility

Flint Hills Resources, LP (“FHR” or “Permittee”) owns and operates the Pine Bend Refinery (“refinery” or “facility”) in the city of Rosemount, Dakota County, Minnesota. The refinery primarily processes heavy, sour crude oil from Western Canada, although it may also process oil from other parts of the world. Pipelines currently deliver all of the crude oil to the refinery, where FHR processes it to produce a wide variety of products. These products include gasoline, diesel fuel, heating oil, jet fuel, petroleum coke, asphalt, elemental sulfur, and carbon dioxide. FHR distributes these products to customers in Minnesota and the surrounding Upper Midwest states via pipelines, trucks, barges and rail cars.

1.3 Description of any Changes Allowed with this Permit Issuance

This major amendment is a combination of several permit applications for unrelated changes at the facility. These changes are for sour water tanks, installation of a new Penex unit to meet new mobile source air toxics (MSAT II) requirements for (reduction of) gasoline benzene content, updated testing requirements for the Nos. 1, 2 and 3 coker heaters, a 120-day test extension for coker heaters Nos. 1, 2, and 3, and revisions to the requirements for the No. 3 coker drum replacement permit issued in October 2007 due to changes in the scope of the drum replacement project.


Major Permit Amendment for Sour Water Tanks (SWT)

This major permit amendment application requests authorization for changes to the sour water tanks to meet industry best practice standards. The proposed changes will address potential safety implications of higher concentration hydrogen sulfide (H2S) and volatile organic compound (VOC) releases from the PSVs located on each tank. Although infrequent, computer modeling conducted for the H2S emissions vented from the PSVs on each of the sour water tanks indicated the possibility of localized H2S emissions that could pose safety concerns to facility personnel near the tanks. This permit amendment is required because proposed physical changes to the sour water tanks will trigger modification/reconstruction provisions for two affected sources under NSPS subpart K, thereby triggering compliance with NSPS subpart Kb.

The Permittee plans to modify the current sour water tanks (TK367, TK368 & TK515) from fixed roof tanks to floating roof tanks with additional control provided through implementation of a lean sponge oil layer in the tanks. A nitrogen blanket will replace the fuel gas blanket previously used on the tanks above the internal floating roof in order to maintain vapor concentrations below the lower explosive limit (LEL). The modification of the fixed roof tanks to internal floating roof tanks will eliminate the free evaporation of the surface liquid to the headspace resulting in reduced frequency of atmospheric releases. The lean sponge oil layer will act as additional control to lower H2S emissions found in the sour water. Finally, the sour water skimmer vessels are being increased in size to allow for better separation of higher vapor pressure components prior to transfer into the sour water tanks, further reducing the frequency of an atmospheric release from the tanks.

The tanks are currently controlled via steam eductors that route the emissions from the sour water tanks to either the flare gas recovery system or low pressure gas recovery system. FHR plans to remove the eductors from the sour water tanks as part of this project. As noted previously, when the tanks are modified to internal floating roof tanks, a nitrogen blanket will replace the current fuel gas blanket since the fuel gas would preferentially saturate the sponge oil. If the tanks remained connected to the eductors, the nitrogen would overload the flare (or fuel) gas recovery systems. CE017 and CE021 were the control equipment that controlled emissions from the sour water tanks prior to the eductors being used. CE017 and CE021 are being removed from TK367 and TK368 in the facility description as control equipment for these tanks. CE021 was deleted from the facility description by permit action 001.

Project Scope and Schedule (SWT)

This major amendment covers the construction of the proposed modification for the sour water tanks (TK367, TK368, and TK515) from fixed roof to internal floating roof tanks as well as the implementation of additional control through a lean sponge oil layer and tie-ins to the corresponding process units. By modifying the sour water tanks (TK367, TK368, and TK515) as proposed in the application, the tanks will now be subject to NSPS subpart Kb compliance standards.


Table 1. Current & Proposed Listings of Tanks in Title V Permit Groups

Tank ID Current Applicable Group(s) Proposed Applicable Group(s) after Modification

TK367, TK368 GP032 NSPS K Tanks w/ fixed roof & CVS/CD & >40,000 gals

GP039 NSPS Kb tanks w/ internal floating >39,890 gals & tvp (0.75-11.1 psi)

GP043 MACT CC Group 2 Tanks (Not subject to NSPS Ka or Kb)

GP042 MACT CC Requirements, satisfied by NSPS Kb

GP046 Tanks MN R post 1973 & >40,000 gals

Same as left column for GP046.

TK515 GP025 NSPS Kb Tanks w/ fixed roof >39,890 gals

GP039 NSPS Kb tanks w/ internal floating >39,890 gals & tvp (0.75-11.1 psi)

GP042 MACT CC Requirements, satisfied by NSPS Kb


GP046 Tanks MN R post 1973 & >40,000 gals


Note: See Table 10 notes for explanation of Groups that Tanks 367, 368 & 515 will be joining after the sour water tanks project modification to internal floating roofs.

Other Changes at the Facility Considered in this Permit Action (SWT)

1. The current skimmers of the influent sour water lines will be increased in size to allow for longer residence times in the skimmers resulting in reduced VOC and H2S concentrations in the sour water sent to the storage tanks. The skimmers are considered flow through process vessels and have a closed vent control system via the flare gas recovery system.

2. The fuel gas blanket used in the current fixed roof sour water tanks will be replaced with a nitrogen blanket.

3. On-line H2S analyzers will be installed on each of the sour water tanks in the headspace above the floating roof to provide monitoring for indication of sponge oil saturation or other upset condition.

4. The stripped sour water tank (TK516) which is currently connected to the same eductor system at TK516 will be retrofitted with a conservation vent to atmosphere. Controls are not required on this tank based on vapor pressure (NSPS Kb), HAP content (MACT CC), or benzene content (NESHAP FF).

Schedule for Project Completion (SWT)

The proposed construction start date for the sour water tanks modification project is June 2008 with a final completion date of August 2010 (April 2010 for TK515, June 2010 for TK368, and August 2010 for TK367). Skimmer improvements are scheduled to begin construction in 2009. The length of time to complete the project is due to the timing of when each sour water tank can be taken off-line without causing disruptions to the facility process units. Only one sour water tank can be taken off-line and modified at a time so as not to cause process upsets. Although construction is currently scheduled to extend over roughly two years, the schedule is subject to some variation.


Minor Permit Amendment for Mobile Source Air Toxics II (MSAT II)/Penex Project

Section 202(l) of the Clean Air Act required the U.S. Environmental Protection Agency (EPA) to set standards to control hazardous air pollutants from motor vehicles and other moving sources (called “mobile source air toxics,” or MSATs), motor vehicle fuels, or both. Hazardous air pollutants, also known as air toxics, include benzene and other hydrocarbons such as 1,3-butadiene, formaldehyde, acetaldehyde, acrolein, and naphthalene. EPA published a rule under this authority in March 2001 that established toxics emissions performance standards for gasoline refiners and committed to additional rulemaking to evaluate the need for and feasibility of additional controls.

This additional rulemaking was finalized in February, 2007, when EPA issued a final rule (generally referred to as MSAT II) to reduce hazardous air pollutants from mobile sources. The final standards will significantly lower emissions of benzene and the other air toxics in three ways: (1) by lowering benzene content in gasoline; (2) by reducing exhaust emissions from passenger vehicles operated at cold temperatures (under 75 degrees); and (3) by reducing emissions that evaporate from, and permeate through, portable fuel containers.

This project is intended to meet the requirements of the first of these. Specifically, EPA is requiring that, beginning in 2011, refiners must meet an annual average gasoline benzene content standard of 0.62 percent by volume (vol%) on all their gasoline, both reformulated and conventional, nationwide. The national benzene content of gasoline today is about 1.0 vol%. The regulations include a nationwide averaging, banking, and trading program. In addition to the 0.62 vol% standard, refiners must also meet a maximum average benzene standard of 1.3 vol% beginning on July 1, 2012. A facility’s or importer’s actual annual average gasoline benzene levels may not exceed this maximum average standard.

Permittee (FHR) is planning to utilize a combination of processes to meet the requirements for low toxics gasoline standards: • Benzene saturation to convert the benzene in naphtha streams to cyclohexane; • Pre-fractionation to remove components (benzene precursors) from feedstocks to reformers

that would otherwise be converted to benzene within the reformers; and, • Post-fractionation to remove benzene from naphtha streams prior to being blended into

gasoline.

Specifically, with this project, FHR is planning to: • Construct a new isomerization unit referred to as the Penex unit that will reduce the

concentration of benzene in gasoline blend streams; • Modify an existing naphtha splitter to increase pre-fractionation capabilities (i.e., send light

naphtha to either Penex unit); and, • Utilize an existing naphtha splitter for post-fractionation benzene removal.

Total potential emissions increases for all pollutants represented in this application following installation and startup of the MSAT II project are estimated at ~100 tons per year (tpy) in aggregate. However, due to the conservative nature of emissions estimates, total actual air emissions are expected to increase less than 10 tpy in aggregate beyond emissions that have been achieved with the FHR Emissions Reduction Initiative (ERI) completed in 2004. The ERI


resulted in a reduction in total facility emissions of greater than 50% over 5 years. This emissions-neutral project approach has limited actual emissions increases resulting from all recent projects and has been achieved by implementing a number of changes to reduce emissions further, primarily by installation of ultra low NOx burners (ULNB) at existing heaters and boilers and sulfur plant improvements.

Project Scope and Schedule (MSAT II)

This permit application covers construction of a proposed new Penex unit (44 Unit) and modifications to existing facility process units and emission units, as shown in Table 1 below. Note that the emission unit (EU) and stack/vent (SV) identification (ID) are shown in the table for new, modified and related existing equipment/activities at the facility. The existing IDs are contained either in FHR’s Title V permit application or were not needed in the Title V application and are used solely for equipment identification purposes.

The general project scope for the new Penex Unit and modified existing equipment is contained in the following sections and is organized consistent with Table 1. FHR has attempted to be as specific as possible in detailing the scope of work that may be performed. However, projects that are listed in this application may be cancelled or revised, and new projects may be added that relate to the MSAT II Project objectives. If a proposed modification will occur in the future that relates to the MSAT II Project, and if the modification changes the emissions increase or the regulatory applicability as shown in this permit application, FHR will submit an amended permit application to Minnesota Pollution Control Agency (MPCA) in accordance with federal and state air quality permitting rules.

TABLE 2. EMISSION UNIT (EU) AND STACK/VENT (SV) IDS COVERED IN THIS PERMIT APPLICATION. (MSAT II)

MPCA MPCA FHR FHR

Unit EU ID SV ID EU ID SV ID

New Penex Unit Fugitives FS-135 (new) NA FS-44UNIT NA

25 Splitter Fugitives FS-048 NA FS-25UNIT NA New

or

Phys

ical

ly

Mod

ified

EU

s

15 Splitter Fugitives FS-027 NA FS-15UNIT NA Related Hydrogen Plant Increase EU-052 SV-046 EU-27H1 SV-27H1 Related Cooling Tower Increase EU-268 NA EU-CT1 NA Related Steam Increase EU-313 SV-173 EU-B9 SV-B9

Non

-mod

ified

Pr

ojec

t Rel

ated

A

ctiv

ities

Related Light Naphtha Tank Increases TK-011 NA EU-TK11 NA

New Penex Unit (MSAT II)

The new Penex unit will be approximately 50% larger than the existing Penex unit, and will be designed for a 20,000 barrels per day (bpd) feed rate. The Penex process (the most widely used isomerization process) is a fixed bed process that utilizes a chloride-promoted catalyst to isomerize 5- and 6-carbon paraffins to higher octane branched components. Essentially the unit converts low-value low octane gasoline component (referred to as light naphtha) into high-value


high octane gasoline component (referred to as isomerate), and concurrently converts the aromatic components (e.g., benzene) to branched paraffins. The unit will be located in a central location within the facility complex in the area of a maintenance shop that will be removed to accommodate the new unit. Equipment within the unit includes process vessels (including guard beds, feed surge drum, Penex reactors, naphtha stabilizer, feed driers, methanator reactor, gas driers, and off-gas caustic scrubber), valves, flanges, pumps, and heat exchangers. No new process heaters will be installed; the limited heat required will be obtained by utilizing steam through reboilers or exchangers.

From an emissions perspective, a new fugitive emissions source (FS-135) will be generated for this process unit that will include the valves, pumps, and connectors that will be monitored under the Consolidated Leak Detection and Repair (LDAR) program, and new oily water sewer cups. No other emission units will be constructed within the process unit.

Physical Changes to Existing Facility Equipment (MSAT II)

The following list summarizes specific physical changes or modifications that will occur with existing equipment to support the MSAT II project. Most all of these have quantifiable emission increases exclusively associated with fugitive emission sources: 1. 25 unit splitter modifications:

• 25 unit splitter pump replacements (25P-40s); • Light naphtha jumpover (piping connection between two lines) to 25 splitter feed

line; • New piping from the 25 unit to the new 44 unit;

2. 15 unit splitter modifications: • added overhead air coolers (15V8 overhead); • added debutanizer bottoms air cooler; • debutanizer modifications (jumpovers and level controllers to 28 unit); • replace light naphtha pumps (15P-7s); • replace tower internals on splitter (trays, downcomers, etc.); • jumpovers and piping changes for feed, overhead, and bottoms from splitter; • install sweet naphtha (secondary lean oil) jumpover to achieve fuel gas sulfur

reductions (as referenced in previous air permit applications including the No. 3 coke drum replacement project);

• new pipe connections to Powerformer to replace connections formerly to the 15 unit splitter;

• new pumps in the Powerformer to carry feed to the 15 splitter; 3. New piping connections from existing Penex unit (32 unit) to new Penex unit (44 unit); 4. Utility connections to the new Penex unit:

• hydrogen supply, fuel gas export, flare piping, steam lines, steam condensate, utility water, boiler feed water, instrument air, nitrogen, firewater, potable water for eye wash stations, slop, electrical power supply,

• cooling water, likely from cooling tower No. 1, but possibly from cooling tower No. 3; an additional booster pump may be incorporated into the final design;


• fresh and spent caustic, no new tanks to be installed; will utilize existing storage and supply lines;

• storm sewer, will route to 7th St. sump via the existing diversion box; • oily water sewer, preliminary plans are to tie into minor sump located north of the

new process unit; and • perchloroethylene supply; no new tanks to be installed; will utilize existing storage

and supply lines; 5. Steam tracing for various lines; 6. Heating, ventilating, and air conditioning (HVAC) systems for electrical buildings, etc.; no

new control room is intending to be installed with the new process unit; and, 7. A groundwater supply well (MW-7) will need to be relocated to accommodate the new

process unit. Appropriate regulatory approvals will be obtained for installation of the replacement well.

Non-modified Project-related Activities (Utilization Increases) MSAT II

The proposed changes associated with the MSAT II Project are expected to require additional hydrogen supply to effectively remove the benzene from the light naphtha stream. No physical changes are planned for the hydrogen plants that would increase rates or potential emissions from these emission units. Improved utilization or market driven reductions in other units will provide the necessary hydrogen to ensure successful operation of this unit. However, for completeness additional heater firing in the hydrogen plants is included in this analysis.

A preliminary steam balance on the MSAT II Project has been performed to evaluate if any additional steam production at the existing boilers may be necessary. The project steam balance shows a 55,000 lb/hr increase in steam demand resulting in increased firing on the boiler of approximately 60 mmBtu/hr. This incremental steam use from a site perspective will likely be generated from Boiler No. 9 which was installed within the last two years. Although FHR believes this added steam will be within the previously permitted capacity of Boiler No. 9, similar to the additional hydrogen discussed above, emissions for steam generation have been added to this permit to be conservative.

Additional cooling water supply will be needed with the new process unit. This may necessitate increased recirculation rates within the cooling towers which would have an impact on emissions from cooling towers. The MSAT II Calculations attachment provides documentation for these potential increases.

No new storage tanks for the isomerate or light naphtha are being installed as part of this project. Essentially, light naphtha that previously would have been managed in the light naphtha tanks (floating roof tanks) will now be treated in the new Penex unit and will be routed to the light naphtha tank (also floating roof tank). This change will not result in increased rate for these two tanks cumulatively, but will result in a slight increase in vapor pressure for the isomerate material stored in the light naphtha tank. Emissions increases associated with these tanks are discussed in the MSAT II Calculations attachment to this TSD.

Schedule for Project Completion (MSAT II)


The proposed construction start date for the actual Penex unit (44 Unit) is March 2009 with a tentative completion and start-up date of March 2010. Demolition of the maintenance shop, located in the area of the new Penex unit, is expected to be completed later in 2008. Monitoring well No. 7 relocation, also currently located in this area, is expected to begin in August 2008. Demolition of the existing well will occur once the new well is online. Modifications to the 15 and 25 unit splitters will occur over the next two years beginning in 2009.

Major Permit Amendment to Revise Performance Test Requirements and Conversion of Operating Limits to Emission Factor Thresholds for Coker Heaters (EU 028, EU 030, and EU 034)

The 2005 Title V operating permit contains EU 028 (21H-1), EU 030 (21H-2), and EU 034 (23H-1) NOX and CO performance testing requirements. FHR uses the test results for calculating emissions for emissions inventory purposes. There are no applicable NOX or CO limits for these heaters. FHR requests revision of the five-year testing frequency in the 2005 Title V permit to a 10-year testing frequency, and authorization to operate EU 028, EU 030, and EU 034 above the permitted operating limit as part of the current permit action.

These coker heaters were initially tested in December 2003 as part of FHR’s Emissions Reduction Initiative. The five-year testing frequency was established in the Title V permit based on requirements of Minn. R. 7019.3050, item C in effect at that time. The rule allowed use of stack test data up to five years old for emission inventory purposes. Since then, Minn. R. 7019.3050, item C was amended to allow use of performance test data up to ten years old for inventory purposes. A 10-year testing frequency is now acceptable because none of these coker heaters are subject to NOX or CO emission limits (and therefore the test frequency should not be based on the MPCA Testing Frequency Policy). The next performance tests are due December 3, 4, and 5, 2013 for EU 030, EU 028, and EU 034, respectively.

The Title V permit also contains limits based on the performance testing to restrict heater operating levels. However, the testing was not for determining compliance and there are no applicable NOX or CO limits. Therefore Minn. R. 7017.2025, subps. 3 and 3a do not apply and operating limits should not be imposed on these heaters based on the performance testing.

FHR requests authorization to operate EU 028, EU 030, and EU 034 above the permitted duty limit (referred to as the operating limit in the 2005 Title V permit) established by the 2003 testing. FHR proposes to use the appropriate AP-42 emission factor or other MPCA-approved factors to calculate emissions when operating the heaters above permitted duty limits. MPCA staff agreed to revise the permit as requested because AP-42 emission factors (in table 1.4-1 for large wall fired boilers) are conservative compared to factors measured during performance testing (refer to Table 3). In addition, the operating limit imposed by the emission factor performance testing is now more appropriately referred to as the ‘emission factor threshold’ (EFT) in the revised Title V permit, and the citation was changed from Minn. R. 7017.2025, subp. 3 to Minn. R. 7007.0800, subp. 2 because testing is not for compliance determination purposes and Minn. R. 7017.2025, subps. 3 and 3a do not apply.

Table 3. Coker Heater Emission Factor Comparisons1


Emission Unit

Test Date Tested NOX

Factor

AP-42 NOX

Factor

AP-42 NOX (Large Wall-Fired Boilers Emission Factor Category)

Tested CO

Factor

AP-42 CO Factor

EU 028 (21H-1)

12/04/03 0.164 0.193 0.004 0.058

EU 030 (21H-2)

12/03/03 0.153 0.193

Uncontrolled Pre-NSPS 0.001 0.058

EU 034 (23H-1)

12/05/03 0.037 0.097 Low NOX Burners 0.007 0.058 1All factors in lb/mmBtu; AP-42 factors converted to lb/mmBtu at a HHV of 1448 Btu/scf of refinery fuel gas (HHV usually 1100 – 1200 Btu/cf; 1448 Btu/cf measured 12/2003); all testing done while combusting refinery fuel gas

Also note the EU 034 EFT is 133.4 mmBtu/hr. The EFT was originally reported as 187.2 mmBtu/hr in the November 2, 2004 NOX Notice of Review letter due to a test data reporting error. This error was corrected by permit No. 03700011-004.

During the drafting of the current permit action (Permit 006), MPCA staff made several determinations regarding establishment of EFTs through performance testing, and the necessary number of runs for each test. For testing when the only purpose is to establish or revise an emission factor, the test shall be composed of at least 3 test runs. The EFT is calculated as 110% of the average operating rate of all test runs.

Administrative Amendment for 120-day Test Extension on Coker Heaters (EU028, 030, 034)

An administrative amendment was received October 6, 2008 in accordance with Minn. R. 7007.1400, subp. 1(H) to extend the deadline by 120 days for performance tests on coker heaters nos. 1, 2 and 3. This extension will allow the heaters to be covered by the permit shield while the current amendment to extend the testing frequency to ten years for these heaters is processed.

23H-2 (EU 035) No. 3 Coker Operating Limit and Testing Frequency

EU 035 NOX and for CO testing is conducted periodically for re-evaluation of the NOX to O2 and CO to O2 emissions correlations for use in continuous calculation of NOX and CO emissions. While testing for compliance determination is usually conducted at worst case conditions for all test runs (which in many cases is at maximum operating rate), whereas testing for correlation evaluation is done throughout the range of normal operation to determine a correlation equation.

Although EU 035 testing is for evaluation of emissions correlations, this heater is subject to NOX and CO limits and therefore it is still appropriate to establish operating limits based on testing results by using requirements of Minn. R. 7017.2025, subps. 3 and 3a, as guidance. These rules state that when testing determines that a source is in compliance but the source operates at less that 90% capacity during the test, an operating limit is established at 110% of the average operating rate of all test runs providing emissions were measured at less than 80% of the applicable limit.

For a correlation test, operating levels are intentionally varied to re-evaluate the correlation throughout the normal operating range. As a result, it is reasonable to establish an operating rate based on the maximum single run operating rate as opposed to the average operating rate of all


test runs. If the measured emissions did not exceed 80% of any applicable limit, the operating limit will be 110% of the maximum single run operating rate.

EU 035 rated capacity is 122 mmBtu/hr and 90% of the capacity is 109.8 mmBtu/hr. The maximum operating rate of any of the test runs was 102.6 mmBtu/hr, the maximum NOX was 0.057 lb/mmBtu (limit is 0.12 lb/mmBtu), and the maximum CO was 0.00186 lb/mmBtu (limit is 0.10 lb/mmBtu). Both NOX and CO were measured at less than 80% of applicable limits. Based on the results of the June 2007 testing and this discussion, the EU 035 operating limit was revised from the existing permit value (104.4 mmBtu/hr) to 112.9 mmBtu/hr (110% * 102.6 mmBtu/hr). In addition, the citation for the operating limit (imposed by the emissions correlation testing) was changed from Minn. R. 7017.2025, subp. 3 to Minn. R. 7007.0800, subp. 2 because testing is not for compliance determination purposes, the operating limit is not determined exactly as prescribed at Minn. R. 7017.2025, subp. 3, and Minn. R. 7017.2025, subp. 3 does not apply.

This permit amendment (permit 006) also addresses an issue regarding the EU 035 test frequency established by the December 19, 2007 Notice of Compliance (NOC) based on June 28, 2007 testing for NOX and for CO. During the tests, emissions were measured at less than 60% of applicable limits. The NOC revised the testing frequency from once every 36 months to once every 60 months based on MPCA stack testing frequency guidance. However, the testing was not for compliance demonstration purposes; it was for re-evaluation of the NOX to O2 and CO to O2 emissions correlations.

The test frequency guidance is based on the concept that the larger the margin of compliance measured during a test, the larger the time interval until the next test. This concept is not applicable for establishing an EU 035 testing frequency because EU 035 testing is for evaluation of emissions correlations equations used in continuous calculation of NOX and CO emissions. The frequency of correlation testing should be based on a more appropriate parameter such as the degree of variability of a succession of test results, as opposed to the margin of compliance with an applicable limit. As a result the testing frequency guidance is not applicable and the test frequency will remain at 36 months. Note that EPA has proposed performance specification 16 (PS 16) to Appendix B of part 60. PS 16 as proposed requires verification of the correlations once each year.

Major Amendment for Revision of October 2007 No. 3 Coker Drum Replacement Permit


Permit No. 03700011-004 (October 2007 No. 3 coker drum replacement permit) authorized end-of-life replacements of the two 23 unit coke drums (E & F), and modifications to the coke drum heaters (EU 034 and EU 035) and associated equipment to expand No. 3 coker throughput by up to 4000 bpd. The project was permitted as a PSD major modification due to a significant net emissions increase for NOX.

In late 2007, the Permittee determined it was necessary to separate the drum replacement project from any future project for expanding No. 3 coker capacity (such as modifications to the No. 3 coke drum heaters), due to economic, engineering, and construction issues. Construction on the drum replacement project is now forecast to commence spring 2009 with completion in spring 2012. At this time the Permittee has no plans for modifying the No. 3 coker heaters.

The Permittee has demonstrated that the No. 3 coker drum replacement is completely separate from any unit expansion due to the need for separate internal approvals for an expansion, if or when such expansion would proceed. However, due to the long lead time, replacement drums were ordered and manufactured approximately 50% larger than existing drums to accommodate the original project scope (that included the No. 3 coker expansion).

Given the original and potential future link to a unit expansion project, the Permittee engaged in a series of discussions with the MPCA on phased permitting and project aggregation. The MPCA agreed that the drum replacement and the possible future heater modifications could be permitted as two separate projects, based on the information provided by FHR. If the Permittee engages in a future heater modification project within two years of the drum replacement project, the Permittee is committed to including the combined emissions increase for the two projects in a future PSD analysis. If PSD thresholds are projected to be reached, updated BACT and ESA analyses will be submitted prior to initiating any expansion phase.

Due to the revised scope of the No. 3 coker drum replacement, the Permittee submitted an application in May 2008 for this major amendment to revise the permit accordingly. The application included a revised PSD applicability analysis. Although the new replacement drums will lead to a small increase in the No. 3 coker and related equipment utilization compared to historical baseline rates, the revised analysis demonstrates that emission changes would not exceed PSD significant levels. As a result, this major amendment removes the PSD requirements from the 2007 No. 3 coker drum replacement permit because the project is no longer a PSD major modification.


Table 4. Project Scope and Schedule (No. 3 Coker Drum Replacement Revision) Emission Unit/Fugitive Source

Description MPCA EU ID

MPCA SV ID

FHR EU ID

FHR SV ID

FS 027 N/A FS-15UNIT N/A New Process Fugitive Components in VOC Service FS 045 N/A FS-23UNIT N/A

New

Fu

gitiv

e Em

issi

ons

New Flare Gas Recovery Compressors & Vessels

FS 109 N/A FS-84UNIT N/A

Related No. 3 Coker Charge Heater (23H-1) EU 034 SV 032 EU-23H1 SV-23H1 Related No. 3 Coker Charge Heater (23H-2) EU 035 SV 033 EU-23H2 SV-23H2 Related 38 GOHT Heaters (38H-2, 38H-1A, 38H-1B)

EU 102 EU 103 EU 104

SV 087 SV 088 SV 089

EU-38H2, 38H1A, 38H1B

SV-38H2, 38H1A, 38H1B

Related 27 DHT Heaters (27H-101, 27H-102)

EU 050 EU 051

SV 044 SV 045

EU-27H101, 27H102

SV-27H101, 27H102

Related 28 NHT Heater (28H-1) EU 053 SV 047 EU-28H-1 SV-28H-1 Related Steam Demand (71B-8) EU 204 SV 132 EU-71B8 SV-71B8 Related SRU Increase GP 112

(EU 111 EU 235 EU 236 EU 237 EU 260 EU 261 EU 262)

N/A Various SRUs

N/A

Related No. 2 H2 Plant Demand (27H-1) EU 052 SV 046 EU-27H1 SV-27H1

Non

-mod

ified

Pro

ject

-rel

ated

Act

iviti

es

Related Storage Tank Increases Various

Fugitive component emissions for the new process components listed in Table 3 will be grouped into the existing emissions group FS-15Unit, FS-84Unit, and FS-23Unit covering the 15, 84 and 23 Units. This includes the 15 unit gas plant, the 84 unit Flare Gas Recovery System, the 23 unit gas plant, and the No. 3 coker unit (23).

New Fugitive Equipment at the #3 Coker Unit, the Flare Gas Recovery System, and the Coker Unit Gas Plants

Changes in the 23 Unit (including the two new drums with associated piping) will create new process fugitive emissions. The Permittee plans to potentially add or modify valves, flanges, and other components associated with this new equipment. Also, the Permittee intends to implement a fuel gas sulfur reduction project within the facility fuel gas system (this will likely include the 15 unit coker gas plant). As part of the No. 3 coker scope revision, the Permittee will add five new compressors and two associated receiver vessels to the facility flare gas recovery system. The compressors will serve the purpose of recovering No. 3 coker drum blowdown vapor.

Note that the MSAT project also involves changes to FS 027 (FS-15Unit). FS 027 emissions data for the No. 3 coker scope revision project is not identical to FS 027 emissions data for the MSAT project. This is because FS 027 is comprised of many different valves, pumps, and flanges and the specific components of FS 027 that are part of the MSAT project are unique and different


from the specific components of FS 027 that are part of the No. 3 coker drum scope revision project.

Modifications to Existing No. 3 Coker Unit Equipment – Revised Scope

The No. 3 coker drum replacement project no longer includes modification of the 23H-1 and 23H-2 heaters. Also, the existing drums are no longer expected to be demolished immediately after installation of the new drums but will be rendered unusable as the process piping and associated equipment will be demolished both during and immediately following the turnaround initiating the change over to the replacement drums.

The fuel gas sulfur reduction project previously necessary for emissions offsets will likely still be implemented within the facility fuel gas system (this will likely target the 15 unit gas plant). This initiative is no longer a commitment but the Permittee intends to implement it as an emissions reduction project at the Facility.

The Permittee will no longer need to limit PM10 emissions by shipping coke primarily through rail cars instead of trucks, restricting coke storage pile acreage from 30 acres to 15 acres, and implementing a conveyor system to transport petroleum coke to the storage pile (instead of using front end loaders).

Installation of a new water separation system to recover the coke drum cutting water with supporting coke fine collection equipment is still scheduled for this project. The revised scope also includes the replacement of the existing cutting water supply pump and the associated supply tank.

Non-modified Project-related Activities

The proposed changes associated with the No. 3 Coker Drum Replacement Project are expected to increase coker utilization by approximately 1500 barrels per day on average over historical baselines. This increased throughput will in turn result in increased utilization of the downstream unit heaters that may increase emissions at fuel gas combustion devices.

1.4. Facility Emissions:

Table 5. Facility Classification

Classification Major/Affected Source

Synthetic Minor Minor

PSD PM, PM10, PM2.5, SO2, NOX, CO,

VOC

N/A Pb

Part 70 Permit Program PM10, PM2.5, SO2, NOX, CO, VOC,

HAP

N/A N/A


Table 6. Title I Emissions Increase Summary (SWT)

Pollutant Emissions Increase from

the Modification

(tpy)

Limited Emissions

Increase from the

Modification (tpy)

Source-wide Contemporaneous

Increases and Decreases (tpy)1

Net

Emissions Increase

(tpy)

PSD/112(g) Significant Thresholds for major sources

NSR/112(g) Review Required?

(Yes or No)

PM 0 N/A 25 No PM10 0 N/A 15 No PM2.5 0 N/A 10 No NOX 0 N/A 40 No SO2 0 N/A 40 No CO 0 N/A 100 No VOC 10.73 N/A 40 No Pb 0 N/A 0.6 No H2S 0.012 N/A 10 No TRS inc. H2S 0.26 N/A 10 No 1Other emission changes during the contemporaneous period as defined by 40 CFR § 52.21, 40 CFR § 52.24 or 40 CFR pt. 51.

Table 7. Title I Emissions Increase Summary (MSAT II)

Pollutant Emissions Increase from the Modified units of the MSAT II

Project (tpy)

Emissions Increase from the New Units of the MSAT II

Project (tpy)

Source-wide Contemporaneous

Increases and Decreases (tpy)1

Total

Emissions Increase

(tpy)


NSR/112(g) Review

Required? (Yes or No)

PM 3.3 N/A 3.3 25 No PM10 3.4 N/A 3.4 15 No PM2.5 3.4 N/A 3.4 10 No NOx 22.9 N/A 22.9 40 No SO2 12.0 N/A 12.0 40 No CO 22.2 N/A 22.2 100 No VOC 4.1 29.0 N/A 33.1 40 No Pb 2.2E-4 N/A 2.2E-4 0.6 No 1Other emission changes during the contemporaneous period as defined by 40 CFR § 52.21, 40 CFR § 52.24 or 40 CFR pt. 51.


Table 8. Non-Title I Emissions Increase Summary for VOCs (SWT) (Only criteria pollutant emitted is VOCs from modifications)

Pollutant

After Change (lb/hr)

Before Change (lb/hr)

Net Change (lb/hr)

Insignificant Modification

Thresholds (lb/hr <)

Minor and Moderate Amendment Thresholds

(lb/hr < or >)

Type of Amendment

(Minor or Moderate)

PM10 0 0 0 0.855 3.42 NA NOX 0 0 0 2.28 9.13 NA SO2 0 0 0 2.28 9.13 NA CO 0 0 0 5.70 22.80 NA VOC 2.44 0 2.44 2.28 9.13 Minor* Pb 0 0 0 0.025 0.11 NA *VOC emission changes from this project qualify for a minor amendment but reconstruction/modification of emission units subject to NSPS subp. Kb requires a major amendment (Minn. R. 7007.1500, subp. 3a).

Table 9. Non-Title I Emissions Increase Summary for VOCs (MSAT II)

Pollutant

After Change (lb/hr)

Before Change (lb/hr)

Net Change (lb/hr)

Insignificant Modification

Threshold (lb/hr <)

Minor and Moderate Amendment Threshold

(lb/hr < or >)

Type of Amendment

(Minor or Moderate)

PM10 0 0 0 0.855 3.42 NA NOX 0 0 0 2.28 9.13 NA SO2 0 0 0 2.28 9.13 NA CO 0 0 0 5.70 22.80 NA VOC 6.6* 0 6.6* 2.28 9.13 Minor Pb 0 0 0 0.025 0.11 NA *0.25 lb/hr VOC from FS027 & FS048 each, 6.1 lb/hr VOC from FS135

Table 10. Title I Emissions Increase Summary (No. 3 Coker Project Revision)

Pollutant ATPA Emissions Increases from

increased utilization of non-modified

existing equipment (tpy)

Emissions Increase

from New Units (tpy)

Source-wide Contempor-

aneous Increases and Decreases

(tpy)1

Total Emission Increase for

scope revision of No. 3 coker drum

replacement (tpy)


(tpy)

NSR/112(g) Review

Required?

(Yes or No)

PM 6.5 N/A 6.5 25 No PM10 2.6 N/A 2.6 15 No PM2.5 1.2 N/A 1.2 10 No NOX 13.7 N/A 13.7 40 No SO2 7.9 N/A 7.9 40 No CO 3.7 N/A 3.7 100 No VOC 1.1 6.0 N/A 7.1 40 No Pb 6.4E-04 N/A 6.4E-04 0.6 No 1Other emission changes during the contemporaneous period as defined by 40 CFR § 52.21, 40 CFR § 52.24 or 40 CFR pt. 51.


2. Regulatory and/or Statutory Basis

2001 CONSENT DECREE

(MSAT II) A Consent Decree between Koch Petroleum Group, L.P. (now Flint Hills Resources, LP), the EPA and the MPCA was entered on April 25, 2001. The Consent Decree contains provisions for the facility’s LDAR program, which will also apply to the new fugitive components in the 44 Unit (FS135) and will require dual seal pumps or equivalent for all new or modified light liquid pumps.

(No. 3 Coker Revision) The Consent Decree required among other things, NOX reductions at existing boilers and process heaters unless they were equipped with ultra-Low NOX Burners (ULNB). The two 23 unit heaters (23H-1 and 23H-2) were equipped with current generation ULNBs upon the effective date of the Consent Decree and therefore are not subject to the Consent Decree.

The new fugitive VOC components will be subject to the facility LDAR program.

NEW SOURCE REVIEW (NSR)/PREVENTION OF SIGNIFICANT DETERIORATION (PSD)

(SWT) The facility is an existing major source under PSD regulations as indicated in Table 5. A PSD applicability analysis was conducted for this project and was determined not to be subject to a PSD review based on an actual to potential test, as defined in 40 CFR 52.21(b)(2); therefore, the Sour Water Tanks Modification Project is not subject to PSD review. The emissions increases from the sour water tank modification/reconstruction project are below PSD applicability thresholds for VOC, H2S and total sulfur. However, the application is considered a major permit amendment due to the NSPS modification/reconstruction analysis identified above.

(MSAT II) The MSAT II Project is not a major modification, as defined in 40 CFR 52.21(b)(2); therefore, the MSAT II Project is not subject to PSD review. FHR is not proposing project specific recordkeeping for any pollutants based on guidance in the reasonable possibility rule.

(No. 3 Coker Revision) The PSD applicability analysis for the revised scope of the No. 3 Coker Drum Replacement Project determined that the emissions changes are not significant under PSD. This is in contrast to the applicability analysis for the October 2007 permit. The analysis for the October 2007 permit determined the proposed change was a PSD major modification due to a significant increase in NOX emissions and the October 2007 permit required BACT for NOX emissions from the 23 unit heaters that were potentially being modified. The revised application submitted in May 2008 contains an applicability analysis that demonstrates that all pollutant increases are minor for the revised scope permit. Furthermore, the projected increases are less than 50% of the significant emission rates and therefore no project-specific recordkeeping is required by 40 CFR §52.21(r)(6) and therefore none is proposed for the revised scope permit amendment.

The revised scope of the No. 3 coker drum replacement project in the May 2008 application shows that emissions increases are due to new fugitive emission sources, and increased utilization of equipment due to 50% larger replacement drums. These units include the sulfur recovery units, hydrogen plants, steam generating units, the 23 unit heaters, the coke pad, the naphtha, distillate, and gas oil hydrotreaters, and associated storage tanks.


PART 70 PERMIT PROGRAM

The facility is a major source under the Part 70 permit program as indicated in Table 5 and is currently operating under an existing Part 70 permit (Air Emission Permit No. 03700011-005). The changes authorized by this major permit amendment are included in the amended Part 70 permit (Air Emission Permit No. 03700011-006) which will supersede the existing Part 70 permit.

NEW SOURCE PERFORMANCE STANDARDS (NSPS)

(SWT) 40 CFR pt. 60, subp. Kb – Standards of Performance for Volatile Organic Liquid Storage Vessels (including Petroleum Liquid Storage Vessels) for which construction, reconstruction or modification commenced after July 23, 1984: Of the emission units involved in this project, the NSPS already applies to TK515. Tanks 367, 368 and 515 are being reconstructed from fixed roof tanks to internal floating roof tanks, thus triggering NSPS subp. Kb applicability and compliance standards. TK367 and TK368 were previously subject to NSPS subp. K (GP032). The sour water tanks involved in this project will also follow the general provisions of 40 CFR pt. 60, subp. A.

(MSAT II) 40 CFR pt. 60, subp. J/Ja – Fuel Gas Combustion Device and Flaring: No new heaters are being installed that would be impacted by these subparts with respect to affected facilities defined as fuel gas combustion devices (FGCD). No existing heaters or boilers are being modified as part of this project. All existing heaters and boilers noted in this permit application are already subject to 40 CFR 60 Subpart J for sulfur dioxide (SO2) emissions, in accordance with paragraph 45.(A.) of the 2001 Consent Decree.

EPA issued the final rule related to NSPS Ja in May 2008. A few conditions were not included in the proposed rule but were later added to the final rule, particularly related to the flare system as an affected facility. There will be tie-ins completed into the flare gas recovery system for this new process unit; however, based on FHR’s understanding of the rule, the Penex tie-ins will be into the flare gas recovery (FGR) system which is defined as a separate process unit which routes to the fuel gas system under the new rule. Therefore, no modification or reconstruction of the flare system is being triggered under NSPS Ja by the addition of pressure relief devices to the FGR system. Even if triggered, NSPS Ja would require good control practices and an emission monitoring system on the flare system. FHR currently utilizes flare gas recovery compressors that have been cited as good control practices in the rule and utilizes alternative methods for monitoring flare gas composition as part of the flaring policy finalized under the Consent Decree.

The changes to the fuel gas system (the tie-ins discussed above) do not constitute modification of reconstruction of that system under Ja. Therefore that system and associated fuel gas combustion devices will remain subject to subpart J and not Ja. NSPS Ja is currently stayed as it relates to the flare system.

(MSAT II) 40 CFR pt. 60, subp. GGGa/VVa – New Fugitive Equipment: With issuance of the No. 2 Crude Metallurgy permit amendment (Permit No. 03700011-005) in August 2008, site-wide applicability under the revised subpart GGGa standards apply rather than subpart GGG. FHR considers new or replaced fugitive “equipment,” as defined in 40 CFR 60.591, that are associated with existing process units to be covered under the facility’s established Leak


Detection and Repair (LDAR) program, which is required under 40 CFR 60 Subpart GGGa (per the amendment being processed). Fugitive equipment associated with new process units for the MSAT II Project trigger construction under Subpart GGGa. All new fugitive equipment being installed as part of this project will be incorporated into the LDAR program and organized under the existing process unit fugitive source (FS) numbers or under the FS number for the new Penex unit.

A specific requirement impacting the new unit under GGGa/VVa, is that the total number of valves designated as difficult-to-monitor (DTM) within the new Penex unit, (and thus exempt from 40 CFR 60.482-7a) will be limited to less than 3% of the total number of valves. This condition is being met through construction specifications and through implementation of the LDAR tagging and monitoring program. Therefore, no additional permit condition is being proposed in the permit.

(MSAT II) 40 CFR pt. 60, subp. QQQ – New Process Drains: Process drains installed for the MSAT II Project are considered affected facilities under NSPS QQQ. Specifically, a small number of new drains (cups with no new junction box) will tie into the facility’s existing process sewer system (likely utilizing the 32-unit minor sump to the north of the new Penex unit). The new cups will be designed with water seal controls required to meet QQQ requirements.

Since the new cups are routed directly to an existing junction box (i.e., no new junction box being installed), that is currently regulated under NSPS QQQ, modification provisions are not triggered. Essentially, the individual drain system (IDS) and aggregate facility (AF) as defined under the regulation for the components connected to this junction box are already regulated under NSPS QQQ. This change essentially expands the existing affected facility under NSPS QQQ.

Therefore, this action is not considered an NSPS modification, and hence no Title I modification is triggered that would require a major permit amendment.

(No. 3 Coker Revision) All existing heaters noted in the permit application are already subject to 40 CFR part 60 Subpart J for SO2 emissions, in accordance with paragraph 45.(A.) of the 2001 Consent Decree. The project does not trigger NSPS Ja for any refinery heaters (no modifications or increase in PTE).

Note: NSPS Ja requires that Delayed Coking Units (DCU) depressurize to less than 5 psi and route exhaust gases to a fuel gas system/flare gas recovery system. While FHR has and will continue to route exhaust gases to a fuel/flare gas system meeting the intent of this rule, FHR had a fully binding contract in place and fabrication in progress on the replacement coke drums prior to the NSPS Ja issuance date of May 14, 2007. Therefore, NSPS Ja is not applicable to this project.

(No. 3 Coker Revision) 40 CFR 60 Subpart GGG & GGGa – New Fugitive Equipment: The Permittee considers new or replaced fugitive “equipment,” as defined in 40 CFR §60.591, that are associated with existing process units to be covered under the facility’s established Leak Detection and Repair (LDAR) program, which is required under 40 CFR 60 Subpart GGG. With issuance of the No. 2 Crude Metallurgy permit amendment (Permit No. 03700011-005) in August 2008, site-wide applicability under the revised subpart GGGa standards apply rather than


subpart GGG. However, fugitive components will also be subject to the requirements of the 2001 Consent Order as well as the consolidated LDAR requirements of the facility’s Title V permit which is consistent with subpart GGGa. The equipment will be incorporated into the LDAR program and organized under the existing process unit.

(No. 3 Coker Revision) 40 CFR 60 Subpart QQQ- New Process Drains: New individual drain systems installed for the No. 3 Coker Drum Replacement Project are affected facilities under NSPS QQQ. These drains and their associated junction boxes will tie into the facility’s existing process sewer system. In accordance with 40 CFR §60.690(b), “the construction or installation of a new individual drain system shall constitute a modification to an affected facility described in §60.690(a)(4). For purposes of this paragraph, a new individual drain system shall be limited to all process drains and the first common junction box.” The Permittee assumes that new individual drain systems (IDS) will be installed and that they trigger subpart QQQ. Also, modifications to existing individual drain systems will be evaluated against the modification and reconstruction provisions of NSPS for applicability under NSPS subpart QQQ.

NATIONAL EMISSION STANDARDS FOR HAZARDOUS AIR POLLUTANTS (NESHAP)

(MSAT II/SWT) The MSAT II project does not include any new emission units subject to Section 112(g) and 112(j) of the Clean Air Act, and therefore, these requirements do not apply to this project. The SWT project is not applicable to Section 112(g) and Section 112(j) requirements are not expected to result in any further action by FHR for the proposed modified sour water tanks.

(SWT) The National Emission Standards for Hazardous Air Pollutants applicable to the sour water tanks project is 40 CFR pt. 63, subp. CC. Sour water tanks TK367 and TK368 are currently subject to 40 CFR pt. 63, subp. CC. The modification from fixed roof to internal floating roof will not change the fact the tanks are still subject to Subpart CC. However, the modification of the tanks will classify the tanks to be subject to 40 CFR pt. 60, subp. Kb. By following the standards of Subpart Kb, the compliance standards of 40 CFR pt. 63, subp. CC will be met, as is currently being done for TK515.

Also 40 CFR pt. 61, subp. FF for Benzene Waste Operations is applied facility wide. In correspondence received by FHR from EPA Region 6 on January 7, 2008, the Agency concluded that the Benzene Waste Operations NESHAP (BWON) rule, 40 CFR pt. 61, subp. FF, applies to sour water streams in the same manner as it applies to other waste streams. Thus, the Agency believes that the BWON regulates sour water streams upstream of the exit of any sour water stripper. FHR (as well as many other refineries) has historically taken the view that BWON requirements apply only downstream of the sour water stripper. FHR believes its position is strongly supported by the rule, as discussed in the November 2, 2006 applicability request letter filed with EPA on FHR’s behalf by Beveridge & Diamond. Therefore, FHR historically has not included streams upstream of the sour water stripper exit in its BWON compliance program. FHR has determined such streams are controlled at this facility, but components and control devices managing such streams have not been subject to any BWON monitoring or compliance demonstration. FHR currently is communicating with Ken Garing and has requested the EPA to reconsider their interpretation as well as issue a clarification of this letter.


The modification being considered with this permit application is independent of this determination. This determination would impact monitoring and recordkeeping associated with sour water management. Although the sour water tanks would be subject to the determination, the controls currently being used and those being proposed both comply with existing requirements under Subpart FF. Furthermore, the applicability determination doesn’t require additional permitting because Subpart FF already is applied facility wide.

(MSAT II) 40 CFR pt. 61, subp. A General Provisions: The determination of whether a source undergoes “construction” or “modification” is not completely clear in the general provisions, which have not changed significantly since 1985. The underlying terms “source”, “stationary source”, and “affected facility” are intermingled within the definitions of “construction” and “modification”. Nevertheless, a strict reading of the general provisions yields that the new components in the Penex Unit trigger construction under Subparts J and V. No other Subpart A implications are triggered with respect to other NESHAPs Part 61 subparts (the facility is currently subject to Subpart FF and will continue to be with this change).

(MSAT II) The National Emission Standards for Hazardous Air Pollutants applicable to the Mobile Source Air Toxics II project are 40 CFR pt. 61, subp. FF which already regulates benzene waste streams for the entire petroleum facility. FHR is already subject to this NESHAP so modification is not triggered. Any new benzene waste streams from the Penex unit will be controlled under the site wide benzene NESHAP compliance system in accordance with the total facility requirements, section J of the Title V permit.

(MSAT II) 40 CFR pt. 61, subp. J/V Equipment Leaks (Fugitive Emission Sources) of Benzene: Each component (i.e., each new valve or connector) that is in benzene service (>10% benzene by weight) is subject to Subpart J (which specifies compliance with the standards defined under V). Currently the facility does not have any components subject to these standards. As noted previously, this project will result in one new line that will be subject to these specific requirements (the 15 splitter overhead routed to the Penex units). The Title V permit currently references Subparts J/V as part of the consolidated LDAR program. Compliance with the facility consolidated LDAR program meets requirements under Subpart V with the addition of one requirement (monthly monitoring for leaks).

(MSAT II) 40 CFR pt. 63, subp. CC Wastewater Streams, Equipment Leaks: Subpart CC already applies to both the isomerate and light naphtha tanks (Group 1) with compliance demonstration being met by current NSPS Kb standards. The current project will not change requirements here. Subpart CC will also apply to the new fugitive equipment (including sewer drains) associated with the MSAT II Project. In order to determine the applicability of existing source provisions or new source provisions to this equipment, FHR has reviewed the applicability requirements of 40 CFR 63.641 to this project. The provisions of 40 CFR 63.641(i) state the following:

“If an additional petroleum refining process unit is added to a plant site that is a major source as defined in section 112(a) of the Clean Air Act, the addition shall be subject to the requirements for a new source if it meets the criteria specified in paragraphs (i)(1) through (i)(3) of this section:


(1) It is an addition that meets the definition of construction in §63.2 of subpart A of this part; (2) Such construction commenced after July 14, 1994; and (3) The addition has the potential to emit 10 tons per year or more of any hazardous air pollutant or 25 tons per year or more of any combination of hazardous air pollutants.”

The criteria in paragraphs (i)(1) and (i)(2) apply to this project. In accordance with paragraph (i)(3), if the additional petroleum refining process unit (PRPU), the Penex Unit, has the potential to emit at least 10 tpy of any HAP or 25 tpy of all HAPs, then the new source provisions of Subpart CC apply. Otherwise, the existing source provisions apply upon startup, as shown below in excerpts from paragraphs (l), (l)(1), (l)(2), and (l)(2)(i).

“(l) If an additional petroleum refining process unit is added to a plant site or if a miscellaneous process vent, storage vessel, gasoline loading rack, or marine tank vessel loading operation that meets the criteria in paragraphs (c)(1) through (c)(7) of this section is added to an existing petroleum facility or if another deliberate operational process change creating an additional Group 1 emission point(s) (as defined in §63.641) is made to an existing petroleum refining process unit, and if the addition or process change is not subject to the new source requirements as determined according to paragraphs (i) or (j) of this section, the requirements in paragraphs (l)(1) through (l)(3) of this section shall apply. Examples of process changes include, but are not limited to, changes in production capacity, or feed or raw material where the change requires construction or physical alteration of the existing equipment or catalyst type, or whenever there is replacement, removal, or addition of recovery equipment … (1) The added emission point(s) and any emission point(s) within the added or changed petroleum refining process unit are subject to the requirements for an existing source. (2) The added emission point(s) and any emission point(s) within the added or changed petroleum refining process unit shall be in compliance with this subpart by the dates specified in paragraphs (l)(2)(i) or (l)(2)(ii) of this section, as applicable. (i) If a petroleum refining process unit is added to a plant site or an emission point(s) is added to any existing petroleum refining process unit, the added emission point(s) shall be in compliance upon initial startup of any added petroleum refining process unit or emission point(s) or by 3 years after the date of promulgation of this subpart, whichever is later …”

Total HAP potential to emit from all new emission sources for the project is less than the 10/25 tpy major source thresholds (see Table 14). Therefore, the affected facilities associated with this project are subject to the existing source provisions of MACT CC. FHR will be required to meet the recordkeeping and reporting requirements of 40 CFR 63.641(l)(3)(i) through (vii).

(MSAT II) 40 CFR pt. 63, subp. UUU Catalytic Cracking and Reforming Units: Subpart UUU regulates catalytic cracking and reforming units. The Penex unit being installed is not considered an affected facility under this subpart.

(No. 3 Coker Revision) Section 112(g) Applicability Review: The Permittee has determined that the new fugitive sources (i.e., pumps, equipment leaks) are already specifically regulated or exempted under a MACT standard issued pursuant to section 112(d). Specifically, 40 CFR part 63 Subpart CC regulates the following emission points at a petroleum facility: miscellaneous


process vents, storage vessels, wastewater streams and treatment operations, equipment leaks (e.g., fugitives), gasoline loading racks, and marine vessel loading operations. Subpart CC covers all new emission points associated with this project (which essentially entails the equipment leaks or fugitives).

(No. 3 Coker Revision) No. 3 Coker Unit Benzene Waste Streams – 40 CFR part 61 Subpart FF: The facility, including the No. 3 Coker Unit, is already an affected facility subject to Subpart FF of 40 CFR part 61 (National Emission Standard for Benzene Waste Operations). The new equipment will comply with Subpart FF as applicable.

(No. 3 Coker Revision) Wastewater Streams and Equipment Leaks – 40 CFR part 63 Subpart CC: Subpart CC will regulate the new sewer drains and downstream equipment, and new fugitive equipment associated with the No. 3 Coker Drum Replacement Project. In order to determine the applicability of existing source provisions or new source provisions to these equipment, Flint Hills Resources has reviewed the applicability requirements of 40 CFR §63.641 to this project. The provisions of 40 CFR §63.641(i) state the following:

“If an additional petroleum refining process unit is added to a plant site that is a major source as defined in section 112(a) of the Clean Air Act, the addition shall be subject to the requirements for a new source if it meets the criteria specified in paragraphs (i)(1) through (i)(3) of this section: (1) It is an addition that meets the definition of construction in §63.2 of subpart A of this part; (2) Such construction commenced after July 14, 1994; and (3) The addition has the potential to emit 10 tons per year or more of any hazardous air pollutant or 25 tons per year or more of any combination of hazardous air pollutants.”

The criteria in paragraphs (i)(1) and (i)(2) apply to this project. In accordance with paragraph (i)(3), if the additional petroleum refining process unit (PRPU), No. 3 Coker Unit, has the potential to emit at least 10 tpy of any HAP or 25 tpy of all HAPs, then the new source provisions of Subpart CC apply. Otherwise, the existing source provisions apply upon startup, as shown below in excerpts from paragraphs (l), (l)(1), (l)(2), and (l)(2)(i).

“(l) If an additional petroleum refining process unit is added to a plant site or if a miscellaneous process vent, storage vessel, gasoline loading rack, or marine tank vessel loading operation that meets the criteria in paragraphs (c)(1) through (c)(7) of this section is added to an existing petroleum refinery or if another deliberate operational process change creating an additional Group 1 emission point(s) (as defined in §63.641) is made to an existing petroleum refining process unit, and if the addition or process change is not subject to the new source requirements as determined according to paragraphs (i) or (j) of this section, the requirements in paragraphs (l)(1) through (l)(3) of this section shall apply. Examples of process changes include, but are not limited to, changes in production capacity, or feed or raw material where the change requires construction or physical alteration of the existing equipment or catalyst type, or whenever there is replacement, removal, or addition of recovery equipment …


(1) The added emission point(s) and any emission point(s) within the added or changed petroleum refining process unit are subject to the requirements for an existing source. (2) The added emission point(s) and any emission point(s) within the added or changed petroleum refining process unit shall be in compliance with this subpart by the dates specified in paragraphs (l)(2)(i) or (l)(2)(ii) of this section, as applicable. (i) If a petroleum refining process unit is added to a plant site or an emission point(s) is added to any existing petroleum refining process unit, the added emission point(s) shall be in compliance upon initial startup of any added petroleum refining process unit or emission point(s) or by 3 years after the date of promulgation of this subpart, whichever is later …”

Table 17 summarizes HAP emissions from all new emission sources for the project. This table shows that total HAP potential to emit from all new emission sources for the project is less than the 10/25 tpy major source thresholds. Therefore, the affected facilities associated with this project are subject to the existing source provisions of Subpart CC. FHR will be required to meet the recordkeeping and reporting requirements of 40 CFR §63.641(l)(3)(i) through (vii).

(No. 3 Coker Revision) Boilers and Process Heaters – Clean Air Act Section 112(j) (for sources formerly subject to part 63 subpart DDDDD): The No. 3 coker heaters are existing sources and are not being modified under the revised scope of the No. 3 Coke Drum Replacement Project. The Permittee has submitted a 112(j) application for case-by-case determination of emission limits and work practice standards as requested by the MPCA.

RISK MANAGEMENT PLAN UPDATE

(No. 3 Coker Revision) The facility is subject to the chemical accident prevention provisions in 40 CFR Part 68, due to the presence of a process containing a regulated substance in an amount exceeding a threshold quantity in §68.115. The Permittee submitted a risk management plan (RMP) to the EPA and to local emergency response agencies in 1999, and the required 5-year RMP update in 2004. The Permittee also submitted an update before the startup of its new hydrocracker.

The No. 3 Coker Unit is a program level 1 RMP process for flammable substances. This project does not significantly change the inventory of regulated substances within the process; therefore, the expansion project will not change the program level or otherwise require an update to the RMP.

STATE IMPLEMENTATION PLAN (SIP) ADMINISTRATIVE ORDER

(No. 3 Coker Revision) The facility operates under an Administrative Order for SO2 emissions. The revised scope of the No. 3 coker drum permit does not change the analysis of the SIP Administrative Order impacts by the October 2007 No. 3 coker drum replacement permit.


ENVIRONMENTAL REVIEW

(No. 3 Coker Revision) Minnesota Rules 4410.4300, Subp 4., requires a mandatory EAW for “expansion of an existing petroleum facility that increases its capacity by 10,000 or more barrels per day.” The mandatory EAW threshold of 10,000 barrels per day of crude capacity will not be exceeded.

Minnesota Rules 4410.4300, Subp. 10(B), requires a mandatory EAW for “construction of a facility…capable of storing 1,000,000 gallons or more of hazardous materials.“ The Permittee now will be replacing existing cutting and cooling water management equipment, including the replacement of a cutting water storage tank as part of the project. The cutting/cooling water managed in these tanks/basins is not considered hazardous material and does not trigger the mandatory EAW.

No other mandatory EAW thresholds are potentially applicable. COMPLIANCE ASSURANCE MONITORING (CAM)

(No. 3 Coker Revision) 40 CFR part 64 Compliance Assurance Monitoring does not apply. Among other reasons, uncontrolled emissions for each of the new and modified emissions sources are below the part 70 major source threshold for each pollutant. MINNESOTA STATE RULES (SWT) Minn. R. 7011.1500 – Minn. R. 7011.1520 Standards of Performance for Liquid Petroleum and Volatile Organic Liquid Storage Vessels applies to TK367, TK368 and TK515. By following the standards of 40 CFR pt. 60, subp. Kb, compliance will be met for the applicable Minnesota rules. (MSAT II) A major permit amendment is required for a new source if it is a “Title I modification” (Minn. R. 7007.1500, subp. 1, item D). The definition of “Title I modification” addresses applicability to a 40 CFR 61 subpart.

- “Title I modification” [Minn. R. 7007.0100, subp. 26] includes under item E: A hazardous air pollutant modification: any modification as defined in Code of Federal Regulations, title 40, section 61.15, as amended, or any other rules adopted by the administrator under section 112 of the Act.

As determined above, the new components are considered construction under 40 CFR 61, not a modification. The individual components regulated by Subparts J and V (i.e. pump or valve) are new sources, not existing sources that have been physically or operationally modified. Therefore, the new Penex Unit is not a Title I modification unless it is triggered by a NSPS or New Source Review (NSR) requirement.

(MSAT II) Risk Management Plan Update: The Pine Bend facility is subject to the chemical accident prevention provisions in 40 CFR pt. 68, since the facility has a process containing a regulated substance present in an amount that exceeds a threshold quantity in §68.115. FHR submitted a risk management plan (RMP) to the EPA and to local emergency response agencies in 1999, and the required 5-year RMP update in 2004. The new unit will likely be a new


covered process under these rules and will likely require an update to the RMP. This will be completed prior to startup of the unit.

(MSAT II) State Implementation Plan (SIP) Administrative Order: The facility is covered by an Administrative Order for SO2 emissions. Section IV of the Order contains provisions for changes at the facility that do not require a modification of the Order. Paragraph A of Section IV reads:

“The Company may install and operate any new sulfur dioxide process or control equipment with a maximum potential sulfur dioxide emissions rate that does not exceed 2.28 pounds per hour, except as expressly allowed elsewhere in this part (Part IV.) …”

The MSAT II Project does not contain any new SO2 emission source that has a potential to emit SO2. Therefore, no amendments to the SIP are required.

(MSAT II) Minnesota Standards for Stationary Sources: Minnesota Rules 7011.1400 through 7011.1435 contains state standards of performance for existing and new affected facilities at petroleum refineries and incorporates relevant NSPS for petroleum facility equipment. None of the equipment being considered for the MSAT II project falls within these standards.

(NOX Test - Nos. 1, 2, and 3 Coker Heaters) Minn. R. 7017.2020, subp. 1 Performance Tests General Requirements; Minn. R. 7019.3050, item C Performance Test Data; Minn. R. 7007.0800, subp. 2 Emissions Limitations and Standards. The MPCA has determined that Minn. R. 7017.2025 is an inappropriate citation for the duty limits on the three coker heaters because testing is required for NOX emission factor development and determination of the emission factor threshold, and not for NOX emissions compliance determination. These citations are changed to Minn. R. 7007.0800, subp. 2 for these emission factor thresholds.

(No. 3 Coker Revision) No new sources are proposed as part of the scope revision to the No. 3 coker drum replacement permit. Therefore there are no changes to the applicability discussion of Minnesota Standards of Performance for the No. 3 coker revision permit in the October 2007 permit technical support document.


Table 11. Regulatory Overview of the Major & Minor Amendment (SWT/MSAT II) Subject

Item Applicable Regulations Comments:

GP039 40 CFR pt. 60, subps. A, Kb

Minn. R. 7011.1520, subp. C Standards of Performance for volatile organic liquid storage vessels (including petroleum liquid storage vessels) for which construction, reconstruction or modification commenced after July 23, 1984

GP042 40 CFR pt. 63, subp. CC Minn. R. 7011.7280, subp. A

National Emission Standards for Hazardous Air Pollutants from Petroleum Refineries

GP046 Minn. R. 7011.1500 – Minn. R. 7011.1520

Standards for Stationary Sources: Liquid Petroleum & Volatile Organic Liquid Storage Vessels

FS027, FS048, FS135

40 CFR pt. 60, subp. GGGa Minn. R. 7011.1435 item B

Standards of Performance for Equipment Leaks of VOC in petroleum refineries for which construction, reconstruction or modification commenced after November 7, 2006 (This NSPS was implemented site wide via permit action -005)

FS027, FS048, FS135

40 CFR pt. 60, subp. VVa (only as referenced by 40 CFR pt. 60, subp. GGGa)

Standards of Performance for Equipment Leaks of VOC in the synthetic organic chemicals manufacturing industry for which construction, reconstruction or modification commenced after November 7, 2006 (This NSPS was implemented site wide via permit action -005)

FS027, FS048, FS135

40 CFR pt. 60, subp. QQQ Minn. R. 7011.1435 item C 40 CFR pt. 61, subp. A

Standards of Performance for VOC Emissions from Petroleum Facility Wastewater Systems General Provisions

GP039, GP042, GP046, FS027, FS048, FS135

40 CFR pt. 61, subp. FF National Emission Standard for Benzene Waste Operations (site wide)

FS027, FS135

40 CFR pt. 61, subps. J/V National Emission Standard for Equipment Leaks (Fugitive Emission Sources) of Benzene National Emission Standard for Equipment Leaks (Fugitive Emission Sources)

(SWT) TK367 & TK368 are moving from GP032 & GP043 into GP039 & GP042 as they are being reconstructed to meet best practice standards NSPS subp. Kb. Both tanks are currently in GP046.

TK515 is moving from GP025 to GP039. TK515 is currently in GP042 & GP046.

(MSAT II) FS135 is a new unit (Penex, 44 Unit). FS027 (15 Unit) and FS048 (25 Unit) are being modified.


FS135 will be associated with the following Groups at FHR: GP067, GP069, GP071, GP072, GP087, GP090, GP091, GP095, GP096, GP099, GP100, GP101, GP109 and GP114. (FS135 is not being placed in GP080, though storm sewers in the 44 Unit will comply with the GP080 requirement.)

Table 12. Regulatory Overview of Units Affected by the Modification/Permit Amendment (No. 3 Coker Revision)

Subject Item

Applicable Regulations Comments:

FS 027 FS 045 FS 109

40 CFR 60 Subpart GGG & GGGa; 2001 Consent Decree 40 CFR pt. 63, subp. CC

Standards of Performance for Equipment Leaks of VOC in Petroleum Refineries. Applicable components added by this project will be subject to the requirements of this standard which are already contained in the existing permit. NESHAP for Petroleum Refineries. Affected equipment added or replaced with this project will be subject to the requirements of this standard that are already contained in the existing permit.

FS 027

40 CFR 61 Subparts J/V

NESHAP for Equipment Leaks (Fugitive Emission Sources) of Benzene & NESHAP for Equipment Leaks (Fugitive Emission Sources) Valves and connectors in VHAP service (>10% benzene by weight) with this FS unit are subject to these NESHAPs.

FS 027 FS 045

40 CFR 60 Subpart QQQ 40 CFR pt. 61, subp. FF

Standards of Performance for VOC Emissions From Petroleum Refinery Wastewater Systems. Standards of Performance for VOC Emissions from Petroleum Refinery Wastewater Systems. New individual drain systems added by this project will be subject to the requirements of this standard as currently contained in the existing permit. New drain cups on existing individual drain systems will be subject to the standard if modification or reconstruction provisions are triggered by the changes. National Emission Standard for Benzene Waste Operations. Affected sources added or replaced with this project will be subject to the requirements of this standard that are already contained in the existing permit.

EU 034 EU 035 EU 050 EU 051

CAA Section 112(j) (for sources formerly subject to subpart DDDDD)

The boiler and process heaters are existing sources subject to section 112(j) due to the vacature of part 63, subp. DDDDD. The Permittee has submitted an application for


Subject Item

Applicable Regulations Comments:

EU 052 EU 053 EU 102 EU 103 EU 104 EU 204

a case-by-case determination of emission limits.

GP 112 40 CFR §52.21 Limits to avoid significant emissions increases and avoid PSD

EU 034, EU 035

40 CFR §52.21 PSD no longer applies for the NOX increases at these coker heaters because emission increases are less than significant due to the revision in the coker drum replacement project scope. All PSD-based requirements add to the permit by permit No. 03700011-004 have been removed.

3. Technical Information

3.1 Emission Calculations (SWT) Potential-to-emit calculations for the Sour Water Tanks project are in an attached spreadsheet. A summary of the emissions increases is shown below in Table 13.

Table 13. Emissions Increases from Sour Water Tanks Project PM PM10 SO2 NOx VOC CO Pb H2S TRS Unit (tpy) (tpy) (tpy) (tpy) (tpy) (tpy) (tpy) (tpy) (tpy) TK-367 3.38 0.004 0.08TK-368 3.38 0.004 0.08TK-515 3.96 0.004 0.10Total Increase (tpy) 0.0 0.0 0.0 0.0 10.73* 0.0 0.0 0.012 0.26PSD Significant Rate 25.0 15.0 40.0 40.0 40.0 100.0 0.6 10.0 10.0H2S: Hydrogen Sulfide; TRS: Total Reduced Sulfur including H2S *10.73 tpy VOC = 21464.89 lb/yr VOC * 1ton/2000lb = 10.73 tpy

3.2 Emission Calculations (MSAT II)

The tables below summarize the emissions increases involved with the Mobile Source Air Toxics II (MSAT II) project. A more detailed discussion of the emissions increases is attached to this TSD.

Non-modified Units Experiencing Increased Utilization: A comprehensive review was conducted to determine the impacts of the MSAT II Project on existing, non-modified emission units at the refinery. This review includes increased utilization of the following units: EU052, EU268, EU313 and TK011. These units’ emissions based on increased utilization were compared to PSD significance thresholds and the results are shown in Table 16. Actual utilization increases can and will vary depending on a variety of operating factors. The emission units listed have been permitted to their potentials in prior permitting action.

Table 14. HAP Emissions Calculations for FS027, FS048 & FS135 (MSAT)


These new sources use the same HAP emission factors; emissions from them are combined into a single table.

Volatile HAP Max Emission Factor

Max hourly use

Max HAP Emission Rate

Max Unc. HAP

Emissions

Max Cont. HAP Emissions

lb HAP/lb VOC

VOC (tpy) (lbs/hr) (tpy) (tpy)

Benzene 2.66E-03 29.00 0.018 0.077 0.077Ethyl Benzene 1.62E-02 29.00 0.107 0.470 0.470Naphthalene 6.24E-03 29.00 0.041 0.181 0.181Hexane 3.70E-02 29.00 0.245 1.073 1.073Toluene 5.12E-02 29.00 0.339 1.485 1.485Xylene 9.77E-02 29.00 0.647 2.833 2.833Polycyclic Organic Matter 1.41E-02 29.00 0.093 0.409 0.409Biphenyl 5.90E-04 29.00 0.004 0.017 0.017 Total 6.545

Table 15. Fugitive VOC Emissions Calculations for FS027, FS048 & FS135 (MSAT)

Fugitive Source E.F. (lbs/hr)

Qty Emis. Rate

(lbs/hr)

Max. Unc. Emis. (tpy)

Max. Cont. Emis. (tpy)

Valves (gas) 3.51E-4 0 0.00 0.00 0.00 Valves (light liquid) 2.78E-4 2097 1.45 6.37 6.37 Valves (heavy liquid) 1.79E-4 0 0.00 0.00 0.00 Pump Seals (light liquid) 3.38E-3 19 0.19 0.81 0.81 Pump Seals (heavy liquid) 8.29E-3 0 0.00 0.00 0.00 Compressor Seals (gas) 3.74E-4 Press. Relief Valves/Seals (gas)

4.13E-4 (6.22E-5)

0 0.00 0.00 0.00

Connectors/Flanges (all) 1.40E-4 (8.16E-5)

4769 4.92 21.55 21.55

Open-Ended Lines (all) 0 Sampling Connections (all) 0 Drain Cups and Junction Boxes

3.40E-3 18 0.06 0.27 0.27

Total 29.00

Project Emission Increases and Comparison to PSD Significance Thresholds

Table 16. MSAT II Project Emissions vs. PSD Significant Emission Rate Unit Em. PM PM10 PM2.5 SO2 NOX VOC CO Pb


New/Modified Units

Meth. (tpy) (tpy) (tpy) (tpy) (tpy) (tpy) (tpy) (tpy)

FS-135; 44 Unit ATP 26.9 FS-048; 25 Unit ATP 1.1 FS-027; 15 Unit ATP 1.0 Non-modified Units

EU-052; 27H1 ATPA 0.5 1.0 1.0 8.7 11.1 1.5 0.5 8.6 E-5EU-268; 81CT1 ATPA 0.8 0.4 0.4 0.3 EU-313; B9 ATPA 2.0 2.0 2.0 3.3 11.8 1.4 21.7 1.3 E-4TK-011; TK11 ATPA 0.9 Emissions Increase 3.3 3.4 3.4 12.0 22.9 33.1 22.2 2.2 E-4PSD Significant Rate

25.0 15.0 10.0 40.0 40.0 40.0 100.0 6.0 E-1

ATP: Actual to Potential; ATPA: Actual to Projected Actual

3.3 Emission Calculations (No. 3 Coker Drum Scope Revision)

Table 17. No. 3 Coker Revision HAP Emissions Calculations for FS 027, FS 045 & FS 109

HAP Emission Factor

lb. HAP/

Maximum Annual VOC

Maximum HAP

Emission Rate

Maximum Uncontrolled

HAP Emissions

Maximum Controlled

HAP Emissions

lb. VOC (tons/yr) (lbs/hr) (tons/yr) (tons/yr) Benzene 2.66E-3 6.0 0.004 0.016 0.016 Ethyl Benzene 1.62E-2 6.0 0.022 0.096 0.096 Naphthalene 6.24E-3 6.0 0.008 0.037 0.037 Hexane 3.70E-2 6.0 0.050 0.220 0.220 Toluene 5.12E-2 6.0 0.070 0.305 0.305 Xylenes 9.77E-2 6.0 0.133 0.582 0.582 Polycyclic Organic Matter 1.41E-2 6.0 0.019 0.084 0.084 Biphenyl 5.90E-4 6.0 0.001 0.004 0.004 Total 1.344

Table 18. No. 3 Coker Revision Fugitive VOC Emissions Calculations for FS 027, FS 045 & FS 109


Fugitive Source

Emission Factor

Quantity Emission Rate

Maximum Uncontrolled

Emissions

Maximum Controlled Emissions

(lbs/hr) (lbs/hr) (tons/yr) (tons/yr) Valves (gas) 3.51E-04 210 0.15 0.64 0.64 Valves (light liquid) 2.78E-04 165 0.11 0.50 0.50 Valves (heavy liquid) 1.79E-04 45 0.03 0.14 0.14 Pump Seals (light liquid) 3.38E-03 4 0.04 0.16 0.16 Pump Seals (heavy liquid) 8.29E-03 0 Compressor Seals (gas) 3.74E-04 2 0.003 0.01 0.01 Press. Relief Valves/Seals (gas)

4.13E-04 (6.22E-05)1

5 0.01 0.03 0.03

Connectors/Flanges (all) 1.40E-04 (8.16E-05)1

944 0.97 4.26 4.26

Open-Ended Lines (all) 0 Sampling Connections (all) 0 Drain Cups & Junction Boxes 3.40E-03 14 0.05 0.21 0.21 Total 6.0

1Parenthetical factors are for heavy liquids.

The delta permit database tracks fugitive VOC emissions under GP 005 (Process Fugitive Emissions from the Total Facility). The delta emissions data was revised by the addition of Table 15 and Table 18 VOC emissions data to GP 005.

3.4 No. 3 Coker Drum Replacement Revised PSD Analysis

The May 2008 permit application for revision of the No. 3 Coker Drum Replacement project contains an updated PSD analysis. The revised analysis uses the ‘hybrid test’ to calculate relevant emission changes, as was done for the original October 2007 permit.

The revised analysis includes additional new fugitive emissions from compressors added to FS 109 that were not in the original October 2007 permit analysis. The revised analysis also removes the emission increases for the No. 3 coker heaters (because they will not be modified) and revamps the list of sources that will experience increased utilization from the 1500 bpd increase in the No. 3 coker due to the larger replacement coke drums. A summary of the analysis changes are shown below in Table 19.

Table 19. No. 3 Coker Drum Replacement PSD Analysis Revisions


Source Description

MPCA EU/SV FHR EU/SV Included in Original

Analysis?

Included in Revised Analysis?

NEW EMISSION SOURCES FS 027/NA FS-15UNIT/NA Yes Yes New Process Fugitive

Components in VOC Service FS 045/NA FS-23UNIT/NA Yes Yes

New Flare Gas Recovery Compressors & Vessels

FS 109/NA FS-84UNIT/NA No Yes

MODIFIED EMISSION SOURCES No. 3 Coker Charge Heater (23H-1) EU 034/SV 032 EU-23H1/SV-23H1

No. 3 Coker Charge Heater (23H-2) EU 035/SV 033 EU-23H2/SV-23H2

Yes; larger drums installed and emission units modified

see below

Fuel Gas System GP 116 Yes, modified No, and not modifiedCoke Pile Storage Pad FS 009 Yes, and source

modified No, and source not modified

SOURCES ONLY EXPERIENCING INCREASED UTILIZATION No. 3 Coker Charge Heater (23H-1) EU 034/SV 032 EU-23H1/SV-23H1

No. 3 Coker Charge Heater (23H-2) EU 035/SV 033 EU-23H2/SV-23H2

see above

Yes; larger drums installed but emission units (heaters) not modified

Related SRU Increase GP 112/NA (EU 111 EU 235 EU 236 EU 237 EU 260 EU 261 EU 262)

Various SRUs/NA Yes Yes

Related 38 GOHT Heaters (38H-2, 38H-1A, 38H-1B)

EU 102/SV 087 EU 103/SV 088 EU 104/SV 089

EU-38H2/SV-38H2 EU-38H1A/SV-38H1A EU-38H1B/SV 38H1B

No Yes

Related 27 DHT Heaters (27H-101, 27H-102)

EU 050/SV 044 EU 051/SV 045

EU-27H101/SV-27H101 EU-27H102/SV-27H102

No Yes

Related 28 NHT Heater (28H-1)

EU 053/SV 047 EU-28H-1/SV-28H-1 No Yes

Related Steam Demand (71B-8)

EU 204/SV 132 EU-71B8/SV-71B8 No Yes

Related No. 2 H2 Plant Demand (27H-1)

EU 052/SV 046 EU-27H1/SV-27H1 No Yes

31-5 Unit Desulfurizer EU 056/SV 050 EU 058/SV 052

EU-31H4/SV-31H4 EU-31H7/SV-31H7

Yes No

33 Unit GOHT Heaters EU 084/SV 074 EU 085/SV 075

EU-33H31/SV-33H31 EU-33H32/SV-33H32

Yes No

Merox Incinerator EU 245/SV 078 EU-34H3/SV-34H3 Yes No Related Storage Tanks Various GPs Yes Yes

Baseline Emission Calculations: In the application for the October 2007 No. 3 coker drum replacement permit, the Permittee determined SO2 baseline actual emissions for all existing


sources using the period of July 1, 2000, through June 30, 2002. For all other pollutants, a baseline period of January 1, 2004, through December 31, 2005 was used.

For the No. 3 coker drum replacement scope revision, the Permittee elected to use the 24-month period from January 1, 2006, through December 31, 2007, for all pollutants. According to the Permittee, this revised baseline period for all regulated NSR pollutants emitted from all existing emission units impacted by the No. 3 Coker Drum Replacement Project is conservative because it is most representative of past and current capabilities of units being affected by the scope revision permit for those pollutants.

Non-modified Units Experiencing Increased Utilization: In the No. 3 coker drum replacement revised scope permit application, the Permittee states considerable flexibility exists in shifting feed/demand to/from alternate units. As a result they chose to highlight specific emission units in the PSD analysis based on normal operation/design line-ups, current operating rates versus capacity, and the conservative use of the higher emission factors associated with units when possible. An example includes allocating the emissions associated with additional steam demand to boiler #8 because it has the least modern burners and thus the worst case NOX emissions. Actual utilization increases can and will vary depending on a variety of operating factors. Most, if not all, of the emission units under consideration have been permitted to their potentials in prior permitting action.

Table 19 shows the changes made by the Permittee in the sources used in the original and revised PSD analyses for the No. 3 coker drum replacement project. 3.5 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 considers the following:

• The likelihood of 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 20 summarizes the periodic monitoring requirements for those emission units for which the monitoring required by the applicable requirement is nonexistent or inadequate.


Table 20. Periodic Monitoring (SWT/MSAT II/No. 3 Coker Drum Revision)

Emission Unit or Group

Requirement (basis)

Additional Monitoring

Discussion

GP 042 40 CFR pt. 63, subp. CC

None By following the standards of 40 CFR pt. 60, subp. Kb, compliance will be met for 40 CFR pt. 63, subp. CC

GP 082 (FS 109)

40 CFR pt. 70 (consolidated LDAR requirements based on various applicable provisions of 40 CFR pt. 60, subps. A and GGGa; 40 CFR pt. 61, subps. A, J and V; 40 CFR pt. 63, subps. A and CC; Clean Fuels Permit (106A-92-I/O-32))

None These fugitive sources and equipment units are subject to these subparts through the facility’s consolidated Leak Detection and Repair (LDAR) program.

FS027 FS048 FS135

40 CFR pt. 60, subps. A, GGGa 40 CFR pt. 61 subps. A, J, V & 40 CFR pt. 63 subps. A, CC

None These fugitive sources and equipment units are subject to these subparts through the facility’s consolidated Leak Detection and Repair (LDAR) program.

FS 027 FS 135

40 CFR pt. 61, subps. J & V

None Monthly monitoring of components subject to this Subpart.

3.6 Insignificant Activities

FHR did not list any new operations associated with this permit amendment (SWT, MSAT II, NOX Test Extension or No. 3 Coker Drum Replacement Scope Revision) that are classified as insignificant activities.

3.7 Permit Organization

In general, the permit meets the MPCA Delta Guidance for ordering 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 tracked (e.g., limits, submittals, etc.), should be in Table A or B. The main


reason is that the appendices are word processing sections and are not part of the 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.

3.8 Comments Received

Public Notice Period: December 5, 2008 – January 5, 2009 EPA 45-day Review Period: December 5, 2008 – January 20, 2009 No comments were received from the public during the public notice period or from EPA during their review period. No changes were made to the draft permit.

4. Conclusion

Based on the information provided by Flint Hills Resources, LP, the MPCA has reasonable assurance that the proposed operation of the emission facility, as described in the Air Emission Permit No. 03700011-006 and this technical support document, will not cause or contribute to a violation of applicable federal regulations and Minnesota Rules. Staff Members on Permit Team: Marshall Cole (permit writer/engineer)

Tarik Hanafy (permit writer/engineer) Cary Hernandez (enforcement) Curtis Stock (stack testing)

Amrill Okonkwo (peer reviewer) AQ File No. 106A; DQ 2077 (Incorporates DQ 1817, 1969, 2102, 2193, 2247) Attachments: 1. Facility Description and CD-01 Forms (as appropriate) 2. Revised Coker No. 3 Calculations 3. Sour Water Tanks Calculations 4. Mobile Source Air Toxics II Calculations 5. PER 006 CD-01 Changes

Date post:	07-Sep-2020
Category:	Documents
Upload:	others
View:	2 times
Download:	0 times

AIR EMISSION PERMIT NO. 03700011-006 Major ......25 GP 037 NSPS IFR Tank/Basin subject to NESHAPs FF...

Documents