DOCSLIB.ORG

Arizona Clean Fuels Yuma, Llc

Total Page：16

File Type：pdf, Size：1020Kb

Download full-text PDF Read full-text
Arizona Clean Fuels Yuma, Llc TECHNICAL SUPPORT DOCUMENT AND STATEMENT OF BASIS FOR CONSTRUCTION OF ARIZONA CLEAN FUELS YUMA, LLC PETROLEUM REFINERY Permit Number 40140 September 15, 2006 TABLE OF CONTENTS I. INTRODUCTION ......................................................1 A. Company Information.............................................2 B. Attainment Classification..........................................2 II. PROCESS DESCRIPTION ..............................................2 A. Crude Distillation Unit ............................................5 B. Gas Concentration Plant ..........................................6 C. Hydrocracker Unit ...............................................6 D. Naphtha Hydrotreater Unit ........................................7 E. Catalytic Reforming Unit ..........................................8 F. Isomerization Unit ...............................................9 G. Distillate Hydrotreater Unit ........................................9 H. Butane Conversion Unit ..........................................10 I. Benzene Reduction Unit ..........................................11 J. Delayed Coking Unit .............................................12 K. Petroleum Coke Storage, Handling, and Loading .....................12 L. Amine Regeneration Unit .........................................13 M. Sour Water Stripper .............................................13 N. Sulfur Recovery Plant ...........................................13 O. Hydrogen Plant .................................................15 P. Group “A” Storage Tanks ........................................15 Q. Group “B” Storage Tanks ........................................16 R. Group “D” Storage Tanks ........................................16 S. Group “E” Storage Tank .........................................16 T. Truck and Rail Car Loading Racks ................................16 U. Benzene Waste Operation ........................................17 V. Wastewater Treatment Plant ......................................17 W. Equipment Leaks ...............................................19 X. Emergency Flares ...............................................19 Y. Steam Boilers ...................................................20 Z. Cooling Tower ..................................................20 AA. Internal Combustion Engines .....................................20 BB. Mobile Sources and Fugitive Dust Sources ..........................21 III. EMISSIONS ..........................................................22 A. General........................................................22 B. Process Heaters .................................................27 C. Boilers.........................................................33 D. Sulfur Recovery Plant............................................35 E. Group “B” Storage Tanks and Tank Farm Thermal Oxidizer...........37 F. Wastewater Treatment Plant......................................45 G. Truck and Rail Car Loading Racks.................................48 H. Sour Water Tank................................................52 I. Emergency Flares ...............................................54 J. Coke Silo Baghouse..............................................56 Arizona Clean Fuels Yuma, LLC Permit Number 40140i September 15, 2006 K. Spray Dryer Baghouse............................................57 L. Catalyst Regenerators............................................58 M. Cooling Tower ..................................................61 N. Equipment Leaks................................................64 O. Internal Combustion Engine......................................130 P. Vehicle Traffic on Paved Areas ...................................132 IV. REGULATORY APPLICABILITY .....................................134 A. Permit Regulations .............................................134 1. Class I Permit............................................134 2. Nonattainment New Source Review ..........................134 3. Prevention of Significant Deterioration.......................134 B. New Source Performance Standards (NSPS) ........................135 1. 40 CFR 60 Subpart A, General Provisions ....................135 2. 40 CFR 60 Subpart D, Fossil-Fuel-Fired Steam Generators ......136 3. 40 CFR 60 Subpart Da, Electric Utility Steam Generating Units . 136 4. 40 CFR 60 Subpart Db, Industrial-Commercial-Institutional Steam Generating Units .........................................136 5. 40 CFR 60 Subpart Dc, Small Industrial-Commercial-Institutional Steam Generating Units ...................................136 6. 40 CFR 60 Subpart J, Petroleum Refineries ...................137 7. 40 CFR 60 Subpart Kb, Volatile Organic Liquid Storage Vessels ........................................................137 8. 40 CFR 60 Subpart UU, Asphalt Processing ...................138 9. 40 CFR 60 Subpart VV, Synthetic Organic Chemicals Manufacturing Industry (SOCMI) Equipment Leaks ........................139 10. 40 CFR 60 Subpart XX, Bulk Gasoline Terminals ..............139 11. 40 CFR 60 Subpart GGG, Equipment Leaks of VOC in Petroleum Refineries ...............................................139 12. 40 CFR 60 Subpart NNN, VOC Emissions from SOCMI Distillation Operations ..............................................139 13. 40 CFR 60 Subpart QQQ, VOC Emissions from Petroleum Refinery Wastewater Systems ......................................140 14. 40 CFR 60 Subpart RRR, VOC Emissions from SOCMI Reactor Processes................................................140 C. National Emission Standards for Hazardous Air Pollutants (NESHAP) . 141 1. 40 CFR 61 Subpart A, General Provisions ....................141 2. 40 CFR 61 Subpart FF, Benzene Waste Operations ............141 3. 40 CFR 63 Subpart A, General Provisions ....................142 4. 40 CFR 63 Subpart B, Control Technology Determinations for Major Sources in Accordance with Clean Air Act §§ 112(g) and 112(j) . 143 5. 40 CFR 63 Subparts F and G, SOCMI Process Units ...........144 6. 40 CFR 63 Subpart H, Equipment Leaks .....................144 7. 40 CFR 63 Subpart R, Gasoline Distribution Facilities ..........144 8. 40 CFR 63 Subpart CC, Petroleum Refineries .................144 9. 40 CFR 63 Subpart UUU, Petroleum Refinery Catalytic Cracking Units, Arizona Clean Fuels Yuma, LLC Permit Number 40140ii September 15, 2006 Catalytic Reforming Units, and Sulfur Recovery Units..........147 10. 40 CFR 63 Subpart EEEE, Organic Liquids Distribution (Non-Gasoline) ........................................................148 11. 40 CFR 63 Subpart ZZZZ, Stationary Reciprocating Internal Combustion Engines ......................................148 12. 40 CFR 63 Subpart DDDDD, Industrial Boilers and Process Heaters ........................................................149 D. Arizona Administrative Code.....................................149 1. A.A.C. R18-2-602, Open Burning ............................149 2. A.A.C. R18-2-604, Open Areas, Dry Washes, or Riverbeds ......149 3. A.A.C. R18-2-605, Roadways and Streets .....................149 4. A.A.C. R18-2-606, Material Handling ........................150 5. A.A.C. R18-2-607, Storage Piles .............................150 6. A.A.C. R18-2-612, Opacity of Emissions from Nonpoint Sources ........................................................150 7. A.A.C. R18-2-702, General Provisions for Existing Point Sources ........................................................150 8. A.A.C. R18-2-703, Steam Generators and Fuel-Burning Equipment ........................................................150 9. A.A.C. R18-2-704, Incinerators .............................151 10. A.A.C. R18-2-709, Petroleum Refineries ......................151 11. A.A.C. R18-2-710, Petroleum Liquid Storage Vessels ...........151 12. A.A.C. R18-2-719, Stationary Rotating Machinery .............151 13. A.A.C. R18-2-724, Fossil-fuel Fired Equipment ................152 14. A.A.C. R18-2-726, Sandblasting Operations ...................152 15. A.A.C. R18-2-727, Spray Painting Operations .................152 16. A.A.C. R18-2-730, Unclassified Sources ......................152 17. A.A.C. R18-2-801, General Provisions for Mobile Sources .......152 18. A.A.C. R18-2-802, Off-Road Machinery ......................153 19. A.A.C. R18-2-804, Roadway and Site-Cleaning Machinery ......153 20. Article 9, New Source Performance Standards .................153 21. Article 11, Federal Hazardous Air Pollutants ..................153 E. Compliance Assurance Monitoring................................153 V. CONTROL TECHNOLOGY ANALYSES ................................156 A. General.......................................................156 1. Best Available Control Technology ..........................156 2. Maximum Achievable Control Technology....................159 B. Boilers and Process Heaters ......................................159 1. BACT for Particulate Matter...............................159 2. BACT for Sulfur Dioxide ..................................161 3. BACT for Nitrogen Oxides ................................162 4. BACT for Carbon Monoxide ...............................171 5. BACT for Volatile Organic Compounds .....................172 C. Sulfur Recovery Units...........................................173 1. BACT for Sulfur Dioxide ..................................174 Arizona Clean Fuels Yuma, LLC Permit Number 40140iii September 15, 2006 2. BACT for Reduced Sulfur Compounds ......................180 3. BACT for Nitrogen Oxides ................................181 D. BACT for Sulfur Pits............................................182
Load more

Recommended publications
  • Hydrocarbon Processing®
    HYDROCARBON PROCESSING® 2012 Gas Processes Handbook HOME PROCESSES INDEX COMPANY INDEX Sponsors: SRTTA HYDROCARBON PROCESSING® 2012 Gas Processes Handbook HOME PROCESSES INDEX COMPANY INDEX Sponsors: Hydrocarbon Processing’s Gas Processes 2012 handbook showcases recent advances in licensed technologies for gas processing, particularly in the area of liquefied natural gas (LNG). The LNG industry is poised to expand worldwide as new natural gas discoveries and production technologies compliment increasing demand for gas as a low-emissions fuel. With the discovery of new reserves come new challenges, such as how to treat gas produced from shale rock—a topic of particular interest for the growing shale gas industry in the US. The Gas Processes 2012 handbook addresses this technology topic and updates many others. The handbook includes new technologies for shale gas treating, synthesis gas production and treating, LNG and NGL production, hydrogen generation, and others. Additional technology topics covered include drying, gas treating, liquid treating, effluent cleanup and sulfur removal. To maintain as complete a listing as possible, the Gas Processes 2012 handbook is available on CD-ROM and at our website for paid subscribers. Additional copies may be ordered from our website. Photo: Lurgi’s synthesis gas complex in Malaysia. Photo courtesy of Air Liquide Global E&C Solutions. Please read the TERMS AND CONDITIONS carefully before using this interactive CD-ROM. Using the CD-ROM or the enclosed files indicates your acceptance of the terms and conditions. www.HydrocarbonProcessing.com HYDROCARBON PROCESSING® 2012 Gas Processes Handbook HOME PROCESSES INDEX COMPANY INDEX Sponsors: Terms and Conditions Gulf Publishing Company provides this program and licenses its use throughout the Some states do not allow the exclusion of implied warranties, so the above exclu- world.
    [Show full text]
  • Geothermal Steam Economic H2S Abatement and Sulfur Recovery
    Proceedings World Geothermal Congress 2005 Antalya, Turkey, 24-29 April 2005 Geothermal Steam Economic H2S Abatement and Sulphur Recovery Wayne D. Monnery Xergy Processing Inc., Calgary, Alberta, Canada [email protected] Keywords: H2S abatement the H2S quantity is above about 100 – 200 kg/d due to the high operating cost associated with replacement and ABSTRACT disposal of the non-regenerable chemical. A serious problem that occurs in geothermal steam power projects is the emission of hydrogen sulfide. This problem 1.2 New H2S Abatement Technology is not easily rectifiable and as a result, the geothermal steam industry has a need for H2S abatement technology that is In the geothermal industry, most of the same technology as suitable and economic for use in geothermal steam the petroleum industry has been considered as well as facilities. Current technology has proven to have high limestone-gypsum technology. Unfortunately, existing capital and/or operating costs and some processes are technology has shown to have relatively high capital and difficult to operate. operating costs and often produces byproducts (waste streams) and poor quality products that are difficult and In answer to the requirement for new technology and for expensive to dispose of (Nagl, 2003; Takahashi and companies to be environmentally responsible, Xergy Kuragaki, 2000). Processing Inc. has developed a gas phase direct oxidation process for treating H2S in the range of 0.1 to 20 t/d which As a result, there is a need for a technology with lower has several applications. The process is ideally suited for capital and operating costs that produces a saleable quality H2S abatement in geothermal power processes.
    [Show full text]
  • Gas Processes Handbook - 2004
    Premier sponsor: Main Menu P r ocess Categories Gas Processes 2004 Index Contributor Index Gas Processes Articles Main Menu Gas Processes Handbook - 2004 Hydrocarbon Processing’s Gas Processes Handbooks have helped to provide the Process Categories natural gas industry with the process • technology necessary for drying, treating, NGL, LNG, liquid treating and sulfur • Gas Processes 2004 Index removal. In a further expansion of the technology presented we also provide Contributor Index hydrogen generation, gas effluent cleanup • and flue gas treatment. In the interest of maintaining as complete listings as possi- Gas Processes Articles ble, the 2004 Gas Processes Handbook is • available on CD-Rom only. Additional copies may be ordered from our website. • Gas Processing Company Equipment & Services Gulf Publishing Company PROGRAM LICENSE AGREEMENT YOU SHOULD READ THE TERMS AND CONDITIONS CAREFULLY BEFORE USING THIS APPLICATION. INSTALLING THE PROGRAM INDICATES YOUR ACCEPTANCE OF THESE TERMS AND CONDITIONS. CLICK HERE TO READ THE TERMS AND CONDITIONS Premier sponsor: Main Menu P r ocess Categories Gas Processes Index Contributor Index Gas Processes Articles License agreement Gas Processes Handbook - 2004 Gulf Publishing Company provides this program and licenses its use through- tion of this agreement. You agree upon such termination to destroy the pro- LIMITATIONS OF REMEDIES AND LIABILITY out the world. You assume responsibility for the selection of the program to gram together with all copies. achieve your intended results, and for the
    [Show full text]
  • (12) United States Patent (10) Patent No.: US 7,060,233 B1 Srinivas Et Al
    USOO7060233B1 (12) United States Patent (10) Patent No.: US 7,060,233 B1 Srinivas et al. (45) Date of Patent: Jun. 13, 2006 (54) PROCESS FOR THE SIMULTANEOUS 4,444,908 A 4, 1984 Hass et al. .................. 5O2.247 REMOVAL OF SULFUR AND MERCURY 4,508,699 A 4, 1985 Schoofs ............ ... 423,574 R 4,519,992 A 5/1985 Alkhazov et al. ........... 423 230 (75) Inventors: Girish Srinivas, Broomfield, CO (US); 4,528,277 A 7/1985 Hass et al. .................... 5O2.79 Robert J. Copeland, Golden, CO (US) 4,552,746 A 11/1985 Kettner et al. .... ... 423,573 4,623,533. A 1 1/1986 Broecker et al. ........... 423/573 (73) Assignee: TDA Research, Inc., Wheat Ridge, CO 4,640,908 A 2/1987 Dupin ... ... 502/243 (US) 4,786,483. A * 11/1988 Audeh ........... ... 423,210 4,818,740 A 4, 1989 Berben et al. .............. 502,313 (*) Notice: Subject to any disclaimer, the term of this 4,857,297 A 8, 1989 Kettner et al. ........... 423,576.8 patent is extended or adjusted under 35 4,886,649 A 12/1989 Ismagilov et al. .......... 423 230 U.S.C. 154(b) by 0 days. 4.937,058 A * 6/1990 Dupin et al. ................ 423,224 4,981,577 A * 1/1991 Audeh et al. ..... ... 208,251 R. (21) Appl. No.: 10/717,299 4,982,003 A 1/1991 Hara et al. .................. 564,480 9 4,983,277 A * 1/1991 Audeh et al. ..... ... 208,252 (22) Filed: Nov. 19, 2003 5,034,203 A 7, 1991 Audeh et al.
    [Show full text]
  • C:\Projects\Arizona DEQ\Arizona Clean Fuels\Draft Technical Support
    TECHNICAL SUPPORT DOCUMENT AND STATEMENT OF BASIS FOR CONSTRUCTION OF ARIZONA CLEAN FUELS YUMA, LLC PETROLEUM REFINERY Permit Number 1001205 August 30, 2004 TABLE OF CONTENTS I. INTRODUCTION ...........................................Page 1 of 449 A. Company Information..................................Page 1 of 449 B. Attainment Classification...............................Page 1 of 449 II. PROCESS DESCRIPTION ...................................Page 1 of 449 A. Crude Distillation Unit .................................Page 4 of 449 B. Gas Concentration Plant ...............................Page 4 of 449 C. Hydrocracker Unit ....................................Page 5 of 449 D. Naphtha Hydrotreater Unit .............................Page 6 of 449 E. Catalytic Reforming Unit ...............................Page 7 of 449 F. Isomerization Unit ....................................Page 7 of 449 G. Distillate Hydrotreater Unit .............................Page 8 of 449 H. Butane Conversion Unit ................................Page 9 of 449 I. Benzene Reduction Unit ...............................Page 10 of 449 J. Delayed Coking Unit ..................................Page 10 of 449 K. Petroleum Coke Storage, Handling, and Loading ..........Page 11 of 449 L. Amine Regeneration Unit ..............................Page 11 of 449 M. Sour Water Stripper ..................................Page 12 of 449 N. Sulfur Recovery Plant ................................Page 12 of 449 O. Hydrogen Plant ......................................Page 14 of 449 P. Group “A”
    [Show full text]
  • The Sour Gas, Sulfur and Acid Gas Book
    The Sour Gas, Sulfur and Acid Gas Book Technology and Application in Sour Gas Production, Treating and Sulfur Recovery (SI Units) Edward Wichert (www.grayjay.ventures) Preface The objective of The Sour Gas, Sulfur and Acid Gas Book is to describe the historical development and current applications of the procedures and processes used in the sour natural gas industry to safely produce, gather and treat sour gas, recover sulfur and dispose of waste products in an environmentally friendly manner. The production of sour natural gas in large volumes started in the 1950’s at Jumping Pound, Alberta, and at Lacq, France, and grew rapidly in the following years in Canada and the United States. This required the development of new technologies to handle the production and processing of the sour gas so that it could be used for industrial and domestic purposes. The evolution of improvements in metallurgy for sour gas, well completion techniques, sour gas treating methods and the increases in sulfur recovery efficiency can be traced by reviewing the papers published in the technical literature or presented at various gatherings of industry experts, such as the Laurance Reid Gas Conditioning Conference (LRGCC) held annually near the end of February in Norman, Oklahoma. Up to about the mid-1950’s the topics at such technical conferences dealt mainly with research on natural gas properties and natural gas dehydration. Since that time, the papers dealing with various improvements in sour gas treating and enhancements in sulfur recovery outnumber all other topics at the LRGCC. Currently (2018) the main sour gas developments are taking place in the Middle East, where a major technical conference on Sour Oil and Gas Advanced Technology (SOGAT) takes place annually.
    [Show full text]
  • Tail Gas Treatment of Sour- SEWGS CO2 Product
    Tail gas treatment of sour- SEWGS CO2 product H.A.J. van Dijk Juni 2012 ECN-E--12-025 Acknowledgement This literature review has been performed as part of the EDGaR Effect of impurities in C02 on the CCTS chain optimisation project (proj.nr. 5.0889). Abstract This literature review covers the technologies suitable for the CO2-H2S separation within the context of CO2 purification of a pre-combustion captured stream intended for storage or reuse. The technologies considered cover existing industrially applied processes, emerging processes as well as processes in development. Several technologies capable of achieving the desired CO2-H2S separation were identified. Among them are liquid scrubbing processes Thiopaq and CrystaSulf producing elemental sulphur, selective oxidation to elemental sulphur such as MODOP or based on novel catalysts and sorbent-based (reactive) separations using low-, medium- or high-temperature (reactive) sorbents. Contents Summary 4 1 Introduction 8 2 Acid gas removal technology 11 2.1 COS, CS2 and SO2 conversion 11 2.2 H2S removal via solvents 12 3 Claus process 16 3.1 General description 16 3.2 H2S equilibrium chemistry 17 3.3 Claus plant configurations 18 3.4 Liquid processes 22 3.5 Novel catalytic processes 23 4 Sorbent based desulphurization 25 4.1 Regenerative processes 25 4.2 Low temperature sorbents 28 4.3 Semi-regenerative sorbent based processes 29 5 CO2 gas conditioning 31 6 Thermal and electrochemical H2S decomposition 32 7 Discussion 34 8 References 38 ECN-E--12-025 Introduction 3 Summary Within the EDGaR CO2 purity project, a literature research was conducted on technologies suitable for CO2-H2S separation.
    [Show full text]
  • Alaska Coal Gasification Feasibility Studies– Healy Coal-To-Liquids Plant
    Alaska Coal Gasification Feasibility Studies– Healy Coal-to-Liquids Plant DOE/NETL-2007/1251 Final Report July 2007 Disclaimer This report was prepared as an account of work sponsored by an agency of the United States Government. Neither the United States Government nor any agency thereof, nor any of their employees, makes any warranty, express or implied, or assumes any legal liability or responsibility for the accuracy, completeness, or usefulness of any information, apparatus, product, or process disclosed, or represents that its use would not infringe privately owned rights. Reference therein to any specific commercial product, process, or service by trade name, trademark, manufacturer, or otherwise does not necessarily constitute or imply its endorsement, recommendation, or favoring by the United States Government or any agency thereof. The views and opinions of authors expressed therein do not necessarily state or reflect those of the United States Government or any agency thereof. ii Alaskan Coal Gasification Feasibility Studies– Healy Coal-to-Liquids Plant DOE/NETL-2007/1251 Final Report for Subtask 41817.333.01.01 July 2007 NETL Contact: Brent Sheets Manager Arctic Energy Office Prepared by: Lawrence Van Bibber Charles Thomas Robert Chaney Research & Development Solutions, LLC (RDS)/ Science Applications International Corporation (SAIC) National Energy Technology Laboratory www.netl.doe.gov iii Usibelli Coal Mine Operations Healy, Alaska The Usibelli Coal Mine, located in interior Alaska, is the site selected for studying the feasibility of siting a modest size Fischer-Tropsch (F-T) liquids production facility. This study focused on evaluating the feasibility of the gasification of Usibelli coal, Alaska’s only operating mine, to produce F-T liquids to supply the niche markets of Alaska refineries.
    [Show full text]