DOCSLIB.ORG

Hydrocarbon Processing®

Total Page：16

File Type：pdf, Size：1020Kb

Download full-text PDF Read full-text
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. You assume responsibility for the selection of the program to achieve your sion may not apply to you. intended results, and for the installation, use and results obtained from the program. Gulf Publishing Company does not warrant that the functions contained in the program will meet your requirements. However, Gulf Publishing Company warrants LICENSE the media, on which the program is furnished to be free from defects in materials You may: and workmanship under normal use for period of thirty (30) days from the date of 1. Use the program on a single machine; delivery to you as evidenced by a copy of your receipt. 2. Copy the program into any machine readable or printed form for backup or Gulf Publishing Company is under no obligation to furnish technical support other modification purposes in support of your use of the program on the single machine; than to get the program up and running. Gulf Publishing Company does not provide 3. Transfer the program and license to another party if the other party agrees to engineering services. Gulf Publishing Company will make every effort, within reason, accept the terms and conditions of this agreement. If you transfer the program, you to forward other technical problems/inquiries on to the entity that is responsible for must at the same time either transfer all copies of the program to the same party or said technical support. destroy any copies not transferred. Gulf Publishing Company may discontinue support and distribution of the soft- You must reproduce and include the copyright notice on any copy of the program. ware covered by this license agreement, at any time, without liability or notice. GENERAL LIMITATIONS LIMITATIONS OF REMEDIES AND LIABILITY You may not use, copy, modify, or transfer the program, or any copy of it, modified or Gulf Publishing Company’s entire liability and your exclusive remedy shall be: merged portion, in whole or in part, except as expressly provided for in this license. If 1. The replacement of any CD not meeting Gulf Publishing Company’s limited you transfer possession of any copy, modification or merged portion of the program warranty and which is returned to Gulf Publishing Company or an authorized software to another party, your license is automatically terminated. You agree not to make cop- dealer with a copy of your receipt, or ies of the program or documentation for any purpose whatsoever, but to purchase all 2. If Gulf Publishing Company or the dealer is unable to deliver a replacement CD copies of the program from Gulf Publishing Company, except when making for secu- which is free of defects in materials or workmanship, you may terminate this agree- rity purposes reserve or backup copies of the program for use on the single machine. ment by returning the program and your money will be refunded. In no event will Gulf Publishing Company be liable to you for any damages of any TERM kind, including any lost profits, lost data, lost savings, or other incidental or con- This license is effective until terminated. You may terminate it at any other time by de- sequential damages or use or inability to use such program even if gulf publishing stroying the program together with all copies, modifications and merged portions in company or an authorized software dealer has been advised of the possibility of such any form. It will also terminate upon conditions set forth elsewhere in this agreement damages, or for any claim by any other party. or if you fail to comply with any term or condition of this agreement. You agree upon Some states do not allow the limitation or exclusion of liability for incidental or such termination to destroy the program together with all copies. consequential damages so the above limitation or exclusion may not apply to you. LIMITED WARRANTY GENERAL The program is provided “as is” without warranty of any kind, either expressed or You may not sublicense, assign or transfer the license or the program except as implied, including but not limited to the implied warranties of merchantability and expressly provided in this agreement. Any attempt otherwise to sublicense, assign or fitness for a particular purpose. The entire risk as to the quality, fitness, results to be transfer any of the rights, duties or obligations hereunder is void. obtained, and of performance of the program is with you. Should the program prove This agreement will be governed by the laws of the State of Texas. unsatisfactory or deficient, you (and not Gulf Publishing Company or any authorized Should you have any question concerning this agreement, you may contact Gulf software dealer) assume the entire cost of all necessary servicing, repair or correction. Publishing Company by writing to Gulf Publishing Company, Software Division, Due to the large variety of potential applications for the software, the software has P.O. Box 2608, Houston, Texas 77252. not been tested in all situations under which it may be used. Gulf Publishing Company You acknowledge that you have read this agreement, understand it and agree to shall not be liable in any manner whatsoever for the results obtained through the use be bound by its terms and conditions. You further agree that it is the complete and of the software. Persons using the software are responsible for the supervision, man- exclusive statement of the agreement between us which supersedes any proposal or agement, and control of the software. The responsibility includes, but is not limited prior agreement, oral or written, and any other communications between us relating to, the determination of appropriate uses for the software and the selection of the to the subject matter of this agreement. software and other programs to achieve intended results. www.HydrocarbonProcessing.com HYDROCARBON PROCESSING® 2012 Gas Processes Handbook HOME PROCESSES INDEX COMPANY INDEX Sponsors: Process Categories Dehydrogenation Drying Effluent cleanup Hydrogen Liquid treating LNG and NGL Sulfur Synthesis gas Treating www.HydrocarbonProcessing.com HYDROCARBON PROCESSING® 2012 Gas Processes Handbook HOME PROCESSES INDEX COMPANY INDEX Sponsors: Company Index Advanced Extraction Technologies Inc. GL Noble Denton Air Liquide Global E&C Solutions / Goar, Allison & Associates LLC Lurgi GmbH / MEDAL, Air Liquide GTC Technoloy US LLC Advanced Technologies US LLC Guild Associates Inc. Air Products and Chemicals Inc. Haldor Topsøe A/S Axens Jacobs Comprimo Sulfur Solutions BASF Corp. Johnson Matthey Catalysts BASF—Gas Treating Excellence by BASF Kanzler Verfahrenstechnik GmbH Black & Veatch Corp. The Linde Group Caloric Anlagenbau GmbH Merichem Co. Cameron Compression Systems Prosernat IFP Group Technologies (formerly NATCO Group) Randall Gas Technologies CB&I Shell Global Solutions BV Connelly-GPM Inc. Siirtec Nigi S.p.A. ConocoPhillips Technip Costain Energy & Process ThioSolv LLC Davy Process Technology Ltd. ThyssenKrupp Uhde GmbH ExxonMobil Research and Engineering Co. UOP LLC, a Honeywell Company Foster Wheeler URS Corp. www.HydrocarbonProcessing.com HYDROCARBON PROCESSING® 2012 Gas Processes Handbook HOME PROCESSES INDEX COMPANY INDEX Dehydrogenation STAR process (dehydrogenation of light paraffins to olefins) ThyssenKrupp Uhde GmbH www.HydrocarbonProcessing.com HYDROCARBON PROCESSING® 2012 Gas Processes Handbook HOME PROCESSES INDEX COMPANY INDEX Drying Drigas Siirtec Nigi S.p.A. Drizo gas dehydration Prosernat IFP Group Technologies Ecoteg Siirtec Nigi S.p.A. Ifpexol Prosernat IFP Group Technologies www.HydrocarbonProcessing.com HYDROCARBON PROCESSING® 2012 Gas Processes Handbook HOME PROCESSES INDEX COMPANY INDEX Effluent cleanup AdvaCap Prosernat IFP Group Technologies Cansolv
Load more

Recommended publications
  • Sulfur Recovery
    Sulfur Recovery Chapter 16 Based on presentation by Prof. Art Kidnay Plant Block Schematic Adapted from Figure 7.1, Fundamentals of Natural Gas Processing, 2nd ed. Kidnay, Parrish, & McCartney Updated: January 4, 2019 2 Copyright © 2019 John Jechura ([email protected]) Topics Introduction Properties of sulfur Sulfur recovery processes ▪ Claus Process ▪ Claus Tail Gas Cleanup Sulfur storage Safety and environmental considerations Updated: January 4, 2019 3 Copyright © 2019 John Jechura ([email protected]) Introduction & Properties of Sulfur Updated: January 4, 2019 Copyright © 2017 John Jechura ([email protected]) Sulfur Crystals http://www.irocks.com/minerals/specimen/34046 http://www.mccullagh.org/image/10d-5/sulfur.html Updated: January 4, 2019 5 Copyright © 2019 John Jechura ([email protected]) Molten Sulfur http://www.kamgroupltd.com/En/Post/7/Basic-info-on-elemental-Sulfur(HSE) Updated: January 4, 2019 6 Copyright © 2019 John Jechura ([email protected]) World Consumption of Sulfur Primary usage of sulfur to make sulfuric acid (90 – 95%) ▪ Other major uses are rubber processing, cosmetics, & pharmaceutical applications China primary market Ref: https://ihsmarkit.com/products/sulfur-chemical-economics-handbook.html Report published December 2017 Updated: January 4, 2019 7 Copyright © 2019 John Jechura ([email protected]) Sulfur Usage & Prices Natural gas & petroleum production accounts for the majority of sulfur production Primary consumption is agriculture & industry ▪ 65% for farm fertilizer: sulfur → sulfuric acid → phosphoric acid → fertilizer $50 per ton essentially disposal cost ▪ Chinese demand caused run- up in 2007-2008 Ref: http://ictulsa.com/energy/ “Cleaning up their act”, Gordon Cope, Updated December 24, 2018 Hydrocarbon Engineering, pp 24-27, March 2011 Updated: January 4, 2019 8 Copyright © 2019 John Jechura ([email protected]) U.S.
    [Show full text]
  • Natural Gas Acid Gas Removal and Sulfur Recovery Process Economics Program Report 216A
    ` IHS CHEMICAL Natural Gas Acid Gas Removal and Sulfur Recovery Process Economics Program Report 216A December 2016 ihs.com PEP Report 216A Natural Gas Acid Gas Removal and Sulfur Recovery Anshuman Agrawal Principal Analyst, Technologies Analysis Downloaded 3 January 2017 10:20 AM UTC by Anandpadman Vijayakumar, IHS ([email protected]) IHS Chemical | PEP Report 216A Natural Gas Acid Gas Removal and Sulfur Recovery PEP Report 216A Natural Gas Acid Gas Removal and Sulfur Recovery Anshuman Agrawal, Principal Analyst Abstract Natural gas is generally defined as a naturally occurring mixture of gases containing both hydrocarbon and nonhydrocarbon gases. The hydrocarbon components are methane and a small amount of higher hydrocarbons. The nonhydrocarbon components are mainly the acid gases hydrogen sulfide (H2S) and carbon dioxide (CO2) along with other sulfur species such as mercaptans (RSH), organic sulfides (RSR), and carbonyl sulfide (COS). Nitrogen (N2) and helium (He) can also be found in some natural gas fields. Natural gas must be purified before it is liquefied, sold, or transported to commercial gas pipelines due to toxicity and corrosion-forming components. H2S is highly toxic in nature. The acid gases H2S and CO2 both form weak corrosive acids in the presence of small amounts of water that can lead to first corrosion and later rupture and fire in pipelines. CO2 is usually a burden during transportation of natural gas over long distances. CO2 removal from natural gas increases the heating value of the natural gas as well as reduces its greenhouse gas content. Separation of methane from other major components contributes to significant savings in the transport of raw materials over long distances, as well as savings from technical difficulties such as corrosion and potential pipeline rupture.
    [Show full text]
  • Review of Technologies for Gasification of Biomass and Wastes
    Review of Technologies for Gasification of Biomass and Wastes Final report NNFCC project 09/008 A project funded by DECC, project managed by NNFCC and conducted by E4Tech June 2009 Review of technology for the gasification of biomass and wastes E4tech, June 2009 Contents 1 Introduction ................................................................................................................... 1 1.1 Background ............................................................................................................................... 1 1.2 Approach ................................................................................................................................... 1 1.3 Introduction to gasification and fuel production ...................................................................... 1 1.4 Introduction to gasifier types .................................................................................................... 3 2 Syngas conversion to liquid fuels .................................................................................... 6 2.1 Introduction .............................................................................................................................. 6 2.2 Fischer-Tropsch synthesis ......................................................................................................... 6 2.3 Methanol synthesis ................................................................................................................... 7 2.4 Mixed alcohols synthesis .........................................................................................................
    [Show full text]
  • Liquefied Natural Gas: Description, Risks, Hazards, Safeguards
    Liquefied Natural Gas: Description, Risks, Hazards, Safeguards Instructor: Dr. Simon Waldram Done by: Maryam Manojahri Maha Kafood Mohd Kamal CHEN455- Process Safety Engineering Nov. 17, 2009 Table of Contents Executive Summary..……………………………………………………………………………..……..i List of Tables.……………………………………………………………………….……………..….…ii List of Figures.……………………………………………………………………….………………..…ii Introduction.……………………………………………………………………………..……………….1 Value Chain…………………………………………………………………………………..………..….1 Liquefied Natural Gas Process Description and Risks Associated 1.1: Inlet Receiving and Condensate Stabilization………………………………………….….…3 1.2:Acid Gas Removal and Sulfur Recovery……………..………………………….…………….3 1.3:Dehydration and Mercaptan Remov.…………………………………………………….…….3 1.4:Mercury Removal…..…………………………………………………………………….……4 1.5:Gas Chilling and Liquefaction…..………………………………………….………………….4 1.6:Refrigeration ………………………..……………………………………………..…………..5 1.7:Fractionation and Nitrogen Rejection……………………...……………………………...…...5 1.8:Helium Extraction……..……………………………………………..…………..….…………6 1.9:Process Risks, Hazards and Safeguard………………………….…………...………………...6 Safety and Risk Assessments in LNG Main Parts 2.1: Safety in Locating LNG Plants….…………………………………………….………………8 2.1-1:Phast Simulation……………...……………………………………………………..9 2.2:Safety in Process Operation …………………………………………………………11 2.2-1:Risk Assessment in LNG Process Operation…...………………………….11 2.2-1-1:Training ………...……………………………………………….11 H2S Gas in LNG………………………………………………….12 2.2-1-2:Personal Protective Equipment (PPE)……………...…....………13 2.2-1-3:Emergency
    [Show full text]
  • Multi-Objective Optimization of a Rectisol Process
    Jiří Jaromír Klemeš, Petar Sabev Varbanov and Peng Yen Liew (Editors) Proceedings of the 24th European Symposium on Computer Aided Process Engineering – ESCAPE 24 June 15-18, 2014, Budapest, Hungary. Copyright © 2014 Elsevier B.V. All rights reserved. Multi-objective Optimization of a Rectisol® Process Manuele Gatti a,*, Emanuele Martelli a, Franҫois Maréchal b, Stefano Consonni a a Politecnico di Milano, Dipartimento di Energia, Via Lambruschini 4, Milano, Italy b Industrial Process Energy Systems Engineering (IPESE), Ecole Polytechnique Fédérale de Lausanne, 1015, Lausanne, Switzerland [email protected] Abstract This work focuses on the design, simulation and optimization of a Rectisol®-based process tailored for the selective removal of H2S and CO2 from gasification derived synthesis gas. Such task is quite challenging due to the need of addressing simultaneously the process design, energy integration and utility design. The paper, starting from a Rectisol® configuration recently proposed by the authors, describes the models and the solution strategy used to carry out the multi-objective optimization with respect to exergy consumption, CO2 capture level and capital cost. Keywords: Rectisol, CO2 Capture, Numerical Optimization, PGS-COM, Pareto frontier 1. Introduction Coal to Liquids (CTL) as well as Integrated Gasification Combined Cycle (IGCC) plants take advantage from the conversion of a cheap, fossil fuel like coal into a clean synthetic gas, mainly composed of hydrogen, carbon monoxide, carbon dioxide and other minor species, either to produce Liquid Fuels or Electricity as output. In such plants, sulfur-containing compounds are among the most critical contaminants, and they should be separated from the raw syngas not only to cope with emissions regulations but, in the specific case of CTL, also to avoid any potential detrimental impact on the catalyst of the downstream chemical synthesis process.
    [Show full text]
  • Hydrogen Sulfide Capture: from Absorption in Polar Liquids to Oxide
    Review pubs.acs.org/CR Hydrogen Sulfide Capture: From Absorption in Polar Liquids to Oxide, Zeolite, and Metal−Organic Framework Adsorbents and Membranes Mansi S. Shah,† Michael Tsapatsis,† and J. Ilja Siepmann*,†,‡ † Department of Chemical Engineering and Materials Science, University of Minnesota, 421 Washington Avenue SE, Minneapolis, Minnesota 55455-0132, United States ‡ Department of Chemistry and Chemical Theory Center, University of Minnesota, 207 Pleasant Street SE, Minneapolis, Minnesota 55455-0431, United States ABSTRACT: Hydrogen sulfide removal is a long-standing economic and environ- mental challenge faced by the oil and gas industries. H2S separation processes using reactive and non-reactive absorption and adsorption, membranes, and cryogenic distillation are reviewed. A detailed discussion is presented on new developments in adsorbents, such as ionic liquids, metal oxides, metals, metal−organic frameworks, zeolites, carbon-based materials, and composite materials; and membrane technologies for H2S removal. This Review attempts to exhaustively compile the existing literature on sour gas sweetening and to identify promising areas for future developments in the field. CONTENTS 4.1. Polymeric Membranes 9785 4.2. Membranes for Gas−Liquid Contact 9786 1. Introduction 9755 4.3. Ceramic Membranes 9789 2. Absorption 9758 4.4. Carbon-Based Membranes 9789 2.1. Alkanolamines 9758 4.5. Composite Membranes 9790 2.2. Methanol 9758 N 5. Cryogenic Distillation 9790 2.3. -Methyl-2-pyrrolidone 9758 6. Outlook and Perspectives 9791 2.4. Poly(ethylene glycol) Dimethyl Ether 9759 Author Information 9792 2.5. Sulfolane and Diisopropanolamine 9759 Corresponding Author 9792 2.6. Ionic Liquids 9759 ORCID 9792 3. Adsorption 9762 Notes 9792 3.1.
    [Show full text]
  • STANDARD-PLUS™ Brochure(PDF 2.0
    STANDARD-PLUS™ A new standard for standard NGL plants. 02 Introduction. Dating back to the early 1970’s, Linde Engineering North America The realized cost and time savings when constructing a complete standard Inc. (LENA) has been designing and producing modular units for gas NGL recovery plant can be as much as 4-6 months when compared to processing plants worldwide. only using the core standard cryogenic equipment and custom designing all other components, e.g. balance of plant equipment and utilities. This With the evolving shale gas market, the demand to build gas processing can mean a difference of more than 50 million USD in revenue during the plants faster, without affecting quality and high performance, continues to first year for the plant operator. The STANDARD-PLUS™ product line was develop. Many engineering companies have developed their own standard developed to meet demand without compromising quality, safety, and designs for core cryogenic equipment. However, few have attempted to reliability. develop a completely pre-engineered modularized standard Natural Gas Liquids (NGL) recovery plant that covers the wide range of gas processing conditions required for shale gas. Linde Engineering North America Inc. – Natural gas has been a vital part of our business since 1969. Plant modules are workshop prefabricated to maximum extent 120 & 200 MMSCFD Cryogenic Natural Gas Plant 20 MMSCFD Cryogenic 120 MMSCFD Cryogenic 100 MMSCFD CRYO-PLUSTM 200 MMSCFD CRYO-PLUS™ Natural Gas Plant Natural Gas Plant Natural Gas Plant Natural Gas Plant 350 MMSCFD Cryogenic Plant is essentially fully modular Natural Gas Plant 1974 1988 2000 2011 2013 03 Our approach - a standardized concept.
    [Show full text]
  • Environmental, Health, and Safety Guidelines for Petroleum Refining
    ENVIRONMENTAL, HEALTH, AND SAFETY GUIDELINES PETROLEUM REFINING November 17, 2016 ENVIRONMENTAL, HEALTH, AND SAFETY GUIDELINES FOR PETROLEUM REFINING INTRODUCTION 1. The Environmental, Health, and Safety (EHS) Guidelines are technical reference documents with general and industry-specific examples of Good International Industry Practice (GIIP).1 When one or more members of the World Bank Group are involved in a project, these EHS Guidelines are applied as required by their respective policies and standards. These industry sector EHS Guidelines are designed to be used together with the General EHS Guidelines document, which provides guidance to users on common EHS issues potentially applicable to all industry sectors. For complex projects, use of multiple industry sector guidelines may be necessary. A complete list of industry sector guidelines can be found at: www.ifc.org/ehsguidelines. 2. The EHS Guidelines contain the performance levels and measures that are generally considered to be achievable in new facilities by existing technology at reasonable costs. Application of the EHS Guidelines to existing facilities may involve the establishment of site-specific targets, with an appropriate timetable for achieving them. 3. The applicability of the EHS Guidelines should be tailored to the hazards and risks established for each project on the basis of the results of an environmental assessment in which site-specific variables— such as host country context, assimilative capacity of the environment, and other project factors—are taken into account. The applicability of specific technical recommendations should be based on the professional opinion of qualified and experienced persons. 4. When host country regulations differ from the levels and measures presented in the EHS Guidelines, projects are expected to achieve whichever is more stringent.
    [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]
  • Statement of Considerations Request by Hydrogen
    STATEMENT OF CONSIDERATIONS REQUEST BY HYDROGEN ENERGY OF CALIFORNIA FOR AN ADVANCE WAIVER OF PATENT RIGHTS TO INVENTIONS MADE UNDER COOPERATIVE AGREEMENT DE-FEOOO0663; W{A)-2010-006; CH-1545 As set out in the attached waiver petition and in subsequent discussions with DOE Patent Counsel. Hydrogen Energy of California (HECA) has requested an advance waiver of domestic and foreign patent rights for all subject inventions made under the above subject cooperative agreement, entitled, "Hydrogen Energy California Project Commercial Demonstration of Advanced IGCC with Full Carbon Capture." Referring to item 2 of the attached waiver petition, the petitioner will design, construct. and operate an Integrated Gasification Combined Cycle (lGCC) power plant with CO2 capture and sequestration (CCS) that will take blends of coal and petroleum coke, combined with non-potable water, and convert them into hydrogen and CO2. The CO2 will be separated from the hydrogen using the methanol-based Rectisol process. The hydrogen gas will be used to fule a power station, and the CO2 will transported by pipeline to nearby oil reservoirs where it will be used for enhanced oil recovery and sequestered. The project, which will be located in Kern County. California,. is designed to capture more than 2,000,000 tons per year of CO2• The work under this agreement is expected to take place between October 2010 and November 2018, at a total cost of $2.839 billion. HECA will provide 89% cost share or $2.531 billion. DOE will provide the remaining 11 % or $308 million. In its response to questions 5 and 6 of the attached waiver petition.
    [Show full text]
  • Selection of Wash Systems for Sour Gas Removal 4Th International Freiberg Conference on IGCC & Xtl Technologies
    Selection of Wash Systems for Sour Gas Removal 4th International Freiberg Conference on IGCC & XtL Technologies 5 May 2010 B. Munder, S. Grob, P.M. Fritz With contribution of A. Brandl, U. Kerestecioglu, H. Meier, A. Prelipceanu, K. Stübner, B. Valentin, H. Weiß Outline — Overview of Absorptive Sour Gas Removal Processes — Criteria for Choice of Absorptive Sour Gas Removal Processes — Comparison of Amine Wash Processes and the Rectisol® Process ● Qualitative comparison ● Case Studies: Sour gas removal for 1. Fuel gas production for IGCC from coal 2. Coal to Liquid (CtL) process 3. Biomass to Liquid (BtL) process — Summary and Conclusion Linde AG Engineering Division 4th International Freiberg Conference on IGCC & XtL Technologies Selection of Wash Systems for Sour Gas Removal 2 B. Munder, S. Grob, P.M Fritz / 5 May 2010 Overview of Absorptive Sour Gas Removal Processes — Chemical sour gas removal processes: Acid gases are chemically bound to the solvent. ● Amines: e.g. MEA, DEA, DIPA, MDEA, MDEA+additive (e.g. aMDEA® process) ® ® ● Liquid oxidation process on iron basis for removal of H2S: e.g. SulFerox , LO-CAT — Physical sour gas removal processes: Acid gases are dissolved in the solvent. ● Methanol (Rectisol® process) ● Polyethylenglycol Ether (e.g. Selexol®, Genosorb®, Sepasolv® processes) ● n-Methyl-2-Pyrrolidone (NMP; e.g. Purisol® process) — Physical-chemical sour gas removal processes: ● Methanol + Amine (e.g. Amisol® process) ● Sulfolane + Amine (e.g. Sulfinol® process) Linde AG Engineering Division 4th International Freiberg
    [Show full text]
  • 5.1 Petroleum Refining1
    5.1 Petroleum Refining1 5.1.1 General Description The petroleum refining industry converts crude oil into more than 2500 refined products, including liquefied petroleum gas, gasoline, kerosene, aviation fuel, diesel fuel, fuel oils, lubricating oils, and feedstocks for the petrochemical industry. Petroleum refinery activities start with receipt of crude for storage at the refinery, include all petroleum handling and refining operations, and they terminate with storage preparatory to shipping the refined products from the refinery. The petroleum refining industry employs a wide variety of processes. A refinery’s processing flow scheme is largely determined by the composition of the crude oil feedstock and the chosen slate of petroleum products. The example refinery flow scheme presented in Figure 5.1-1 shows the general processing arrangement used by refineries in the United States for major refinery processes. The arrangement of these processes will vary among refineries, and few, if any, employ all of these processes. Petroleum refining processes having direct emission sources are presented on the figure in bold-line boxes. Listed below are 5 categories of general refinery processes and associated operations: 1. Separation processes a. Atmospheric distillation b. Vacuum distillation c. Light ends recovery (gas processing) 2. Petroleum conversion processes a. Cracking (thermal and catalytic) b. Reforming c. Alkylation d. Polymerization e. Isomerization f. Coking g. Visbreaking 3. Petroleum treating processes a. Hydrodesulfurization b. Hydrotreating c. Chemical sweetening d. Acid gas removal e. Deasphalting 4. Feedstock and product handling a. Storage b. Blending c. Loading d. Unloading 5. Auxiliary facilities a. Boilers b. Waste water treatment c. Hydrogen production d.
    [Show full text]