1983: Fundamentals of Gas Sweetening
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CO2 Removal by Amine Absorption and Condensed Rotational Separation: Energy Consumption & Equipment Sizing
CO2 removal by Amine Absorption and Condensed Rotational Separation: Energy Consumption & Equipment Sizing by STEVEN JAN MARTIN DE RIJKE BSc in Mechanical Engineering THESIS submitted in partial fulfillment of the requirements for the degree MASTER OF SCIENCE: MECHANICAL ENGINEERING Department of Mechanical Engineering Technical University Eindhoven Document Number: WPT201214 November 30, 2012 Approved by: prof. dr ir J.J.H. Brouwers dr. ir H.P. van Kemenade prof.dr. M. Golombok dr.ir. J. van der Schaaf Acknowledgment The author wishes to thank J.J.H. Brouwers & H.P. van Kemenade for the idea for this work and their support throughout the process R.J. van Benthum for his insightful help and his time Romico Hold for access to proprietary knowledge regarding the RPS and related processes. J.M. de Rijke & E.A. de Rijke-Amesz for their patience and support ii SUMMARY/ABSTRACT The Rotational Particle Separator (RPS) is a compact device capable of separating micron-sized droplets from gases by centrifugation. Combined with expansion cooling in a turbine at semi-cryogenic temperatures, it provides the opportunity to remove contaminants like CO2 and H2S from natural gas. Potential advantages of this technique are lower energy consumption and compactness. To demonstrate its potential, the technology is compared on the basis of installed volume and energy consumption with conventional amine technology for a range of CO2 concentrations. The comparison is made using a model of both processes and their components separating a range of CO2 contents from a 125 MMscf/day gas stream. The results show that for CO2 concentrations greater than 15% the CRS technology offers significant advantages in both installed volume and energy requirement, unlocking natural gas fields with sour gas concentrations that cannot be treated with conventional technology up until well in the 70% CO2 content. -
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. -
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. -
Amine Systems
2014 JUNE H2S Scavenging: Amine Systems This GATEKEEPER focuses on Amine Systems, one of the most commonly used regenerative H2S scavengers in the Oil & Gas industry. Solution Loading H S > CO Amine 2 2 Amine (wt%) (mole / mole) Selectivity Amines are organic compounds derived from ammonia with substitution of one or all of the hydrogens with MEA 15 - 20 0.30 - 0.35 No alkyl or aryl groups, retaining a basic nitrogen atom with one lone pair of electrons. They can be classified as Primary, Secondary, Tertiary, or Cyclic. DEA 25 - 35 0.30 - 0.35 Limited . Primary – One of three hydrogen atoms is replaced by alkyl or aryl groups DGA 50 - 70 0.30 - 0.35 No . Secondary – Two of the three hydrogen atoms are replaced by alkyl or aryl groups Condition MDEA 20 - 50 0.70 - 0.80 . Tertiary – All three hydrogen atoms are replaced by alkyl or aryl groups Dependent . Cyclic – Either secondary or tertiary amines with a cyclic structure with hydrogen atoms replaced Loading values are based on use in carbon steel systems by alkyl or aryl groups without corrosion inhibitor treatment* Amine Solution Selection Table 1: Amine Operating Ranges The amine selected, as well as the concentration of the solution used, will result in different selectivity of H2S over CO2, mole-to-mole acid gas loading, and degradation of the amine. Blended solutions incorporating more than one amine, as well as specialty designed amine molecules, can be used to increase selectivity, loading, and degradation characteristics of the final solution. Typical operating ranges for common amines have been given in Table 1. -
Economical Sulfur Removal for Fuel Processing Plants Challenge Sulfur Is Naturally Present As an Impurity in Fossil Fuels
SBIR Advances More Economical Sulfur Removal for Fuel Processing Plants Challenge Sulfur is naturally present as an impurity in fossil fuels. When the fuels are burned, the sulfur is released as sulfur dioxide—an air pollutant responsible for respiratory problems and acid rain. Environmental regulations have increasingly restricted sulfur dioxide emissions, forcing fuel processors to remove the sulfur from both fuels and exhaust gases. The cost of removing sulfur from natural gas and petroleum in the United States was about DOE Small Business Innovation $1.25 billion in 2008*. In natural gas, sulfur is present mainly as hydrogen sulfide gas (H2S), Research (SBIR) support while in crude oil it is present in sulfur-containing organic compounds which are converted enabled TDA to develop and into hydrocarbons and H2S during the removal process (hydrodesulfurization). In both cases, commercialize its direct oxidation corrosive, highly-toxic H2S gas must be converted into elemental sulfur and removed for sale or process—a simple, catalyst-based safe disposal. system for removing sulfur from At large scales, the most economical technology for converting hydrogen sulfide into sulfur is natural gas and petroleum—that the Claus process. This well-established process uses partial combustion and catalytic oxidation was convenient and economical enough for smaller fuel processing to convert about 97% of the H2S to elemental sulfur. In a typical application, an amine treatment plants to use. unit concentrates the H2S before it enters the Claus unit, and a tail gas treatment unit removes the remaining 3% of the H2S after it exits the Claus unit. This multi-step process has low operating costs but high capital costs—too expensive for TDA Research, Inc. -
ASPEN HYSES V8.8 Design for the Simultaneous Removal of Thiols
1st International Conference on Advances in Engineering and Technology (ICAET-2018) Contribution ID: 49 Type: Poster Presenter ASPEN HYSES V8.8 Design for the simultaneous removal of thiols, hydrogen sulfide and carbon dioxide from natural gas stream using DEA + MDEA + Piperazine aqueous solutions Natural gas and petroleum industries are dealing with raw materials containing variable concentrations of acid gases (CO2, H2S) and traces of mercaptans and dimethyl disulfide and many others. Treatment processes have to remove not only H2S and CO2 but also OSS and prohibited compounds because worldwide regulations for environmental protection are forcing the petroleum industry to decrease the sulfur content in petroleum fluids. Furthermore, any mercaptans (RSH), carbonyl sulfide (COS), and carbon disulfide (CS2), not absorbed with from the sour gas through amine purification units, complicate the process scheme for downstream liquid treatment. In this work case studies have been carried out on Aspen HYSYS V8.8 for the simultaneous removal of H2S and organic sulfur species for natural gas. Solvent concentration in the aqueous solution has been varied from 0-60 % by volume for simultaneous removal of H2S, Methyl mercaptan, Ethyl mercaptan and n-Propyl mercaptan. While using DEA as the solvent the simulation results show an increase of 14 % Ethyl mercaptan, 49 % Methyl mercaptan and 111 % CO2 removal while a decrease of 41.82 % and 40.66 % was observed in H2S and n-Propyl mercaptan removal respectively vis a vis MDEA. Primary authors: Mr KHAN, Hashim (Punjab University, Lahore); Mr QADRI, Ishaq (Punjab University, Lahore ); Prof. AWAN, Javeed (Punjab University, Lahore) Presenters: Mr KHAN, Hashim (Punjab University, Lahore); Mr QADRI, Ishaq (Punjab University, Lahore ) Track Classification: Chemical & Material Engineering. -
Hydrogen Sulfide Formation in Oil and Gas
Canadian Journal of Chemistry Hydrogen Sulfide formation in Oil and Gas Journal: Canadian Journal of Chemistry Manuscript ID cjc-2015-0425.R1 Manuscript Type: Article Date Submitted by the Author: 18-Nov-2015 Complete List of Authors: Marriott, Robert; University of Calgary Pirzadeh, Payman; University of Calgary Marrugo-Hernandez, Juan; University of Calgary Raval, Shaunak;Draft University of Calgary Keyword: hydrogen sulfide, sulfur, conventional, unconventional, sulfate reduction https://mc06.manuscriptcentral.com/cjc-pubs Page 1 of 32 Canadian Journal of Chemistry Hydrogen Sulfide formation in Oil and Gas Robert A. Marriott, * Payman Pirzadeh, Juan J. Marrugo H. and Shaunak Raval Department of Chemistry, University of Calgary 2500 University Drive NW, Calgary, Alberta * E-mail: [email protected] , Tel: +1-403-220-3144 Draft 1 https://mc06.manuscriptcentral.com/cjc-pubs Canadian Journal of Chemistry Page 2 of 32 Abstract Hydrogen sulfide (H 2S) can be a significant component of oil and gas upstream production, where H2S can be naturally generated in situ from reservoir biomass and from sulfate containing minerals through microbial sulfate reduction (MSR) and/or thermochemical sulfate reduction (TSR). On the other hand, the technologies employed in oil and gas production, especially from unconventional resources, also can contribute to generation or delay of appearance of H2S. Steam assisted gravity drainage (SAGD) and hydraulic fracturing used in production of oil sands and shale oil/gas, respectively, can potentially convert the sulfur content of the petroleum into H2S or contribute excess amounts of H 2S during production. A brief overview of the different classes of chemical reactions involved in the in situ generation and release of H 2S is provided in this work. -
Contaminant Reporting in Amine Gas Treating Service
Contaminant Reporting in Amine Gas Treating Service By Randy Haws and Jim Jenkins CCR Technologies Inc. 11375 West Sam Houston Pkwy South Suite 201 Houston, Texas 77031 ABSTRACT For a number of years the gas treating and refining industries have been focusing on Heat Stable Salts (HSS) contamination in amine service. As knowledge continues to improve in this area, amine system efficiencies are improved and turnaround cycles are minimized. However, two unfortunate states still exist in the industry: (1) analytical reporting for HSS is not consistent and is often times confusing to operators, and (2) HSS is only one of the major contaminants in a gas treating solution. A better understanding of the full range of contaminants and degradation products is essential to achieving total solvent quality. This paper will review current reporting and terminology so that confusion in analyzing contaminants and sample results may be minimized. INTRODUCTION There is a wealth of literature available in the industry on the corrosive nature and proper control targets for Heat Stable Salts (HSS).1-4 Unfortunately it is easy to be confused about measured levels and reporting terminology of these HSS anions. This confusion is compounded by the fact that comparing these measured values to proper control points may be difficult if they are not compared on a consistent basis. HSS are also generally only a part of the contaminants present in the gas treating solution so, it is important to understand the total level of contaminants and degradation products present in the processing solution. This is important for the operator to know because, as the level of contaminants and degradation products increase, the physical properties of the solution may change. -
The Hydrodesulfurization of Diesel Fuel to Meet New Epa
THE HYDRODESULFURIZATION OF DIESEL FUEL TO MEET NEW EPA REQUIREMENTS By FAUSTO ISRAEL MARES-DAVILA ____________________ A Thesis Submitted to The Honors College In Partial Fulfillment of the Bachelors degree With Honors in Chemical Engineering THE UNIVERSITY OF ARIZONA M A Y 2016 Approved by: ____________________________ Dr. Kim Ogden Department of Chemical and Environmental Engineering Abstract In December 1, 2010 the EPA reduced the allowable sulfur content in diesel fuel to 15 ppm, which is now known as ultra-low sulfur diesel (ULSD). In order to reach the 15 ppm sulfur maximum, the hydrodesulfurization unit in many refineries had to be upgraded. The group has been tasked with developing an upgrade catalytic hydrodesulfurization unit for a refinery in the Delaware Valley that can treat 35,000 barrels per stream day (BPSD) of liquid feedstock containing 1.9 wt % sulfur. Performance data from the existing catalytic hydrodesulfurization unit was used to predict the performance of the upgraded unit. ChemCAD software was used for the process calculations and the feed was modeled using boiling curve data. The desulfurization reaction kinetics were based on the reduction of dibenzothiophene. The project goals are to achieve a 99% recovery of diesel fuel while reducing the sulfur content below 15 ppm. The liquid feedstock will be run through a packed bed reactor filled with CoMo/Al2O3 catalyst where the sulfur compounds will react with hydrogen gas to form hydrogen sulfide gas. An amine contactor will be used to remove sour gas from the recycle hydrogen stream and a distillation column will produce diesel. The work presented in this report is the combined effort of Fausto Mares-Davila, Jason Green, Toluwani Omotinugbon, and Jun Terashima. -
Statement of Basis for Crude Expansion
Statement of Basis Draft Greenhouse Gas Prevention of Significant Deterioration Preconstruction Permit for the Diamond Shamrock Refining Company, L.P., Valero McKee Refinery Permit Number: PSD-TX-861-GHG July 2013 This document serves as the statement of basis for the above-referenced draft permit, as required by 40 CFR § 124.7. This document sets forth the legal and factual basis for the draft permit conditions and provides references to the statutory or regulatory provisions, including provisions under 40 CFR § 52.21, that would apply if the permit is finalized. This document is intended for use by all parties interested in the permit. I. Executive Summary On December 2, 2011, Diamond Shamrock Refining Company, L.P., (a Valero company), submitted a Greenhouse Gas (GHG) Prevention of Significant Deterioration (PSD) permit application to EPA Region 6 to authorize a modification at Valero McKee Refinery, an existing major source of criteria pollutants. In connection with the same proposed project, Valero submitted a PSD application for non-GHG pollutants to the Texas Commission on Environmental Quality (TCEQ) on December 2, 2011. In November 2012, Valero requested that TCEQ withdraw its permit amendment application. A new permit application was submitted on December 7, 2012 to the TCEQ for non-GHG pollutants, and an update was submitted to the EPA Region 6 for the GHG PSD permit application. The project at the McKee Refinery, herein referred to as the Crude Expansion Project, proposes to modify certain equipment which will allow for an increase in the overall processing of crude oil from 169,000 barrels per day to 210,000 barrels per day. -
FLUOR CORTDORATION, LT E X =
-T_HE FLUOR CORTDORATION, LT e X = "3 4 I5 rar O ,........VI':1 li41%,.. 1 11 Ì' .11 f- . r» 6' .-= ea- ,.. S W: .:frt Al 0.--- .. - 7 - kit.- = , / I = 01 L?' u -7- 4 .!$ 4160i a a SINCE 1 8 9 0 )49 to the Employees and Shareholders of THE FLUOR CORPORATION,, LTD. ENGINEERS MANUFACTURERS CONSTRUCTORS 2500 S. ATLANTIC BLVD., LOS ANGELES 22 Metal Product Fabrication, Mfg. Division, Paola, Kansas Mid-Continent Gas-Gasoline Department, Houston, Texas eX14 awei2emke e#,Ceit he ae QintAaleAWAI Los AngelesSan FranciscoNew York Chicago Boston Pittsburgh Tulsa Houston 7 Yet41 emelY~ke MO/teJenk&9-1 off4We QkWeir Rak,,) 16169/aft e AIal/ Yki4iT ,Ofteeui fitWeritada ,./(ereeo Head Wrightson Processes Ltd. The Fluor Corporation Servicios Indust ria les of Canada, Ltd. De Mexico, S. A. Message to Employees and Shareholders 4. and 5 , 1949 Income and Expenditures 6 and 7 10 Years' Income and Expenditures 8 and 9 Manufactured Products 10 and I 1 "Xe Kezdez notylawyi Wertiff#& eraihrowieft4 Engineering and Construction 12 and I 3 MECHANICAL DESIGN AND CONSTRUCTION OF THIS COMPLETE REFINERY Research J 4 and 15 WAS COMPLETED BY FLUOR IN 1949 Sales 16 and 17 Ownership of Fluor 18 Employee Benefits 19 Balance Sheet 20 and 21 Board of Directors and Honor Roll 22 and 23 e u,,dyiy,/aa, The year 1949 was another outstanding year in the Arrangements have been concluded with the Amen- in the interpretation of company personnel policy, resulting history of The Fluor Corporation, Ltd. The volume of work can Smelting and Refining Company whereby we will handle in a more equitable treatment of all employee problems. -
Environmental, Health, and Safety Guidelines for Petroleum Refining
This document is NO LONGER IN USE by the World Bank Group. The new version of the World Bank Group Environmental, Health and Safety Guidelines are available at http://www.ifc.org/ehsguidelines Environmental, Health, and Safety Guidelines PETROLEUM REFINING RAFT FOR ECOND UBLIC ONSULTATION MARCH D S P C — 2016 WORLD BANK GROUP 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.