en>ChrisGualtieri: Remove stub template(s). Page is start class or higher. Also check for and do General Fixes + Checkwiki fixes using AWB

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Remove stub template(s). Page is start class or higher. Also check for and do General Fixes + Checkwiki fixes using AWB

← Older revision		Revision as of 01:35, 13 December 2013
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	~~Hi there~~, ~~I am Sophia~~. I'~~ve always cherished living~~ in ~~Kentucky but now I~~'~~m contemplating~~ other ~~choices~~. ~~Invoicing~~ is what ~~I do~~ for a ~~residing but I've~~ usually ~~wanted my personal company~~. ~~Playing badminton~~ is a ~~thing~~ that he is ~~completely addicted~~ to.<br><br>~~Also visit my web page~~ - [http://~~genelab~~.~~microbio~~.~~pusan~~.ac.kr/~~~home_ver2~~/~~zbxe~~/~~index~~.~~php~~?~~document_srl~~=~~1056744~~&~~mid~~=~~lecutre17 best psychics~~]		'''Amine gas treating''', also known as '''gas sweetening''' and '''acid gas removal''', refers to a group of processes that use aqueous solutions of various [[Amine#Aliphatic amines\|alkylamines]] (commonly referred to simply as [[amine]]s) to remove [[hydrogen sulfide]] (H<sub>2</sub>S) and [[carbon dioxide]] (CO<sub>2</sub>) from gases.<ref name=Kohl>{{cite book\|author=Arthur Kohl and Richard Nielson\|title=Gas Purification\|edition=5th Edition\|publisher=Gulf Publishing\|year=1997\|isbn=0-88415-220-0}}</ref><ref name=Gary>{{cite book\|author=Gary, J.H. and Handwerk, G.E.\|title=Petroleum Refining Technology and Economics\|edition=2nd Edition\|publisher=Marcel Dekker, Inc\|year=1984\|isbn=0-8247-7150-8}}</ref><ref>{{cite patent
			\| country = US
			\| number = 4080424
			\| status =
			\| title = Process for acid gas removal from gaseous mixtures
			\| pubdate =
			\| gdate = 21 Mar 1978
			\| fdate = 11 Feb 1976
			\| pridate =
			\| inventor = Loren N. Miller
			\| invent1 = Robert A. Macriss
			\| invent2 = Thomas S. Zawacki
			\| assign1 = Institute of Gas Technology
			\| assign2 =
			\| class =
			}}</ref> It is a common [[unit process]] used in [[oil refinery\|refineries]], and is also used in [[petrochemical]] plants, [[natural gas processing\|natural gas processing plants]] and other industries.

			Processes within oil refineries or chemical processing plants that remove hydrogen sulfide are referred to as "sweetening" processes because the odor of the processed products is improved by the absence of hydrogen sulfide. An alternative to the use of amines involves [[membrane technology]]. Membranes are attractive since no reagents are consumed.<ref>Baker, R. W. "Future Directions of Membrane Gas Separation Technology" Ind. Eng. Chem. Res. 2002, volume 41, pages 1393-1411. {{DOI\|10.1021/ie0108088}}</ref>

			Many different amines are used in gas treating:
			* [[Diethanolamine]] (DEA)
			* [[Ethanolamine\|Monoethanolamine]] (MEA)
			* [[Methyl diethanolamine\|Methyldiethanolamine]] (MDEA)
			* [[Diisopropanolamine]] (DIPA)
			* Aminoethoxyethanol (Diglycolamine) (DGA)

			The most commonly used amines in industrial plants are the alkanolamines DEA, MEA, and MDEA. These amines are also used in many oil refineries to remove [[sour gas]]es from liquid hydrocarbons such as [[liquified petroleum gas]] (LPG).

			==Description of a typical amine treater==
			Gases containing H<sub>2</sub>S or both H<sub>2</sub>S and CO<sub>2</sub> are commonly referred to as ''[[sour gas]]es'' or ''[[acid gas]]es'' in the [[hydrocarbon]] processing industries.

			The chemistry involved in the amine treating of such gases varies somewhat with the particular amine being used. For one of the more common amines, monoethanolamine (MEA) denoted as '''''RNH<sub>2</sub>''''', the chemistry may be expressed as:

			:RNH<sub>2</sub> + H<sub>2</sub>S <math>\Leftrightarrow</math> RNH{{su\|p=+\|b=3}} + SH<sup>-</sup>

			A typical amine gas treating process (as shown in the [[Process Flow diagram\|flow diagram]] below) includes an '''absorber''' unit and a '''regenerator''' unit as well as accessory equipment. In the absorber, the downflowing amine solution absorbs H<sub>2</sub>S and CO<sub>2</sub> from the upflowing sour gas to produce a sweetened gas stream (i.e., a gas free of hydrogen sulfide and carbon dioxide) as a product and an amine solution rich in the absorbed acid gases. The resultant "rich" amine is then routed into the regenerator (a stripper with a [[reboiler]]) to produce regenerated or "lean" amine that is recycled for reuse in the absorber. The stripped overhead gas from the regenerator is concentrated H<sub>2</sub>S and CO<sub>2</sub>. In oil refineries, that stripped gas is mostly H<sub>2</sub>S, much of which often comes from a sulfur-removing process called [[hydrodesulfurization]]. This H<sub>2</sub>S-rich stripped gas stream is then usually routed into a [[Claus process]] to convert it into elemental [[sulfur]]. In fact, the vast majority of the 64,000,000 metric tons of sulfur produced worldwide in 2005 was byproduct sulfur from refineries and other hydrocarbon processing plants.<ref>[http://minerals.usgs.gov/minerals/pubs/commodity/sulfur/sulfumcs06.pdf Sulfur production report] by the [[United States Geological Survey]]</ref><ref>[http://www.agiweb.org/geotimes/july03/resources.html Discussion of recovered byproduct sulfur]</ref> Another sulfur-removing process is the [[WSA Process]] which recovers sulfur in any form as concentrated sulfuric acid. In some plants, more than one amine absorber unit may share a common regenerator unit.

			[[Image:AmineTreating.png\|frame\|center\|[[Process flow diagram]] of a typical amine treating process used in petroleum refineries, natural gas processing plants and other industrial facilities.]]

			The amine concentration in the absorbent aqueous solution is an important parameter in the design and operation of an amine gas treating process. Depending on which one of the following four amines the unit was designed to use and what gases it was designed to remove, these are some typical amine concentrations, expressed as weight percent of pure amine in the aqueous solution:<ref name=Kohl/>

			:* Monoethanolamine: About 20 % for removing H<sub>2</sub>S and CO<sub>2</sub>, and about 32 % for removing only CO<sub>2</sub>.
			:* Diethanolamine: About 20 to 25 % for removing H<sub>2</sub>S and CO<sub>2</sub>
			:* Methyldiethanolamine: About 30 to 55% % for removing H<sub>2</sub>S and CO<sub>2</sub>
			:* Diglycolamine: About 50 % for removing H<sub>2</sub>S and CO<sub>2</sub>

			The choice of amine concentration in the circulating aqueous solution depends upon a number of factors and may be quite arbitrary. It is usually made simply on the basis of experience. The factors involved include whether the amine unit is treating raw [[natural gas]] or [[Petroleum refining processes\|petroleum refinery]] by-product gases that contain relatively low concentrations of both H<sub>2</sub>S and CO<sub>2</sub> or whether the unit is treating gases with a high percentage of CO<sub>2</sub> such as the offgas from the steam reforming process used in [[ammonia production]] or the [[flue gas]]es from [[Conventional coal-fired power plant\|power plants]]. Both H<sub>2</sub>S and CO<sub>2</sub> are acid gases and hence corrosive to [[carbon steel]]. However, in an amine treating unit, CO<sub>2</sub> is the stronger acid of the two. H<sub>2</sub>S forms a film of iron sulfide on the surface of the steel that acts to protect the steel. When treating gases with a high percentage of CO<sub>2</sub>, corrosion inhibitors are often used and that permits the use of higher concentrations of amine in the circulating solution. Another factor involved in choosing an amine concentration is the relative solubility of H<sub>2</sub>S and CO<sub>2</sub> in the selected amine. For more information about selecting the amine concentration, the reader is referred to Kohl and Nielsen's book.<ref name=Kohl/>

			The choice of the type of amine will affect the required circulation rate of amine solution, the energy consumption for the regeneration and the ability to selectively remove either H<sub>2</sub>S alone or CO<sub>2</sub> alone if desired.

			The current emphasis on removing CO<sub>2</sub> from the flue gases emitted by fossil fuel power plants has led to much interest in using amines for that purpose. (See also: [[Carbon capture and storage]] and [[Conventional coal-fired power plant]].)

			In the specific case of the industrial synthesis of [[ammonia]], for the [[steam reforming]] process of hydrocarbons to produce gaseous [[hydrogen]], amine treating is one of the commonly used processes for removing excess carbon dioxide in the final purification of the gaseous hydrogen.

			==aMDEA==
			Activated MDEA or aMDEA uses [[piperazine]] as a catalyst to increase the speed of the reaction with CO2. It has been commercially successful.<ref> {{cite journal \| title = Piperazine – Why It's Used and How It Works \| journal = The Contactor \| date = 2008 \| first = Optimised Gas Treating, Inc. \| volume = 2 \| issue = 4\| id = \| url = http://www.ogtrt.com/files/contactors/vol_2_issue_4.pdf \| accessdate = 2013-10-23}}</ref>

			==See also==

			*[[Ammonia production]]
			*[[Hydrodesulfurization]]
			*[[WSA Process]]
			*[[Claus process]]
			*[[Selexol]]
			*[[Rectisol]]
			*[[Amine]]
			*[[Ionic liquid]]s

			==References==
			{{Reflist}}

			==External links==
			*[http://articles.compressionjobs.com/articles/oilfield-101/2711-gas-dehydration-lts-hydrates-sweetening-amine?start=6 Description of Gas Sweetening Equipment and Operating Conditions]
			*[http://www.bre.com/technicalpapers/technicalpaper.asp?articlenumber=52 Selecting Amines for Sweetening Units], Polasek, J. (Bryan Research & Engineering) and Bullin, J.A. (Texas A&M University), Gas Processors Association Regional Meeting, Sept. 1994.
			*[http://www.naturalgas.org/naturalgas/processing_ng.asp Natural Gas Supply Association] Scroll down to ''Sulfur and Carbon Dioxide Removal''
			*[http://www.gulfpub.com/default.asp?page=14&productID=2743&VS= Description of the classic book on gas treating] by {{cite book\|author=Arthur Kohl & Richard Nielsen \|title=Gas Purification\|edition=Fifth Edition\|publisher=Gulf Publishing\|year=\|isbn=0-88415-220-0}}

			{{DEFAULTSORT:Amine Gas Treating}}
			[[Category:Chemical processes]]
			[[Category:Oil refining]]
			[[Category:Unit processes]]
			[[Category:Acid gas control]]
			[[Category:Natural gas technology]]

131.151.26.125: /* Determination of Plug Flow */

2012-08-22T21:08:41Z

Determination of Plug Flow

New page

Hi there, I am Sophia. I've always cherished living in Kentucky but now I'm contemplating other choices. Invoicing is what I do for a residing but I've usually wanted my personal company. Playing badminton is a thing that he is completely addicted to.<br><br>Also visit my web page - [http://genelab.microbio.pusan.ac.kr/~home_ver2/zbxe/index.php?document_srl=1056744&mid=lecutre17 best psychics]

Plug flow - Revision history

en>ChrisGualtieri: Remove stub template(s). Page is start class or higher. Also check for and do General Fixes + Checkwiki fixes using AWB

131.151.26.125: /* Determination of Plug Flow */