{"id":435,"date":"2017-03-16T18:41:33","date_gmt":"2017-03-17T01:41:33","guid":{"rendered":"http:\/\/rccostello.com\/wordpress\/?p=435"},"modified":"2026-05-08T04:14:49","modified_gmt":"2026-05-08T11:14:49","slug":"hydrogen-sulfide-in-wellhead-gas","status":"publish","type":"post","link":"https:\/\/www.rccostello.com\/wordpress\/modular-plants\/hydrogen-sulfide-in-wellhead-gas\/","title":{"rendered":"Hydrogen Sulfide Removal from Wellhead Gas"},"content":{"rendered":"
\"Hydrogen<\/a>
Hydrogen Sulfide<\/figcaption><\/figure>\n

Hydrogen sulfide (H2<\/sub>S) is a common but dangerous compound that is often found in natural gas wells.  When the concentration of H2<\/sub>S exceeds 5.7 milligrams\/m3<\/sup>, the gas stream is referred to as Sour Gas.  This gas must be treated before it can be used in pipelines or plants.<\/p>\n

Hydrogen sulfide is particularly dangerous, as it is toxic at low levels.  The gas has a characteristic \u201crotten egg\u201d smell at a concentration as low as 1 ppm.  However, at a 10 ppm concentration, the olfactory nerves are desensitized.  At higher concentrations H2<\/sub>S will cause headaches and respiratory damage, and is ultimately fatal.  Because of the loss of the sense of smell at such low concentrations, exposure to H2<\/sub>S is particularly dangerous.  Many individuals have assumed that they were safe, as they could no longer smell the H2<\/sub>S, only to suffer severe consequences.<\/p>\n

When the concentration of H2<\/sub>S at the wellhead is below 10 ppm, the gas stream can be treated easily on site.  Either the Sulfatreat process or an Iron Oxide process can remove the H2<\/sub>S at the wellhead.  Both processes use a solid absorbent that are selective to H2<\/sub>S.  Typically, multiple beds are used, depending upon the wellhead gas flow.  Over time adsorbent will lose capacity and need to be replaced with fresh media.<\/p>\n

At higher wellhead concentrations of H2<\/sub>S, fixed bed adsorbent processes are not economic.  An Amine Unit is a better option in this case.<\/p>\n

An Amine Unit typically contains a countercurrent absorber where the gas and anime are contacted.  The treated gas leaving the top of the absorber will be water saturated, so a TEG drying unit may be required.  The rich amine solution is sent to a regenerator where the H2<\/sub>S is stripped and the amine recycled.  The stripped H2<\/sub>S gas will be processed in additional units for solid sulfur recovery.<\/p>\n

The key to selecting the proper treatment scheme is dependent upon the concentration not only of H2<\/sub>S, but also of carbon dioxide. Let COSTELLO <\/a>help you with determining the proper treatment scheme for your natural gas.<\/p>\n

Phone: 310-792-5870 Email: rcca@rccostello.com<\/strong><\/p>\n

Website: rccostello.com<\/a><\/strong><\/p>\n","protected":false},"excerpt":{"rendered":"

Hydrogen sulfide (H2S) is a common but dangerous compound that is often found in natural gas wells.  When the concentration of H2S exceeds 5.7 milligrams\/m3, the gas stream is referred to as Sour Gas.  This gas must be treated before it can be used in pipelines or plants. Hydrogen sulfide is particularly dangerous, as it […]<\/p>\n","protected":false},"author":1,"featured_media":0,"comment_status":"closed","ping_status":"open","sticky":false,"template":"","format":"standard","meta":{"_genesis_hide_title":false,"_genesis_hide_breadcrumbs":false,"_genesis_hide_singular_image":false,"_genesis_hide_footer_widgets":false,"_genesis_custom_body_class":"","_genesis_custom_post_class":"","_genesis_layout":"","footnotes":""},"categories":[1],"tags":[14,77,76],"class_list":["post-435","post","type-post","status-publish","format-standard","category-modular-plants","tag-engineering-solutions","tag-hydrogen-sulfide","tag-sulfur","entry","has-post-thumbnail"],"yoast_head":"\nHydrogen Sulfide Removal Solutions for Sour Wellhead Gas – COSTELLO<\/title>\n<meta name=\"description\" content=\"Protect your equipment and meet safety standards. 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