{"id":16420,"date":"2015-09-16T10:18:00","date_gmt":"2015-09-16T02:18:00","guid":{"rendered":"https:\/\/www.oilfieldtech.com.au\/?p=16420"},"modified":"2018-09-11T10:32:24","modified_gmt":"2018-09-11T02:32:24","slug":"ophir-fortuna-equatorial-guinea-africas-first-deepwater-independent-flng-project","status":"publish","type":"post","link":"https:\/\/www.oilfieldtech.com.au\/ophir-fortuna-equatorial-guinea-africas-first-deepwater-independent-flng-project\/","title":{"rendered":"Ophir Fortuna, Equatorial Guinea, Africa\u2019s first deepwater independent FLNG project"},"content":{"rendered":"<p>Ophir&#8217;s Fortuna project entered FEED in July 2015 and FID is expected\u00a0once the\u00a0financing solution has finalised. The field is expected to produce 2.2mmtpa and Ophir currently has an 80% working interest in the Upstream PSC.<\/p>\n<p>Fortuna-2 DST flowed gas to surface at a constrained rate of 60 MMscfd, exceeding expectations. The implied unconstrained rate was 180 MMscfd which will reduce the number of development wells required.<\/p>\n<p>Fortuna sits within the Block R licence, offshore Equatorial Guinea which is located in the south-eastern part of the Niger Delta complex. Ophir holds an 80% operated interest in Block R. There have been six commercial discoveries to date in Block R, five of which were made by Ophir. There is a total of 3.0\u00a0<abbr class=\"glossary\" title=\"Trillion cubic feet equivalent\">Tcf<\/abbr>\u00a0of independently certified 2C contingent resource and another 0.7 Tcf of low risk prospective resource in Block R making a total of 3.7 Tcf (at November 2015) for the project planning case.<\/p>\n<p>Production is expected to be around 330 MMscfd with a plateau of 30 years.<\/p>\n<p>&nbsp;<\/p>\n","protected":false},"excerpt":{"rendered":"<p>Ophir&#8217;s Fortuna project entered FEED in July 2015 and FID is expected\u00a0once the\u00a0financing solution has finalised. The field is expected to produce 2.2mmtpa and Ophir currently has an 80% working interest in the Upstream PSC. Fortuna-2 DST flowed gas to surface at a constrained rate&#8230;<\/p>\n","protected":false},"author":3,"featured_media":0,"comment_status":"closed","ping_status":"closed","sticky":false,"template":"","format":"standard","meta":{"footnotes":""},"categories":[49],"tags":[],"aioseo_notices":[],"_links":{"self":[{"href":"https:\/\/www.oilfieldtech.com.au\/wp-json\/wp\/v2\/posts\/16420"}],"collection":[{"href":"https:\/\/www.oilfieldtech.com.au\/wp-json\/wp\/v2\/posts"}],"about":[{"href":"https:\/\/www.oilfieldtech.com.au\/wp-json\/wp\/v2\/types\/post"}],"author":[{"embeddable":true,"href":"https:\/\/www.oilfieldtech.com.au\/wp-json\/wp\/v2\/users\/3"}],"replies":[{"embeddable":true,"href":"https:\/\/www.oilfieldtech.com.au\/wp-json\/wp\/v2\/comments?post=16420"}],"version-history":[{"count":0,"href":"https:\/\/www.oilfieldtech.com.au\/wp-json\/wp\/v2\/posts\/16420\/revisions"}],"wp:attachment":[{"href":"https:\/\/www.oilfieldtech.com.au\/wp-json\/wp\/v2\/media?parent=16420"}],"wp:term":[{"taxonomy":"category","embeddable":true,"href":"https:\/\/www.oilfieldtech.com.au\/wp-json\/wp\/v2\/categories?post=16420"},{"taxonomy":"post_tag","embeddable":true,"href":"https:\/\/www.oilfieldtech.com.au\/wp-json\/wp\/v2\/tags?post=16420"}],"curies":[{"name":"wp","href":"https:\/\/api.w.org\/{rel}","templated":true}]}}