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dc.contributor.authorGhorpade, Tejas S.
dc.date.accessioned2018-07-23T23:43:19Z
dc.date.available2018-07-23T23:43:19Z
dc.date.issued2014-09
dc.identifier.urihttp://hdl.handle.net/11122/8837
dc.descriptionMaster's Project (M.S.) University of Alaska Fairbanks, 2014en_US
dc.description.abstractEnhanced oil recovery (EOR) is essential to recover bypassed oil and improve recovery factor. Alkaline-surfactant-polymer (ASP) flooding is a chemical EOR method that can be used to recover heavy oil containing organic acids from sandstone formations. It involves injection of alkali to generate in situ surfactants, improve sweep efficiency, and reduce interfacial tension (IFT) between displacing and displaced phase, and injection of a polymer to improve mobility ratio; typically, it is followed by extended waterflooding. The concentration of alkali, surfactant, and polymer used in the process depends on oil type, salinity of solution, pressure, temperature of the reservoir, and injection water quality. This project evaluates the effect of waterflooding on recovery, calculates the recovery factor for ASP flooding, and optimum concentration of alkali, surfactant, and polymer for an Alaskan reservoir. Also, the effects of waterflooding and improvement with ASP flooding are evaluated and compared. Studies of these effects on oil recovery were analyzed with a Computer Modeling Group (CMG)-generated model for the Alaskan North Slope (ANS) reservoir. Based on a literature review and screening criteria, the Western North Slope (WNS) 1 reservoir was selected for the ASP process. A CMG - WinProp simulator was used to create a fluid model and regression was carried out with the help of actual field data. The CMG - WinProp model was prepared with a 5 spot well injection pattern using the CMG STARS simulator. Simulation runs conducted for primary and waterflooding processes showed that the recovery factor increased from 3% due to primary recovery to 45% due to waterflooding at 500 psi drawdown for 60 years with a constant producing gas oil ratio (GOR). ASP flooding was conducted to increase recovery further, and optimum ASP parameters were calculated for maximum recovery. Also, effect of alkali, surfactant and polymer on recovery was observed and compared with ASP flood. If proved effective, the use of ASP chemicals for ANS reservoirs to increase the recovery factor could replace current miscible gas injection with chemical EOR. It will help to develop chemical flooding processes for heavier crude oil produced in harsh environments and create new horizons for chemical industries in Alaska.en_US
dc.language.isoen_USen_US
dc.subjectEnhanced oil recoveryen_US
dc.subjectAlaskaen_US
dc.subjectNorth Slopeen_US
dc.subjectOil field floodingen_US
dc.subjectOil field chemicalsen_US
dc.titleAlkali-surfactant-polymer (ASP) flooding - potential and simulation for Alaskan North Slope reservoiren_US
dc.typeOtheren_US
dc.type.degreems
refterms.dateFOA2020-03-05T16:18:07Z


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