Show simple item record

dc.contributor.advisorKazemi, Hossein
dc.contributor.authorBrown, Jeffrey S.
dc.date.accessioned2007-01-03T05:46:19Z
dc.date.accessioned2022-02-09T08:59:23Z
dc.date.available2007-01-03T05:46:19Z
dc.date.available2022-02-09T08:59:23Z
dc.date.issued2014
dc.date.submitted2014
dc.identifierT 7682
dc.identifier.urihttps://hdl.handle.net/11124/17037
dc.description2014 Fall.
dc.descriptionIncludes illustrations (some color).
dc.descriptionIncludes bibliographical references (pages 434-479).
dc.description.abstractA new formulation for fluid trapping using a dual-media approach which includes compositional trapping and interphase mass transfer was developed, coded, and validated. This formulation does not exist in notable commercial reservoir simulators. The formulation was incorporated into a three-dimensional, three-phase, parallel compositional simulator to simulate carbon dioxide (CO2) water-alternating-gas (WAG) injection. Fluid phase trapping is both a channeling issue and a pore-scale issue. Pore-scale phase trapping is strongly related to hysteresis in the relative permeability and capillary pressure; the simulator incorporates them in a methodology consistent with these issues. New algorithms were developed to implement the CO2 solubility in water and oil and CO2 phase trapping in a way that preserves the mass balance of the oil, water, and gas phases. The new simulator was implemented using a parallel infrastructure to facilitate computationally intensive fine grid systems. For test examples, we focused on a mixed wet carbonate reservoir in the Middle East. These tests were used to evaluate the significance of various trapping scenarios. Compositional trapping, gas relative permeability hysteresis, CO2 solubility in water, and permeability heterogeneity were found to have significant impacts on oil recovery and timing, as well as CO2 storage and utilization during waterflood and CO2 WAG processes.
dc.format.mediumborn digital
dc.format.mediumdoctoral dissertations
dc.languageEnglish
dc.language.isoeng
dc.publisherColorado School of Mines. Arthur Lakes Library
dc.relation.ispartof2010-2019 - Mines Theses & Dissertations
dc.rightsCopyright of the original work is retained by the author.
dc.subjecthysteresis
dc.subjectenhanced oil recovery
dc.subjectcarbon dioxide
dc.subjectcompositional simulation
dc.subjecttrapping
dc.subjectreservoir simulation
dc.subject.lcshEnhanced oil recovery
dc.subject.lcshSimulation methods
dc.subject.lcshCarbon dioxide
dc.subject.lcshOil field flooding
dc.subject.lcshCarbon sequestration
dc.subject.lcshHysteresis
dc.subject.lcshPermeability
dc.titleCompositional simulation model for carbon dioxide flooding with improved fluid trapping, A
dc.typeText
dc.contributor.committeememberLusk, Mark T.
dc.contributor.committeememberOzkan, E.
dc.contributor.committeememberSarg, J. F. (J. Frederick)
dc.contributor.committeememberWu, Yu-Shu
thesis.degree.nameDoctor of Philosophy (Ph.D.)
thesis.degree.levelDoctoral
thesis.degree.disciplinePetroleum Engineering
thesis.degree.grantorColorado School of Mines


Files in this item

Thumbnail
Name:
Brown_mines_0052E_10621.pdf
Size:
4.562Mb
Format:
PDF
Description:
A compositional simulation model ...

This item appears in the following Collection(s)

Show simple item record