Foam assisted surfactant-gas flooding in naturally fractured carbonate reservoirs
| dc.contributor.advisor | Sepehrnoori, Kamy, 1951- | |
| dc.contributor.committeeMember | Lashgari, Hamid Reza | |
| dc.creator | Aygol, Hayrettin | |
| dc.creator.orcid | 0000-0001-8375-1157 | |
| dc.date.accessioned | 2018-02-28T17:54:42Z | |
| dc.date.available | 2018-02-28T17:54:42Z | |
| dc.date.created | 2017-12 | |
| dc.date.issued | 2018-01-26 | |
| dc.date.submitted | December 2017 | |
| dc.date.updated | 2018-02-28T17:54:43Z | |
| dc.description.abstract | In naturally fractured reservoirs, water flood performance and efficiency for oil recovery is usually limited by capillary forces. Wettability and interfacial tension (IFT) between oil and water phases are essential factors that limit the potential for oil production in naturally fractured reservoirs. The permeability of such reservoirs is in range of 1~20 md (majority of carbonate reservoirs) with the matrix wettability preferentially oil-wet to mixed-wet. Hence, water and/or gas flood performances are not efficient due to the tendency of water or gas flow through fractures. Surfactants are used to reduce IFT between oil and water, alter the wettability of matrix to proficiently water-wet, and generate in-situ foam as a drive and for mobility control. Spontaneous imbibition between the fractures and the matrix is achieved by both wettability alteration and ultra-low interfacial tensions. Experimental studies show that co-injection or alternate injection of surfactant solution and gas are very promising to mobilize and solubilize the remaining oil. In this study, we overview to provide a technical background and review the literature extensively in order to understand surfactant flooding and foam performance in porous media. Results show that surfactants are induced to matrix through fractures not only by spontaneous imbibition, but also by foam that diverts surfactant solutions into low permeability matrix. The finding results by several authors in lab-scale indicate that surfactant type, foam properties, capillary pressure properties corresponding to different wetting states, and oil-water interfacial tension are crucial factors that significantly impact the efficiency of such processes. In general, summary of this work shows that foam plays a dominant role as a drive to displace the oil in matrix when capillary forces are not strong to retain the oil in presence of surfactants. Although there is very restricted work that claim foam efficiency in presence of oil, mobilized oils are displaced and moved toward fractures as pure oil bank (oil phase). Some laboratory measurements and simulation study reveal with both core and reservoir scales that such process provides great sweep efficiency and recover a significant amount of remaining oil from the matrix to fracture. | |
| dc.description.department | Petroleum and Geosystems Engineering | |
| dc.format.mimetype | application/pdf | |
| dc.identifier | doi:10.15781/T2ZC7SB3N | |
| dc.identifier.uri | http://hdl.handle.net/2152/63774 | |
| dc.language.iso | en | |
| dc.subject | Surfactants | |
| dc.subject | Foam generation | |
| dc.subject | Naturally fractured reservoirs | |
| dc.subject | Interfacial tension reduction | |
| dc.subject | Wettability alteration | |
| dc.subject | Mobility control | |
| dc.title | Foam assisted surfactant-gas flooding in naturally fractured carbonate reservoirs | |
| dc.type | Thesis | |
| dc.type.material | text | |
| thesis.degree.department | Petroleum and Geosystems Engineering | |
| thesis.degree.discipline | Petroleum Engineering | |
| thesis.degree.grantor | The University of Texas at Austin | |
| thesis.degree.level | Masters | |
| thesis.degree.name | Master of Science in Engineering |