Change search
ReferencesLink to record
Permanent link

Direct link
Simulation of Surfactant EOR in a Mechanistic Model with Fracture and Ekofisk Properties
Norwegian University of Science and Technology, Faculty of Engineering Science and Technology, Department of Petroleum Engineering and Applied Geophysics.
2014 (English)MasteroppgaveStudent thesis
Abstract [en]

Large amounts of oil are left in reservoirs after primary and secondary recovery. To recovery as much of the remaining oil as possible, EOR techniques as chemical flooding is considered. Naturally fractured carbonates have often large amount of residual oil left in the reservoir after primary and secondary production periods. Carbonates are in general more complex reservoirs than sandstones, thus must recovery methods be tailored for the environment of the reservoir system. Chemical EOR has become more attractive after the financial crisis in 2008 because of the high oil prices. Ekofisk is naturally fractured chalk reservoir, and is the largest, oldest and longest producing reservoir on Norwegian continental shelf. To improve the recovery is surfactant injection considered as a possible EOR method. A mechanist reservoir model with Ekofisk reservoir properties and a single fracture was made with the purpose to investigate the potential of surfactant injection in Ekofisk. Several parameters that effect the performance of surfactants was investigated and the recovery results were compared with a waterflood basecase. In addition was a mechanistic model with four fractures made for further investigation of surfactant flow in a fracture network and for comparison of the performance of a surfactant flood with surfactant-polymer flood. The author’s simulation results show that surfactant injection should be considered for the field, but more research with a more advanced reservoir model with respect to possible wettability alteration, a larger fracture network and heterogeneity should be done. The model shows poor sweep efficiency in layers far from the fracture in the model, thus should an eventual chemical flood in Ekofisk be considered done with polymers. Surfactant concentration in the injection solution affects the surfactant performance the most. For the single fracture model is the recovery increased with 2,8% when surfactants are injected, and NPV was increased with 8,31E+06 $. For the 9-block model with four fractures, was the recovery improved with 3% for the surfactant-polymer flood compared with a surfactant flood. Also the NPV was increased with 3,71E+06$.

Place, publisher, year, edition, pages
Institutt for petroleumsteknologi og anvendt geofysikk , 2014. , 141 p.
URN: urn:nbn:no:ntnu:diva-25910Local ID: ntnudaim:11259OAI: diva2:742164
Available from: 2014-08-31 Created: 2014-08-31 Last updated: 2014-08-31Bibliographically approved

Open Access in DiVA

fulltext(2838 kB)1029 downloads
File information
File name FULLTEXT01.pdfFile size 2838 kBChecksum SHA-512
Type fulltextMimetype application/pdf
cover(184 kB)2 downloads
File information
File name COVER01.pdfFile size 184 kBChecksum SHA-512
Type coverMimetype application/pdf

By organisation
Department of Petroleum Engineering and Applied Geophysics

Search outside of DiVA

GoogleGoogle Scholar
Total: 1029 downloads
The number of downloads is the sum of all downloads of full texts. It may include eg previous versions that are now no longer available

Total: 124 hits
ReferencesLink to record
Permanent link

Direct link