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An experimental and numerical study of low salinity effects on the oil recovery of carbonate limestone samples

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An experimental and numerical study of low salinity effects on the oil recovery of carbonate limestone samples (Tienda española)

Felix Feldmann (Autor)


Indice, PDF (530 KB)
Lectura de prueba, PDF (590 KB)

ISBN-13 (Impresion) 9783736971769
ISBN-13 (E-Book) 9783736961760
Idioma Inglés
Numero de paginas 254
Edicion 1.
Lugar de publicacion Göttingen
Lugar de la disertacion Clausthal
Fecha de publicacion 02.03.2020
Clasificacion simple Tesis doctoral
Area Geociencias
Petrología y ciencias de yacimiento
Palabras claves Boundary conditions, Boundary formulation, Capillary pressure, Carbonates, Centrifuge method, Contact angle, Core aging, Core preparation, Coreflooding, Crude oil, Cydar, Diluted sea water, Dumux, Enhanced oil recovery, Forbes first solution, Forced imbibition, Formation water, Hassler Brunner, History matching, Improved oil recovery, Inlet water saturation correction, Interfacial tension, Limestone, Low salinity, Low salinity literature review, Low salinity mechanism, Numerical Modelling, Numerical Simulation, Open source simulator, Outcrops, Relative permeability, Remaining oil saturation, Residual oil saturation, Salinity impact, Sea water, Special core analysis, Special core analysis simulation, Spontaneous imbibition, Surface charge change, Zeta potential, Petroleum Engineering, Reservoir Engineering

Low-salinity waterflooding is a relatively simple and cheap Enhanced oil recovery technique in which the salinity of the injected water is optimized (by desalination and/or modification) to improve oil recovery over conventional waterflooding. The presented study combines spontaneous imbibition, centrifuge method, unsteady state coreflooding and zeta potential experiments to investigate low-salinity effects in carbonate limestones samples.
Compared to Formation-water and Sea-water, Diluted-sea-water caused the significantly highest spontaneous oil recovery. Moreover, the imbibition capillary pressure curves are characterized by an increasing water-wetting tendency and a residual oil saturation reduction, as the salinity of the imbibing brines decreases in comparison to Formation-water. The unsteady state corefloodings resulted in the highest secondary oil recovery when Diluted-sea-water was used as injection water.
Based on the open-source C++ simulator Dumux, the study developed a numerical centrifuge and coreflooding model to history match the experimental data. The numerically derived capillary pressure and relative permeability data confirm a correlation between the system’s salinity, wettability, oil recovery and residual oil saturation.