Wettability and Relative Permeability of Lower Cretaceous Carbonate Rock Reservoir, Saudi Arabia

Okasha, Taha; Funk, James J.; Al-Enezi, S. M.

doi:10.2118/81484-ms

Cited by 24 publications

(9 citation statements)

References 16 publications

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“…Rock Quality Influence on Wettability. Several researchers have observed that the extent of wettability alteration towards oil-wet in Middle East carbonates is inversely correlated to the amount of microporosity in the rock (Marzouk et al 1995;Okasha et al 2003). To investigate this hypothesis, we have plotted the invaded zone n exponent against the fraction of total pore volume that is in the micropores.…”

Section: Analysis Of Dielectric Log Datamentioning

confidence: 99%

Integration of Dielectric Dispersion and 3D NMR Characterizes the Texture and Wettability of a Cretaceous Carbonate Reservoir

et al. 2013

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Knowledge of rock texture and wettability are vital for the static and dynamic description of carbonate reservoirs. Conventional log measurements are limited in their applicability for the quantitative assessment of these attributes. Rapid variations of texture in carbonates diminishes the usefulness of core measurements on samples of limited size. Obtaining representative relative permeability by restoring core to native reservoir conditions, especially the original wettability state, is also very challenging.The dielectric response of clean carbonate rocks exhibit characteristic frequency dispersion patterns which depend on their texture and wettability. Dielectric measurements with multiple frequencies have become available enabling us to extract this information by inverting the tool data using a dispersive petrophysical model.The dielectric response is primarily sensitive to water, and provides a measure of the water phase tortuosity, which is a combination of texture and wettability, captured in the Archie's exponents m and n. Previous work has demonstrated the estimation of m from pore size distribution obtained from NMR data using an effective medium model. Formation Resistivity Factor data from core is presented to validate the model-derived m. In this work we propose a way to combine the cementation exponent so derived with the textural answers from the dielectric measurement to make a wettability estimate. We also assess the wettability from 3D NMR stations, using the increase in relaxation of oil manifested as shortening of the oil T 2 signal due to partial wetting of the oil phase. The methods are illustrated on a dataset from a Cretaceous carbonate, onshore Abu Dhabi. The interval surveyed in the subject well straddles an oil/water contact (OWC). The n exponent value derived by the method shows that the rock above the OWC is oil-wet in varying degrees. The inference on wettability state from the NMR data further supports the conclusions.

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Section: Analysis Of Dielectric Log Datamentioning

confidence: 99%

Integration of Dielectric Dispersion and 3D NMR Characterizes the Texture and Wettability of a Cretaceous Carbonate Reservoir

et al. 2013

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“…After the composite core was aged with dead and live oil, it was expected to be weak oil–wet or mixed wet behavior for such carbonate rocks. 51 , 52 …”

Section: Experimental Workmentioning

confidence: 99%

Effect of Conformance Control Patterns and Size of the Slug of In Situ Supercritical CO₂ Emulsion on Tertiary Oil Recovery by Supercritical CO₂ Miscible Injection for Carbonate Reservoirs

et al. 2020

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The reservoir heterogeneity is the major cause of poor volumetric sweep efficiency in sandstone and carbonate reservoirs. Displacing fluids (water, chemical solution, gas, and supercritical CO 2 (sc-CO 2 )) flow toward the high permeable zone. A significant fraction of oil remains in the low permeable zone due to the permeability contrast. This study used in situ sc-CO 2 emulsion as a conformance control agent to plug the high permeable zone and improve the low permeable zone's volumetric sweep efficiency in carbonate formation. We investigated the effect of two types of conformance control patterns and the size of sc-CO 2 emulsion on tertiary oil recovery performance by sc-CO 2 miscible injection for carbonate reservoirs at reservoir conditions. The conformance control patterns are achieved using two different approaches. In the first approach, the low permeable zone was isolated, and the diverting gel system, a 0.4 pore volume slug, was injected into a high permeable zone. In the second approach, the simultaneous injection of the diverting gel system, a 0.2 pore volume slug, was done on both the low and high permeable zones. The first sc-CO 2 injection was conducted as a tertiary oil recovery mode to recover the remaining oil after water flooding. The diverting gel system was injected after the first sc-CO 2 flood for the conformance control. The second or post sc-CO 2 injection was conducted after the diverting gel system injection. The diverting gel system used in this study consisted of a polymer and a surfactant. An in situ emulsion was generated when the injected diverting gel system interacts with the sc-CO 2 in the core plug. Results obtained from dual-core core flooding experiments suggested that the in situ sc-CO 2 emulsion was generated successfully in the formation based on the different pressure increases and observation of the dual-core core flooding experiments. The volumetric sweep efficiency and oil recovery in both conformance control patterns were improved. The production performances were also compared for both conformance control models before and after the diverting gel system injection. The conformance control model 2 (simultaneous injection of the diverting gel system into low and high permeability cores) has a better choice to be applied in field application due to high recovery with a small sc-CO2 emulsion easy operation in the field.

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“…A relative permeability and wettability study was reported for a Lower Cretaceous carbonate by Okasha [4]. Samples of 1.5 in.…”

Section: B General Carbonate Core Samples Studiesmentioning

confidence: 99%

The Effect of Vug Density on Fluid Flow

Zhan-guo

2009

2009 International Conference on Computational Intelligence and Software Engineering

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Abstract-Fractured vuggy reservoirs have long been observed. A thorough understanding of the variability and fluid flow in fractured vuggy carbonates is lacking. Classical theories of fluid flow are not applicable for highly heterogeneous carbonates. Therefore, it is necessary to conduct research on this type of carbonate which is found in many petroleum reservoirs. Singlephase flow in fractured vuggy media is studied by finite element method. The purpose of this study is to obtain phenomenological data (streamlines, velocity and pressure) during flow in a fractured vuggy media to better understand the effect of vug density on flow. Numerical simulation on fractured vuggy model with different vug density are suggested that gravitational impact on flow is more significant in vugs; in identical horizontal plane, velocity in vug is less than velocity in fracture; pressure drop between the both sides of model with bigger vug density is less.

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Wettability and Relative Permeability of Lower Cretaceous Carbonate Rock Reservoir, Saudi Arabia

Cited by 24 publications

References 16 publications

Integration of Dielectric Dispersion and 3D NMR Characterizes the Texture and Wettability of a Cretaceous Carbonate Reservoir

Integration of Dielectric Dispersion and 3D NMR Characterizes the Texture and Wettability of a Cretaceous Carbonate Reservoir

Effect of Conformance Control Patterns and Size of the Slug of In Situ Supercritical CO₂ Emulsion on Tertiary Oil Recovery by Supercritical CO₂ Miscible Injection for Carbonate Reservoirs

The Effect of Vug Density on Fluid Flow

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Wettability and Relative Permeability of Lower Cretaceous Carbonate Rock Reservoir, Saudi Arabia

Cited by 24 publications

References 16 publications

Integration of Dielectric Dispersion and 3D NMR Characterizes the Texture and Wettability of a Cretaceous Carbonate Reservoir

Integration of Dielectric Dispersion and 3D NMR Characterizes the Texture and Wettability of a Cretaceous Carbonate Reservoir

Effect of Conformance Control Patterns and Size of the Slug of In Situ Supercritical CO2 Emulsion on Tertiary Oil Recovery by Supercritical CO2 Miscible Injection for Carbonate Reservoirs

The Effect of Vug Density on Fluid Flow

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Effect of Conformance Control Patterns and Size of the Slug of In Situ Supercritical CO₂ Emulsion on Tertiary Oil Recovery by Supercritical CO₂ Miscible Injection for Carbonate Reservoirs