Experimental Estimation of Relative Permeabilities Through Computed Tomography
- Andrés Felipe Ortiz Meneses (Universidad Industrial de Santander) | Luis Felipe Carrillo M. (Universidad Industrial de Santander) | Edwar Hernando Herrera Otero (Universidad Industrial de Santander) | Nicolás Santos Santos (Universidad Industrial de Santander)
- Document ID
- Society of Petrophysicists and Well-Log Analysts
- SPWLA 60th Annual Logging Symposium, 15-19 June, The Woodlands, Texas, USA
- Publication Date
- Document Type
- Conference Paper
- 2019. held jointly by the Society of Petrophysicists and Well Log Analysts (SPWLA) and the submitting authors
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- 132 since 2007
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Through the mechanical integration of an X-ray computed tomography (CT) scanner and a coreflooding system, images can be obtained during all the time while performing a waterflooding experiment on a rock sample. These images are used to estimate in-situ saturation profiles, therefore, the displacement front movement and the fluids distribution in the different stages can be seen.
A software tool is implemented, which allows simulation and automatic history match of the experimental differential pressure, the oil production and the saturation profiles calculated with CT. This software is programmed in Matlab environment and it uses numerical optimization methods to minimize the difference between the observed and the simulated data.
The method can be used to analyze any unsteady-state experiment of relative permeabilities, and it does not present the restrictions of other classical analysis methods such as the JBN. It is fast, precise, exact and due to the configuration implemented in this work, it is possible to work under reservoir pressure and temperature conditions (up to 10000 psi and 150° c).
The results indicate that including saturation profiles in the calculation can be useful to improve the accuracy of the estimated relative permeabilities. Similarly, it is found that the history matching approach offers remarkable strengths over traditional methods such as the JBN. It is determined that the estimated saturations by means of tomography present errors lower than 3% in comparison with the material balance. The application of this technology produces a better and easier estimation of the relative permeabilities, reduction of the uncertainty in the predictions about the performance of the reservoir. The visualization of the displacement font improves the qualitative understanding of the phenomena related to the fluids flow in porous media.
Multiphase flow in the porous medium is a great importance phenomenon for the correct reservoir modeling, because it occurs during most of its productive life and is vital for the correct prediction of the performance of the different processes as waterflooding.
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