Determination of In Situ Two-Phase Flow Properties Through Downhole Fluid Movement Monitoring

Kuchuk, Fikri J.; Zhan, Lang; Mark, Shouxiang; Al-Shahri, Ali M.; Ramakrishnan, T.S.; Altundas, Yusuf Bilgin; Zeybek, Murat; Loubens, Romain de; Chugunov, Nikita

doi:10.2118/116068-pa

Cited by 12 publications

(2 citation statements)

References 37 publications

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“…1 to Eq. 4 have been published elsewhere (Ramakrishnan and Wilkinson 1997;Kuchuk et al 2010) for oil-water-salt flow applications, different from the one considered in this paper.…”

Section: Mathematical Modelmentioning

confidence: 99%

Retardation of CO2 due to Capillary Pressure Hysteresis: a New CO2 Trapping Mechanism

et al. 2010

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Trapping of CO 2 improves containment security of geologically stored CO 2 . To be able to asses the potential of a storage site using reservoir simulators, it is necessary to include all of the possible trapping mechanisms in the numerical algorithms. Currently, four trapping mechanisms are identified in the CO 2 sequestration literature: structural, residual, dissolution, and mineralization. Although capillary pressure hysteresis has been accounted for in the historical development of simulators, it has not been recognized as a process for hindering movement of the injected CO 2 . Capillary pressure hysteresis reduces the buoyancy driven plume movement significantly compared to relative permeability hysteresis; but it is the latter that has been emphasized in the published literature. In this paper, we focus on a quantitative measure for the contribution of hysteresis in reducing plume transport. Rocks with large pore body to throat size ratio are the best candidates for this mechanism to be operative.In the present work, a self-consistent relative-permeability capillary-pressure hysteresis model is incorporated within a simulator. With this model, it is possible to compare and contrast hysteresis induced retardation to other mechanisms of trapping. The self-consistent parametrization of all of the transport properties is used to quantify sensitivity compactly. The sensitivity of the CO 2 plume shape and the amount of CO 2 trapped, to the strength of the capillary pressure hysteresis, is also described.Simulated results show that CO 2 plume shape with and without capillary pressure hysteresis are significantly different. As expected, capillary pressure hysteresis retards the buoyant transport of the CO 2 plume. Although a portion of the CO 2 is connected, and therefore not residual, the plume remains immobile for all practical purposes. Also, due to decreased driving potential, gravity tonguing below the caprock is reduced in comparison to the case without capillary pressure hysteresis, thus suggesting enhanced storage efficiency. However, the total dissolution of CO 2 in saline water is reduced because of the reduced diffusive transport of CO 2 within the brine. Thus, one mechanism of containment is offset by the other.Inclusion of accurate hysteresis models is important for qualifying storage sites constrained by spatial domain limits. It is anticipated that site acceptability criteria would change as a result of this study, thus impacting risk evaluation.

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“…1 to Eq. 4 have been published elsewhere (Ramakrishnan and Wilkinson 1997;Kuchuk et al 2010) for oil-water-salt flow applications, different from the one considered in this paper.…”

Section: Mathematical Modelmentioning

confidence: 99%

Retardation of CO2 due to Capillary Pressure Hysteresis: a New CO2 Trapping Mechanism

et al. 2010

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“…Consequently, there has been decades-long process to develop procedures to infer relative permeability from other parameters, such as capillary pressure (Purcell, 1949;Brooks and Corey, 1966;Li and Horne, 2006) and resistivity data (Pirson, et al, 1964;Li, 2007 and2010). Recently, the industry has researched new methods to extract relative permeability in-situ by using specially designed permanent downhole electric resistivity array measurements (Kuchuck, et al, 2008).…”

Section: Introductionmentioning

confidence: 99%

In-situ Estimation of Relative Permeability from Resistivity Measurements

Li¹,

Shapiro²,

Horne³

et al. 2010

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Relative permeability is one of the key parameters governing fluid flow through porous media. Determination of relative permeability is traditionally conducted in the laboratory using either recombined reservoir oil or laboratory oil at simulated reservoir conditions or simply at laboratory room conditions. This is because it is expensive to sample representative uncontaminated reservoir fluids and extremely difficult to cut reservoir cores without altering their surface properties. Restoring rock properties to their original reservoir conditions has been a technical challenge to the industry. Upscaling laboratory special core analysis data to reservoir scale is also a concern. Consequently, the industry has been researching new methods to extract relative permeability in-situ including using specially designed permanent downhole electric resistivity array measurements.In this study, a different approach was taken. A semianalytical model, developed to infer relative permeability from resistivity, was verified using experimental and field data. Relative permeability and resistivity were measured simultaneously in the laboratory. The results demonstrated that relative permeability derived from measured resistivity were close to the measured relative permeability. Relative permeability calculated from resistivity logs in two wells was compared to measured relative permeability with encouraging results. With this approach, it would be possible to obtain a distribution of relative permeability characteristics throughout an entire reservoir for enhanced reservoir engineering studies.

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3D static reservoir modeling by geostatistical techniques used for reservoir characterization and data integration

Soleimani

Shokri

2015

Environ Earth Sci

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Determination of In Situ Two-Phase Flow Properties Through Downhole Fluid Movement Monitoring

Cited by 12 publications

References 37 publications

Retardation of CO2 due to Capillary Pressure Hysteresis: a New CO2 Trapping Mechanism

Retardation of CO2 due to Capillary Pressure Hysteresis: a New CO2 Trapping Mechanism

In-situ Estimation of Relative Permeability from Resistivity Measurements

3D static reservoir modeling by geostatistical techniques used for reservoir characterization and data integration

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