Effect of the Pore Size Distribution on the Displacement Efficiency of Multiphase Flow in Porous Media

Yang, Yongfei; Liu, Pengfei; Zhang, Wenjie; Liu, Zhihui; Sun, Hai; Zhang, Lei; Zhao, Jianlin; Song, Wenhui; Liu, Lei; An, Senyou; Ye, Jun

doi:10.1515/phys-2016-0069

Cited by 13 publications

(9 citation statements)

References 21 publications

(23 reference statements)

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“…The concept of the mean hydraulic-unit radius is a significant approach to determine the hydraulic unit, based on appropriate relationships between capillary pressure, porosity, permeability, and geological variation in the reservoir rock 4) .…”

Section: Characterization Of Hydraulic Unitmentioning

confidence: 99%

Application of Hydraulic Flow Unit for Pore Size Distribution Analysis in Highly Heterogeneous Sandstone Reservoir: A Case Study

Ismail

Yasin

2018

J. Jpn. Petrol. Inst.

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Verifiable and accurate prediction of reservoir pore sizes from well logs in a well with no previous exposure of core data is the desirable outcome for any technique intended to estimate pore size. Many methods are based on core and crushed rock samples such as thin section analysis, scanning electron microscope (SEM) and mercury intrusion capillary pressure (MICP) to characterize pore features but these methods are not commonly used because of their high cost. This study introduces a cost-effective approach to establish a relationship between hydraulic flow unit and pore size distribution using routine core analysis data and geophysical well logs. Multiparameter cluster analysis is used to classify the reservoir rock volume into hydraulic flow unit with similar rock characteristics using reservoir quality index (RQI) and flow zone indicators. Well log and core analysis data were used to identify the hydraulic flow unit in the reservoir interval. The discriminant approach was then applied to the predicted hydraulic flow unit to access the range of pore sizes. The predicted hydraulic flow unit with high porosity and permeability and high RQI revealed a range of pore sizes (macro and mega pores). Comparing the obtained results with high-resolution rock thin section study and available empirical approaches indicated verifiable and satisfactory results. The study can extrapolate the pore size information vertically as well as in the neighboring wells in a quite simple and economical way.

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Section: Characterization Of Hydraulic Unitmentioning

confidence: 99%

Application of Hydraulic Flow Unit for Pore Size Distribution Analysis in Highly Heterogeneous Sandstone Reservoir: A Case Study

Ismail

Yasin

2018

J. Jpn. Petrol. Inst.

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“…Place the core into a core holder; CT scanning is used to obtain an accurate and complete pore structure of the dry core (Ioannidis et al, 1995;Hou et al, 2007;Hajizadeh et al, 2011;An et al, 2016;Bultreys et al, 2016;Yang et al, 2016a). It is important to note that the scanning resolution of this study is 3.78 µm/pixel, and the reconstructed 3D gray digital core is shown in Fig.…”

Section: Ct Scan Of a Dry Rock Samplementioning

confidence: 99%

“…As a result, CT has now become an indispensable tool to understand competing phase displacement mechanisms and to characterize fluid phase configurations in laboratory setups that mimic reservoir in-situ conditions and reservoir operational conditions (Sedgwick and Miles-Dixon, 1988). There has been a surge of applications of CT technology in this specific area (Bekri et al, 2005;Arns et al, 2007;Yao et al, 2013;Yang et al, 2015;Arzilli et al, 2016;Yang et al, 2016a;Yang et al, 2016b), and this trend is expected to continue along with the improvement of CT technology and experimental techniques to study fluid phase displacements in more geologically complex reservoirs (e.g. high-temperature and high-pressure reservoir).…”

Section: Introductionmentioning

confidence: 99%

“…Wildenschild and Sheppard, 2013;Berg et al, 2014;Pak et al, 2015;Norouzi Apourvari and Arns, 2016;Tsuji et al, 2016). The quantitative characterization of flow through a porous medium was carried out (Auzerais et al, 1991), a systematic investigation of fluid flow characteristics within diatomite was performed using CT (Akin et al, 2000), the effect of the pore size distribution on the displacement efficiency of multiphase flow in porous media was studied (Yang et al, 2016a), and the multiphase-flow properties of fractured porous media were studied using a laboratory flow apparatus in fractured sandstone systems (Rangel-German et al, 2006), these are the foundation for the quantitative characterization of remaining oil.…”

Section: Introductionmentioning

confidence: 99%

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Pore-scale remaining oil distribution under different pore volume water injection based on CT technology

Liu

Yang

et al. 2017

Adv. Geo-Energ. Res.

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A water-injection experiment was performed on a water-wet reservoir core plug that was filled with brine first and then displaced by synthetic oil. A X-ray Computed Tomography (CT) was used to take snapshots of the process of oil-water displacement at predefined time intervals to characterize the distribution of remaining oil. The quasi-real time images were used to understand the pore-scale phase displacement mechanisms and the distributional pattern of the remaining oil. Four forms of the distributional patterns, i.e. network, porous, isolated and film shape, were observed and analyzed with respect to the injected pore volumes (PV). The results show that with the increased level of water injection, the volume of the oil phase continuously decreases, and the morphology of the oil phase changes from initial continuous network-like to film shape forms. At 15 pore volumes (PV), the network-like remaining oil disappears and transforms into isolated and film-like forms. The statistics of the volume for each form of the remaining oil show that the isolated blobs increase with increasing water injection, by contrast, the average volume of the remaining oil decreases with increasing water injection. The rate of volumetric changes is fast before 5 PV but slow in the later period.Keywords: CT, pore scale, digital core, remaining oil distribution, quasi real time.Citation: Liu, Z., Yang, Y., Yao, J., et al. Pore-scale remaining oil distribution under different pore volume water injection based on CT technology.

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“…The prediction of foam performance was investigated using population-balance models (Du et al 2017;Falls et al 1988;Kovscek et al 1995;Schramm 1994;Kovscek et al 1997;Patzek 1986) and fractional flow models (Gassara et al 2017;Rossen and Zhou 1995;Zhou and Rossen 1994) as the principal foam-modeling methods. Nevertheless, other numerical works have been accomplished such as using digital rock physics (DRP) technology to examine foam flow behavior in a complex pore geometry (Yang et al 2016;Shojaei et al 2018;Du et al 2014). Dholkawala et al (2007) suggested that increasing the total injection velocity would change the form of fractional flow curves, which successively would affect volumetric sweep efficiency and pressure distribution.…”

Section: Introductionmentioning

confidence: 99%

Impact of pertinent parameters on foam behavior in the entrance region of porous media: mathematical modeling

2020

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Foam injection is a promising solution for control of mobility in oil and gas field exploration and development, including enhanced oil recovery, matrix-acidization treatments, contaminated-aquifer remediation and gas leakage prevention. This study presents a numerical investigation of foam behavior in a porous medium. Fractional flow method is applied to describe steady-state foam displacement in the entrance region. In this model, foam flow for the cases of excluding and including capillary pressure and for two types of gas, nitrogen (N 2) and carbon dioxide (CO 2) are investigated. Effects of pertinent parameters are also verified. Results indicate that the foam texture strongly governs foam flow in porous media. Required entrance region may be quite different for foam texture to accede local equilibrium, depending on the case and physical properties that are used. According to the fact that the aim of foaming of injected gas is to reduce gas mobility, results show that CO 2 is a more proper injecting gas than N 2. There are also some ideas presented here on improvement in foam displacement process. This study will provide an insight into future laboratory research and development of full-field foam flow in a porous medium.

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Effect of the Pore Size Distribution on the Displacement Efficiency of Multiphase Flow in Porous Media

Cited by 13 publications

References 21 publications

Application of Hydraulic Flow Unit for Pore Size Distribution Analysis in Highly Heterogeneous Sandstone Reservoir: A Case Study

Application of Hydraulic Flow Unit for Pore Size Distribution Analysis in Highly Heterogeneous Sandstone Reservoir: A Case Study

Pore-scale remaining oil distribution under different pore volume water injection based on CT technology

Impact of pertinent parameters on foam behavior in the entrance region of porous media: mathematical modeling

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