Gas Bubble Migration and Trapping in Porous Media: Pore‐Scale Simulation

Mahabadi, Nariman; Zheng, Xianglei; Yun, Tae Sup; Paassen, Leon A. van; Jang, Jae‐Won

doi:10.1002/2017jb015331

Cited by 61 publications

(27 citation statements)

References 47 publications

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“…This section will study the impact of shale gas solubility on the shale gas production rate. The shale gas solubilities are taken as 1.16, 5.42, and 10 5 . The values of 1.16 and 5.42 for gas solubility are taken from the experimental data obtained by Fu et al [9].…”

Section: Impact Of Shale Gas Solubility In Water On the Shale Gasmentioning

confidence: 99%

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Iterative Analytical Solutions for Nonlinear Two-Phase Flow with Gas Solubility in Shale Gas Reservoirs

2019

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The governing equations of a two-phase flow have a strong nonlinear term due to the interactions between gas and water such as capillary pressure, water saturation, and gas solubility. This nonlinearity is usually ignored or approximated in order to obtain analytical solutions. The impact of such ignorance on the accuracy of solutions has not been clear so far. This study seeks analytical solutions without ignoring this nonlinear term. Firstly, a nonlinear mathematical model is developed for the two-phase flow of gas and water during shale gas production. This model also considers the effects of gas solubility in water. Then, iterative analytical solutions for pore pressures and production rates of gas and water are derived by the combination of travelling wave and variational iteration methods. Thirdly, the convergence and accuracy of the solutions are checked through history matching of two sets of gas production data: a China shale gas reservoir and a horizontal Barnett shale well. Finally, the effects of the nonlinear term, shale gas solubility, and entry capillary pressure on the shale gas production rate are investigated. It is found that these iterative analytical solutions can be convergent within 2-3 iterations. The solutions can well describe the production rates of both gas and water. The nonlinear term can significantly affect the forecast of shale gas production in both the short term and the long term. Entry capillary pressure and shale gas solubility in water can also affect shale gas production rates of shale gas and water. These analytical solutions can be used for the fast calculation of the production rates of both shale gas and water in the two-phase flow stage.

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Section: Impact Of Shale Gas Solubility In Water On the Shale Gasmentioning

confidence: 99%

“…At the last two stages, both gas and water simultaneously flow to the wellbore. The two-phase flow in these stages has significant influence on the gas production life because of complex interactions between gas and water [5]. Therefore, transport behaviors and mechanisms should be carefully studied for gas production forecast.…”

Section: Introductionmentioning

confidence: 99%

Iterative Analytical Solutions for Nonlinear Two-Phase Flow with Gas Solubility in Shale Gas Reservoirs

2019

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“…Nanoparticles adsorbed at the interface between two fluids contribute to stabilize an emulsion (e.g., water‐in‐carbon dioxide, carbon dioxide‐in‐water, air‐in‐water, oil‐in‐water) . The stabilized droplets armored by the nanoparticles at the interface do not tend to coalesce to each other, which could be applied to modify the properties of sediment and fluid by controlling gas bubble migration and trapping in porous media …”

Section: Background – Literature Reviewmentioning

confidence: 99%

“…13,68 The stabilized droplets armored by the nanoparticles at the interface do not tend to coalesce to each other, which could be applied to modify the properties of sediment and fluid by controlling gas bubble migration and trapping in porous media. [69][70][71]…”

Section: Characteristic Behavior Of Nanoparticlesmentioning

confidence: 99%

Interfacial tension and contact angle in CO₂‐water/nanofluid‐quartz system

Zheng¹,

Barrios

Perreault

et al. 2018

Greenhouse Gases

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Nanoparticles can modify the interface properties that are critical for fluid flow in porous media. The interfacial tension (IFT) between CO2 and water and the contact angle (CA) of a water droplet on a mineral surface under high CO2 pressure are critical parameters for CO2‐related applications such as CO2 geological sequestration and CO2‐enhanced resource recovery. This study investigated the IFT and CA in a water‐CO2‐quartz system and a nanofluid (water including either Al2O3 or TiO2 nanoparticles)‐CO2‐quartz system. The values of the IFT and CA were obtained by axisymmetric drop shape analysis (ADSA) for a droplet on a quartz surface in a chamber pressurized with CO2. The effect of nanoparticles on the IFT and CA was explored by comparing the values for the pure water‐CO2‐quartz system. In addition, the effect of CO2 adsorption onto the substrate on the wettability was investigated. The results show that the values of the IFT decrease with increasing CO2 pressure, and the addition of nanoparticles to pure water lowers the IFT further (∼up to a 40% reduction in the liquid CO2 pressure range). The de‐wetting phenomenon was observed for both gaseous and liquid CO2 conditions. © 2018 Society of Chemical Industry and John Wiley & Sons, Ltd.

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“…Noteworthy, yet not addressed this chapter, are feedbacks of the microorganisms on their physical environments. This includes changes of the hydraulic properties of the solid matrix (Hommel et al 2018) due to biomass aggregation (Baveye et al 1998;Yarwood et al 2006;Thullner 2010), or due to microbially induced mineral dissolution, precipitation (Barkouki et al 2011;Ebigbo et al 2012) or gas formation (Mahabadi et al 2018).…”

mentioning

confidence: 99%