Discontinuous and continuous Galerkin methods for compressible single-phase and two-phase flow in fractured porous media

Ma, Tianran; Zhang, Keni; Shen, Weijun; Guo, Chaobin; Xu, Hao

doi:10.1016/j.advwatres.2021.104039

Cited by 37 publications

(25 citation statements)

References 44 publications

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“…In order to ensure the reliability of the proposed diffusion model and coupled model, both of them are verified by experimental results or field test data. In the verification of nonlinear diffusion model, two groups of accurate laboratorial data derived by Ma et al [45] and Charriere et al [46] are used to compare with the fitting curves. Additionally, field history data of methane is adopted to achieve the calibration of the coupled model and its implementation into COMSOL Multiphysics.…”

Section: Model Validationmentioning

confidence: 99%

“…Validation of the Nonlinear Diffusion Model. Ma et al [45] conducted a series of experiments to investigate the gas diffusion behavior under different conditions in coal. Coal samples used in the paper originates from the Lorraine basin, France.…”

Section: Model Validationmentioning

confidence: 99%

“…During the experiment, the whole diffusion processes of pure CH4 were measured at the temperature of 298.15 K (25 °C) and at pressures of 0.1 MPa and 5.0 MPa, respectively. Based on our proposed nonlinear diffusion model, the fitting results between theoretical value of diffusion coefficient and experimental data from Ma et al [45] are shown in Figure 5(a).…”

Section: Model Validationmentioning

confidence: 99%

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Nonlinear Diffusion-Based Multifield Coupling Model for Thermally Enhanced CBM Recovery

Yang

Liu

2022

Geofluids

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Thermal stimulation is a supplementary technique for enhancing gas recovery from coalbed methane (CBM) reservoirs that has received considerable attention worldwide. Investigating gas and heat transfer in coal seams during thermally enhanced CBM recovery is of great significance for predicting gas production and optimizing the extraction method. Gas diffusion in the coal matrix and coupled multiphysics are two of the most important aspects when analyzing gas migration and heat transport. However, previous studies either neglected the nonlinear diffusion process of gas or only assumed that the diffusion coefficient varies with production time. However, considerable experimental results indicate that the gas diffusion coefficient is not only determined by time but also by temperature, which strongly impacts multifield interaction during gas recovery. Thus, prior diffusion models and coupled models must be modified. In this paper, a time-and-temperature-dependent gas diffusion model is established based on fractal theory and experimental data. The proposed diffusion model is embedded into the coupled thermal-hydro-mechanical model to comprehensively describe the behavior of coal deformation, gas migration, and heat transport during CBM recovery. Additionally, both new diffusion model and coupled model were validated with experimental results or field test data, showing that these developed models are applicable for modeling long-term gas diffusion and gas production. Finally, the coupled model was implemented into COMSOL Multiphysics software, and a series of numerical simulations were conducted. The calculation results showed that heat injection could promote gas desorption and diffusion in the matrix while inhabiting gas flow in fractures near the injection well. Gas dynamic diffusion could inhabit gas migration in both matrix system and fracture system at a later production stage. This also means that ignoring the gas nonlinear diffusion process leads to a severe overestimation of coal permeability and gas production.

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Section: Model Validationmentioning

confidence: 99%

Section: Model Validationmentioning

confidence: 99%

Section: Model Validationmentioning

confidence: 99%

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Nonlinear Diffusion-Based Multifield Coupling Model for Thermally Enhanced CBM Recovery

Yang

Liu

2022

Geofluids

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“…Surfactant flooding can use crude oil that cannot be recovered only by water flooding, effectively reducing the remaining oil saturation in reservoir and playing an important role in tertiary oil recovery. With the development of many oil fields entering the middle and late stages, the available resources of conventional reservoirs are becoming less and less, and it is more difficult to further enhance oil recovery [2,3].…”

Section: Introductionmentioning

confidence: 99%

Viscoelastic Oil Displacement System of Modified Silica Nanoparticles/Zwitterionic Surfactant for High Salinity Reservoir

et al. 2022

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Polymer flooding and polymer/surfactant flooding have achieved good efficiency in the application of conventional reservoir, but the existed chemical flooding technology cannot cannot address the issues of the requirements of chemical flooding in high salinity reservoir. Under the condition of high salinity reservoir, due to the increase of calcium and magnesium ions, the increasing viscosity effect of oil displacement system is lost. In order to study the feasibility of applying nanomaterials in the field of enhanced oil recovery under the conditions of high salinity reservoir, develop a low-concentration and high-efficiency oil displacement system. EAPC solution has advantages in reducing interfacial tension, but its viscosity is not good. Therefore, hydrophobically modified silica nanoparticles (SiO2 NPs) were added to the carboxylic acid–type erucic acid amide propyl betaine (EAPC) solution. The interaction between EAPC and hydrophobic carbon chains led to the exposure of carboxyl groups, thus making the system more stable. The interfacial activity and zeta potential were studied, and the interaction mechanism between modified SiO2 NPs and EAPC was obtained. The results show that when the EAPC concentration is 0.3%, the apparent viscosity of the modified silica nanoparticles (SiO2 NPs) composite system can reach 40 mPa·s, and the oil-water interfacial tension can be reduced to 10-2 mN/m. The micro-visualization model and the simulated oil displacement experiment proved that the modified SiO2 NPs (0.3%)/EAPC (0.3%) composite system has a variety of oil displacement mechanisms. Under the simulated reservoir conditions (total salinity of 25000 mg/L, calcium and magnesium ion concentration of 500 mg/L, 70 °C), it is proved that the modified SiO2 NPs composite system had good viscoelasticity and improved oil washing efficiency. The oil displacement system has guiding significance for effectively enhancing the recovery of high salinity reservoir.

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“…At present, horizontal well technology combined with segmented multi-stage fracturing technology is commonly used worldwide to achieve efficient development of tight oil reservoirs (Jiang et al, 2017;Zhang, 2020;Guo et al, 2021;Zheng et al, 2021), and the recovery rate can be improved by increasing the stimulated reservoir volume. However, the fracture expansion of tight oil reservoirs is influenced by their own geological conditions with diverse situations (Zhao et al, 2015;Peng et al, 2016;Zhao et al, 2017;Li et al, 2020;Peng et al, 2020), some reservoirs are strongly heterogeneity with positive and reverse rhythm in the vertical direction (Li et al, 2019a;Zhang et al, 2022b), and the two-phase or even three-phase seepage is superimposed on the influence of engineering factors on the development process (Ma et al, 2021;Shen et al, 2022), which makes the seepage mechanism and development law of tight reservoirs very complex (Zafar et al, 2020;Zhao et al, 2021), and the dominant seepage channel is not clear (Li et al, 2019b). At present, the relevant research is still at the core scale (Jing et al, 2021)…”

Section: Introductionmentioning

confidence: 99%

Study on the development options of tight sandstone oil reservoirs and their influencing factors

Huang

et al. 2022

Front. Energy Res.

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The research area of tight sandstone oil reservoirs was selected, a numerical model of the oil reservoir was developed, and a study of the development options and influencing factors was carried out to analyze the influence of different development methods, physical and engineering parameters on the development dynamics. Study shows that the two main factors limiting the efficient development of tight sandstone reservoirs are reservoir properties and formation energy. Fractured horizontal well injection huff and puff development can effectively improve reservoir physical properties and timely replenish formation energy, which is suitable for the development of such oil reservoirs. In dense sandstone reservoirs, its impact on production capacity is also relatively small when the permeability ratio is small. Due to both gravity and reservoir physical properties, the permeability ratio increases, the cumulative oil production of positive rhythm reservoirs decreases and that of reverse rhythm reservoirs increases, and the location of high-quality reservoirs in the upper part of producing wells is conducive to increasing the final recovery rate. A lower oil to water viscosity ratio can significantly increase the swept volume and improve development effect. Hydrophilic reservoirs can reduce the injection pressure and increase the spread range, effectively improving the problem of inability to inject, and improving reservoir hydrophilicity through surface activators can increase reservoir recovery. The water injection rate determines the recovery rate of formation energy. Generally, the faster the rate, the higher the cumulative oil production. Therefore, the rate of water injection should be increased as much as possible, taking into account construction conditions and economic evaluation. Additionally, the effect of water injection on the development effect is different at different stages, so the appropriate timing of water injection is very important to the water injection huff and puff development effect, and the use of early water injection in this research area is not conducive. Soaking can promote pressure and fluid redistribution and improve water injection huff and puff development effect, but soaking for a long time can lead to reservoir contamination and reduce crude oil production, so the preferred time for a soaking is about 20 days.

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Discontinuous and continuous Galerkin methods for compressible single-phase and two-phase flow in fractured porous media

Cited by 37 publications

References 44 publications

Nonlinear Diffusion-Based Multifield Coupling Model for Thermally Enhanced CBM Recovery

Nonlinear Diffusion-Based Multifield Coupling Model for Thermally Enhanced CBM Recovery

Viscoelastic Oil Displacement System of Modified Silica Nanoparticles/Zwitterionic Surfactant for High Salinity Reservoir

Study on the development options of tight sandstone oil reservoirs and their influencing factors

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