Measurement of dynamic adsorption–diffusion process of methane in shale

Wang, Jinjie; Bu-e, Wang; Li, Yajun; Yang, Zehao; Gong, Hongyu; Dong, Mingzhe

doi:10.1016/j.fuel.2015.12.069

Cited by 96 publications

(45 citation statements)

References 36 publications

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“…The mass change by gas diffusion will decrease with the rising pressure due to the decrease in the compressibility factor of the gas. And the adsorbed gas amount also decreases with the rising pressure as described by adsorption isotherm (Christmann 1991;Wang et al 2016). According to Eq.…”

Section: Effect Of Pressurementioning

confidence: 99%

“…The pressure not only affects the coverage of adsorbed gas, but also influences the adsorption heat, and then impacts the capability of the surface gas transmission (Wu et al 2015;Wang et al 2016). Figure 3 shows the effects of different pressures where four cases were run by varying pressure from 1 to 15 MPa to study CH 4 diffusion and adsorption.…”

Section: Effect Of Pressurementioning

confidence: 99%

“…Since the effect of temperature in the diffusion and adsorption process can be significant, some previous studies have focused on the effect of temperature on fractional site occupancy (Christmann 1991;Wang et al 2016;Shen et al 2017), which directly determines the adsorption gas amount. The desorption of adsorbed gas is an exothermic process, and the temperature influences the capacity of the surface gas transmission (Wu et al 2015).…”

Section: Effect Of Temperaturementioning

confidence: 99%

“…The incremental mass variation attained at 150 • C is also greater than that of lower temperatures in the early stage. At a higher temperature, the gas molecules move faster and have more collisions with the pore surfaces, which results in a greater adsorption rate (Wang et al 2016;Shen et al 2017). The greater gas diffusion rates make the process duration shorter; thus, the 150 • C curve tends to reach equilibrium sooner, which indicates that the higher temperature leads to a more quickly attained process end point.…”

Section: Effect Of Temperaturementioning

confidence: 99%

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Methane Diffusion and Adsorption in Shale Rocks: A Numerical Study Using the Dusty Gas Model in TOUGH2/EOS7C-ECBM

et al. 2018

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Gas production from shale gas reservoirs plays a significant role in satisfying increasing energy demands. Compared with conventional sandstone and carbonate reservoirs, shale gas reservoirs are characterized by extremely low porosity, ultra-low permeability and high clay content. Slip flow, diffusion, adsorption and desorption are the primary gas transport processes in shale matrix, while Darcy flow is restricted to fractures. Understanding methane diffusion and adsorption, and gas flow and equilibrium in the low-permeability matrix of shale is crucial for shale formation evaluation and for predicting gas production. Modeling of diffusion in low-permeability shale rocks requires use of the Dusty gas model (DGM) rather than Fick's law. The DGM is incorporated in the TOUGH2 module EOS7C-ECBM, a modified version of EOS7C that simulates multicomponent gas mixture transport in porous media. Also included in EOS7C-ECBM is the extended Langmuir model for adsorption and desorption of gases. In this study, a column shale model was constructed to simulate methane diffusion and adsorption through shale rocks. The process of binary CH 4 −N 2 diffusion and adsorption was analyzed. A sensitivity study was performed to investigate the effects of pressure, temperature and permeability on diffusion and adsorption in shale rocks. The results show that methane gas diffusion and adsorption in shale is a slow process of dynamic equilibrium, which can be illustrated by the slope of a curve in CH 4 mass variation. The amount of adsorption increases with the pressure increase at the low pressure, and the mass change by gas diffusion will decrease due to the decrease in the compressibility factor of the gas. With the elevated temperature, the gas molecules move faster and then the greater gas diffusion rates make the process duration shorter. The gas diffusion rate decreases with the permeability decrease, and there is a limit of gas diffusion if the permeability is less than 1.0 × 10 −15 m 2 . The results can provide insights for a better understanding of methane diffusion and adsorption in the shale rocks so as to optimize gas production performance of shale gas reservoirs.

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Section: Effect Of Pressurementioning

confidence: 99%

Section: Effect Of Pressurementioning

confidence: 99%

Section: Effect Of Temperaturementioning

confidence: 99%

Section: Effect Of Temperaturementioning

confidence: 99%

See 2 more Smart Citations

Methane Diffusion and Adsorption in Shale Rocks: A Numerical Study Using the Dusty Gas Model in TOUGH2/EOS7C-ECBM

et al. 2018

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“…Qin et al (2012) showed an apparatus for measuring the dynamic gas adsorption process by approximately retaining the pressure. A new Variable-volume Volumetric Method (VVM) has been designed by Wang et al (2016bWang et al ( , 2016c with the consideration of the dynamic gas adsorption/desorption process. With this technique, not only the amount of adsorbed gas stored in reservoir could be obtain, it also depicts the whole dynamic process of gas transport in unconventional rocks.…”

Section: Introductionmentioning

confidence: 99%

Review on gas flow and recovery in unconventional porous rocks

Lin

Wang

Yuan

et al. 2017

Adv. Geo-Energ. Res.

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This study summarizes gas flow process in unconventional porous rocks, including the transportation in tight or shale reservoirs and the spontaneous imbibition happened in them. Fluids flow is greatly affected by the pore structure together with the pore size distribution of porous media. The MRI and BET measurement show peaks in pore throat radius ranging from 2 to 20 nm, whereas the diameter for methane and helium are 0.38 and 0.26 nm, respectively. Yet for different types of reservoir, distinct mechanisms should be utilized based on the flow regimes. Besides, experimental measurement techniques for conventional reservoirs are no long accurate enough for most of the unconventional reservoirs. New attempts have been implemented to obtain more valuable data for accurate reservoir prediction. By reviewing large numbers of articles, a clear and comprehensive map on the gas flow and recovery in unconventional reservoirs is made. Factors influencing the gas flow and recovery are investigated in detail for mathematical simulation process. Reservoir conditions and the sweep efficiency play an important role during gas production process. Besides, adsorbed gas contributes a lot to the total gas recovery. The overall investigations suggest that many parameters that influence the gas flow in unconventional porous rocks should be taken into consideration during the evaluation. Among them, permeability, adsorbed gas dynamics, stimulated reservoir volume as well as the unstimulated reservoir volume, and imbibition effect are the most important ones. This study provides valuable data and reasonable exploitations for characterizing gas flow and recovery in unconventional porous rocks.

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Chemomechanical effects of oxidizer‐CO₂ systems upon hydraulically fractured unconventional source rock

Hull

Abousleiman

2021

Can J Chem Eng

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Carbon dioxide (CO2) as supercritical (scCO2) or foamed (CO2‐Foam) fluid has been tested many times as a fracturing fluid, though it has not yet proven viable. Many challenges have been identified with scCO2 as a fracturing fluid, including poor additive solubility, low viscosity, and limited accessibility. However, CO2 is known to adsorb to organic matter (OM) and displace methane (i.e., enhanced coal bed methane [ECBM] operations), or to mobilize oil as in tertiary enhanced oil recovery. In this study we augment the efficacy of the kerogen control fluid (KCF) for stimulating unconventional rock formations by alternating aqueous oxidizing fracturing fluid with CO2 injection or by combining oxidizers directly with CO2 as a new additive. To this end, KCF‐CO2 tests were designed to treat OM and extend the depth of permeability enhancement. We report the first attempt to combine oxidizer with CO2 in the presence of source shale rocks at elevated temperature and pressure. Scanning electron microscopy imaging of the treated shale sample surfaces demonstrate potential porosity and permeability enhancement, though some mineral and organic deposits are also observed, which may prove to be detrimental. Meanwhile, alternating water‐based KCF with CO2 provides a potential improvement to the KCF as predicted by early lab results on OM. The KCF‐CO2 concept has no equivalent to date in unconventional hydraulic fracturing operations. This technology will contribute to reducing the footprint of anthropogenic CO2 and enhancing its permanent sequestration in unconventional stimulated reservoirs, compliant with our global clean energy initiative of carbon capture, utilization, and storage.

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Measurement of dynamic adsorption–diffusion process of methane in shale

Cited by 96 publications

References 36 publications

Methane Diffusion and Adsorption in Shale Rocks: A Numerical Study Using the Dusty Gas Model in TOUGH2/EOS7C-ECBM

Methane Diffusion and Adsorption in Shale Rocks: A Numerical Study Using the Dusty Gas Model in TOUGH2/EOS7C-ECBM

Review on gas flow and recovery in unconventional porous rocks

Chemomechanical effects of oxidizer‐CO₂ systems upon hydraulically fractured unconventional source rock

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Measurement of dynamic adsorption–diffusion process of methane in shale

Cited by 96 publications

References 36 publications

Methane Diffusion and Adsorption in Shale Rocks: A Numerical Study Using the Dusty Gas Model in TOUGH2/EOS7C-ECBM

Methane Diffusion and Adsorption in Shale Rocks: A Numerical Study Using the Dusty Gas Model in TOUGH2/EOS7C-ECBM

Review on gas flow and recovery in unconventional porous rocks

Chemomechanical effects of oxidizer‐CO2 systems upon hydraulically fractured unconventional source rock

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Product

Resources

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Chemomechanical effects of oxidizer‐CO₂ systems upon hydraulically fractured unconventional source rock