Measurement of the surface diffusion coefficient for adsorbed gas in the fine mesopores and micropores of shale organic matter

Yang, Bin; Kang, Yili; You, Lijun; Li, Xiangchen; Chen, Qiang

doi:10.1016/j.fuel.2016.05.069

Cited by 86 publications

(36 citation statements)

References 70 publications

(150 reference statements)

Supporting

Mentioning

Contrasting

Order By: Relevance

“…This finding (Knudsen diffusion being dominant in micropores) was inconsistent with the conclusion in other studies, indicating that Knudsen diffusion played an important role in meso-macropores only [13,18,85]. Many researchers concluded that surface diffusion (particle-solid surface collision) made the most contributions (>90%) in adsorbed-gas transport in micropores [13,81,[85][86][87]. Unlike the slippage effect or Knudsen effect, which are driven by small pore size, surface diffusion was driven by density gradient of the adsorbed-gas [87].…”

Section: Physio-chemical Properties Measurementsmentioning

confidence: 77%

“…Unlike the slippage effect or Knudsen effect, which are driven by small pore size, surface diffusion was driven by density gradient of the adsorbed-gas [87]. A positive correlation was found between surface diffusion and reservoir pressure or temperature [81,85]. In addition, the presence of water could reduce gas diffusivities in both macro-and micropores and affect gas flow behavior in a shale reservoir [76].…”

Section: Physio-chemical Properties Measurementsmentioning

confidence: 94%

“…Recently, many studies focused on the change of physio-chemical properties of shale due to carbon dioxide (or other gases) injection. The adsorption capacities of different gases [74][75][76][77][78], adsorption-induced swelling strain and swelling rate [77,79,80], gas diffusion in shale [76,81], and physical and chemical structure change [82] have been investigated in different studies.…”

Section: Physio-chemical Properties Measurementsmentioning

confidence: 99%

“…Viscous flow, molecular diffusion, Knudsen diffusion, and surface diffusion described the gas transport behaviors in porous media and were generally evaluated based on different pore sizes, pressure, and production stages [74,76,81,84,85]. A schematic diagram of different flow types and particle motion within a given flow regime is shown in Figure 6 [84].…”

Section: Physio-chemical Properties Measurementsmentioning

confidence: 99%

See 3 more Smart Citations

A Review of Gas Injection in Shale Reservoirs: Enhanced Oil/Gas Recovery Approaches and Greenhouse Gas Control

Nojabaei

2019

Energies

113

View full text Add to dashboard Cite

Shale oil and gas resources contribute significantly to the energy production in the U.S. Greenhouse gas emissions come from combustion of fossil fuels from potential sources of power plants, oil refineries, and flaring or venting of produced gas (primarily methane) in oilfields. Economic utilization of greenhouse gases in shale reservoirs not only increases oil or gas recovery, but also contributes to CO2 sequestration. In this paper, the feasibility and efficiency of gas injection approaches, including huff-n-puff injection and gas flooding in shale oil/gas/condensate reservoirs are discussed based on the results of in-situ pilots, and experimental and simulation studies. In each section, one type of shale reservoir is discussed, with the following aspects covered: (1) Experimental and simulation results for different gas injection approaches; (2) mechanisms of different gas injection approaches; and (3) field pilots for gas injection enhanced oil recovery (EOR) and enhanced gas recovery (EGR). Based on the experimental and simulation studies, as well as some successful field trials, gas injection is deemed as a potential approach for EOR and EGR in shale reservoirs. The enhanced recovery factor varies for different experiments with different rock/fluid properties or models incorporating different effects and shale complexities. Based on the simulation studies and successful field pilots, CO2 could be successfully captured in shale gas reservoirs through gas injection and huff-n-puff regimes. The status of flaring gas emissions in oilfields and the outlook of economic utilization of greenhouse gases for enhanced oil or gas recovery and CO2 storage were given in the last section. The storage capacity varies in different simulation studies and is associated with well design, gas injection scheme and operation parameters, gas adsorption, molecular diffusion, and the modelling approaches.

show abstract

Section: Physio-chemical Properties Measurementsmentioning

confidence: 77%

Section: Physio-chemical Properties Measurementsmentioning

confidence: 94%

Section: Physio-chemical Properties Measurementsmentioning

confidence: 99%

Section: Physio-chemical Properties Measurementsmentioning

confidence: 99%

See 2 more Smart Citations

A Review of Gas Injection in Shale Reservoirs: Enhanced Oil/Gas Recovery Approaches and Greenhouse Gas Control

Nojabaei

2019

Energies

113

View full text Add to dashboard Cite

show abstract

“…First, Klinkenberg proposed a slippage factor to describe this enhancement of measured permeability . Subsequently, a variety of researchers have modified Klinkenberg's slip flow model by using more accurate boundary conditions or by adding other nanoscale flow mechanisms, e.g., Knudsen diffusion and surface diffusion …”

Section: Introductionmentioning

confidence: 99%

Effect of water saturation on gas slippage in circular and angular pores

Chen

et al. 2018

AIChE Journal

View full text Add to dashboard Cite

A unified model for gas slip flow through circular and angular pores in both single phase flow and two-phase flow conditions is developed, and the effect of water saturation on gas slippage factors in different pore shapes are revealed. For circular pores, the water saturation retains as thin film binding on pore surfaces without changing the shape of the cross section, and the hydraulic diameters continuously reduce as water saturation increases, directly leading to an increase in the slippage factor. However, for angular pores, the water saturation retains as both films at boundaries and condensations at corners, and the film-water and corner-water gradually change their cross-section shape (from sharp corners to round corners), which further affects the gas slip behavior. Due to the presence of round corners, the ratio of the cross-sectional area and perimeter, which can also be regarded as the reciprocal of a specific surface area, can even increase at a low water saturation condition. Thus the collisions between gas molecules and pore boundaries weaken, resulting in a slight reduction in the gas slippage factor. This interesting finding in the angular pore case directly explains the contradiction of the published experimental results with the general knowledge (i.e., the gas slip factor always increases as water saturation increases). Thus, the validity of the common assumption regarding actual porous media as capillaries with a circular cross-section must be considered more carefully.

show abstract

Predicting the Gas Storage Capacity in Shale Formations Using the Extreme Gradient Boosting Decision Trees Method

Wang,

Li,

Huo

et al. 2024

Energy Tech

View full text Add to dashboard Cite

Accurate shale gas reserves estimation is essential for development. Existing machine learning (ML) models for predicting gas isothermal adsorption are limited by small datasets and lack verified generalization. We constructed an “original dataset” containing 2112 data points from 11 measurements on samples from 8 formations in 3 countries to develop ML‐based prediction models. Similar to previous ML models, total organic matter, pressure, and temperature are characterized as the three most significant features using the mean impurity method. In contrast to previous ML models, the study reveals that these three features are inadequate to be used to make reasonable predictions for the datasets from the measurements different from those used to train the models. Instead, the extreme gradient boosting decision trees (XGBoost) model with two more features (specific surface area and moisture) exhibits good robustness, generalization, and precision in the prediction of gas isothermal adsorption. Overall, An XGBoost model with optimal input features is developed in this work, which exhibits both good performance in gas adsorption prediction and good potential for the estimation of gas storage in shale gas development.

show abstract

Measurement of the surface diffusion coefficient for adsorbed gas in the fine mesopores and micropores of shale organic matter

Cited by 86 publications

References 70 publications

A Review of Gas Injection in Shale Reservoirs: Enhanced Oil/Gas Recovery Approaches and Greenhouse Gas Control

A Review of Gas Injection in Shale Reservoirs: Enhanced Oil/Gas Recovery Approaches and Greenhouse Gas Control

Effect of water saturation on gas slippage in circular and angular pores

Predicting the Gas Storage Capacity in Shale Formations Using the Extreme Gradient Boosting Decision Trees Method

Contact Info

Product

Resources

About