An integrated multi-scale model for CO2 transport and storage in shale reservoirs

Wang, Yanwei; Dai, Zhenxue; Chen, Li; Shen, Xudong; Chen, Fangxuan; Soltanian, Mohamad Reza

doi:10.1016/j.apenergy.2022.120444

Cited by 33 publications

(5 citation statements)

References 73 publications

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“…which will sharply increase the flow resistance in the near-well area, resulting in the difficulty of fluid flowing to the bottom hole from the distal coal seam (Wang et al, 2023). Therefore, the pressure drop is difficult to be transmitted to the distal end, resulting in the slow expansion of the desorption area, which is consistent with the production characteristics of Q4 well.…”

Section: Figure 15mentioning

confidence: 78%

Production characteristics and influencing factors of coalbed methane wells: a case study of the high-ranking coal seam in the southeastern Qinshui Basin, China

Chen,

Gao,

Wang

2024

Front. Earth Sci.

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This study focuses on coalbed methane (CBM) wells in high-ranking coal seam as the research subject. Considering the influence of effective stress and matrix shrinkage, a comprehensive permeability calculation model for CBM reservoirs is established. Based on this model, the variations in pressure and permeability during well production are quantified. By integrating static geological parameters, a finely classified classification of CBM wells is achieved using self-organizing map (SOM) neural network. Subsequently, an analysis of production dynamic characteristics and productivity differences among different types of CBM wells is performed, followed by providing drainage optimization suggestions. The results of SOM analysis show that 7,000 m3/d and 1,500 m3/d can be used as the production boundaries for the wells with different productivity in Block P. The daily gas production of exceptional well exceeds 7,000 m3/d, and the permeability remains relatively stable throughout the drainage process of this well. The daily gas production of the potential well ranges from 1,500 to 7,000 m3/d, and the permeability exhibits a significant decrease during the drainage process. The daily gas production of Inefficient well is consistently below 1,500 m3/d with moderate permeability variation. In addition to well location and structural geology, production variability is also influenced by the matching of reservoir conditions and drainage systems. This is primarily manifested in discontinuous drainage systems and rapid decline in bottom hole pressure (BHP) during early production. The analysis of drainage parameters indicates that in order to achieve optimal production from CBM wells, the BHP should exhibit an initial rapid decline followed by a slowly decrease during the early production period, with an average pressure drop ranging from 0.005 to 0.02 MPa/d. The research findings can offer technical guidance for the future advancement of CBM in the P Block.

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Section: Figure 15mentioning

confidence: 78%

Production characteristics and influencing factors of coalbed methane wells: a case study of the high-ranking coal seam in the southeastern Qinshui Basin, China

Chen,

Gao,

Wang

2024

Front. Earth Sci.

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“…CO 2 -ECBM technology can not only greatly improve the recovery of CBM but also effectively replace CH 4 with CO 2 in the coal seam so as to achieve the effect of geological sequestration of CO 2 . This is an important direction for CO 2 capture, utilization, and storage (CCUS) technology and has essential practical significance for promoting the realization of "carbon peak and carbon neutrality" [10,11].…”

Section: Introductionmentioning

confidence: 99%

Adsorption and Diffusion Characteristics of CO2 and CH4 in Anthracite Pores: Molecular Dynamics Simulation

Gao,

Wang,

Chen

2024

Processes

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CO2-enhanced coalbed methane recovery (CO2-ECBM) has been demonstrated as an effective enhanced oil recovery (EOR) technique that enhances the production of coalbed methane (CBM) while achieving the goal of CO2 sequestration. In this paper, the grand canonical Monte Carlo simulation is used to investigate the dynamic mechanism of CO2-ECBM in anthracite pores. First, an anthracite pore containing both organic and inorganic matter was constructed, and the adsorption and diffusion characteristics of CO2 and CH4 in the coal pores under different temperature and pressure conditions were studied by molecular dynamics (MD) simulations. The results indicate that the interaction energy of coal molecules with CO2 and CH4 is positively associated with pressure but negatively associated with temperature. At 307.15 K and 101.35 kPa, the interaction energies of coal adsorption of single-component CO2 and CH4 are −1273.92 kJ·mol−1 and −761.53 kJ·mol−1, respectively. The interaction energy between anthracite molecules and CO2 is significantly higher compared to CH4, indicating that coal has a greater adsorption capacity for CO2 than for CH4. Furthermore, the distribution characteristics of gas in the pores before and after injection indicate that CO2 mainly adsorbs and displaces CH4 by occupying adsorption sites. Under identical conditions, the diffusion coefficient of CH4 surpasses that of CO2. Additionally, the growth rate of the CH4 diffusion coefficient as the temperature increases is higher than that of CO2, which indicates that CO2-ECBM is applicable to high-temperature coal seams. The presence of oxygen functional groups in anthracite molecules greatly influences the distribution of gas molecules within the pores of coal. The hydroxyl group significantly influences the adsorption of both CH4 and CO2, while the ether group has a propensity to impact CH4 adsorption, and the carbonyl group is inclined to influence CO2 adsorption. The research findings are expected to provide technical support for the effective promotion of CO2-ECBM technology.

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“…The storage space and fluid transport mechanisms of shale differ significantly from those in conventional gas reservoirs [1][2][3]. Nanoscale organic pores, nano-micro inorganic pores, and microfractures exist in shale; additionally, millimeterscale hydraulic fractures are formed after hydraulic fracturing [4][5][6][7]. Based on scanning electron microscopy (SEM) images, Loucks et al [8] observed the inorganic matter (IOM) pore diameters ranged from 35 nm to several microns, whereas the organic matter (OM) pore diameters ranged from 10 to 300 nm.…”

Section: Introductionmentioning

confidence: 99%

Macroscale Gas–Water Two-Phase Transport Simulation in Shales considering Nanomicroscale Effects

Wang,

Liu,

Yao

et al. 2024

International Journal of Energy Research

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As an effective approach to evaluate shale gas production, macroscale numerical simulations have been conducted; however, multiscale storage space and complex gas–water two-phase transport mechanisms are not systematically considered. To deal with this, a rigorous cross-scale gas–water two-phase transport simulation method that considers the pore, core, and field scale is proposed herein. First, to investigate the fluid storage state in different pore types during the gas–water two-phase transport process, a shale pore network gas–water transport simulation is conducted. Subsequently, a core-scale model that considers the distribution of organic matter is constructed, and the gas–water two-phase transport behaviors are upscaled from the pore to the core by incorporating nanomicroscale effects. Next, a shale gas–water two-phase macroscale numerical simulation is implemented based on the core-scale simulation results. Multiple interacting continua are used to describe the shale matrix and microfractures, whereas the embedded discrete fracture method is employed to represent hydraulic fractures. Finally, the manner by which nanomicroscale effects, stress sensitivity, and SRV area affect the production of shale gas reservoirs is discussed comprehensively. This study provides a practical method to estimate shale gas production by rigorously considering gas–water nanomicroscale effects to reduce uncertainties during productivity evaluation.

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An integrated multi-scale model for CO2 transport and storage in shale reservoirs

Cited by 33 publications

References 73 publications

Production characteristics and influencing factors of coalbed methane wells: a case study of the high-ranking coal seam in the southeastern Qinshui Basin, China

Production characteristics and influencing factors of coalbed methane wells: a case study of the high-ranking coal seam in the southeastern Qinshui Basin, China

Adsorption and Diffusion Characteristics of CO2 and CH4 in Anthracite Pores: Molecular Dynamics Simulation

Macroscale Gas–Water Two-Phase Transport Simulation in Shales considering Nanomicroscale Effects

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