Comparative modeling and optimization of CO2-ECBM processes using DP and MINC models
DOI:
https://doi.org/10.62813/see.2025.01.04Keywords:
Coalbed methane, CO2-ECBM, MINC model, Multistage fractured horizontal well, Orthogonal experiment designAbstract
CO2-enhanced coalbed methane (CO2-ECBM) recovery technology is vital for meeting rising energy demands and combatting climate change. It boosts CBM recovery and enables concurrent CO2 storage, offering a sustainable approach for energy supply and environmental protection. In this study, the dual-porosity (DP) model and the multiple interacting continua (MINC) model were compared to unravel the effect of distinct transient flow behaviors on gas recovery from a fractured horizontal well in coal seams with multiscale natural and artificial fractures. Using an L25 (56) orthogonal array, the influence order of parameters on methane recovery was determined through range analysis, and an optimal parameter set was identified. Results indicate that the MINC model, due to the inclusion of transient flow between fracture and matrix, yields higher peak gas production rate and higher CH4 recovery for CO2-ECBM from coal seams with multiscale fractures. The orthogonal testing results show that the optimized parameter set achieves a recovery factor of 40.56%, surpassing the 37.7% of the benchmark case for the CBM reservoir sector model, attributed to reduced bottomhole pressure (BHP) and skin factor. These findings with economical insights provide useful guidance for CO2-ECBM development and concurrent geological storage.
References
Amoih, F., Finqueneisel, G., Zimny, T., et al., 2024. Comparative study on different coals from the Lorraine Basin (France) by sorption isotherms, thermogravimetric analysis and breakthrough curves for CO2-ECBM recovery. International Journal of Coal Science & Technology, 11(1), 46.
Arri, L.E., Yee, D., Morgan, W.D., et al., 1992. Modeling coalbed methane production with binary gas sorption. In SPE Rocky Mountain Regional Meeting. SPE-24363-MS.
Asif, M., Wang, L., Naveen, P., et al., 2024. Influence of competitive adsorption, diffusion, and dispersion of CH4 and CO2 gases during the CO2-ECBM process. Fuel, 358, 130065.
Bai, G., Su, J., Li X., et al., 2022. Step-by-step CO2 injection pressure for enhanced coal seam gas recovery: a laboratory study. Energy, 260, 125197.
Barenblatt, G.I., Zheltov, Y.P., Kochina, I.N., 1960. Basic concepts in the theory of seepage of homogeneous liquids in fissured rocks. Journal of Applied Mathematics and Mechanics, 24(5), 852-864.
Bekeshov, D., Ashimov, S., Wang, Y., et al., 2023. Understanding gas-enhanced methane recovery in graphene nanoslits via molecular simulations. Capillarity, 6(1), 1-12.
Boruah, A., 2025. CO₂ Geosequestration: Capturing Carbon for a Sustainable Future: Carbon Dioxide Storage in Geological Media. Springer Nature, 73-81.
Fang, H., Li, A., Sang, S., et al., 2023. Numerical analysis of permeability rebound and recovery evolution with THM multi-physical field models during CBM extraction in crushed soft coal with low permeability and its indicative significance to CO2 geological sequestration. Energy, 262, 125395.
Gao, D. and Bi, Y., 2022. Technical advances in well type and drilling & completion for high-efficient development of coalbed methane in China. Natural Gas Industry B, 9(6), 561-577.
Geng, X. and Yan, J., 2021. Experimental study on influence of gas injection conditions on CO2 replacement and displacement of CH4. Journal of Safety and Technology, 17(11), 79-84. (In Chinese)
Kazemi, H., Merrill, L.S., Porterfield, K.L., et al., 1976. Numerical simulation of water-oil flow in naturally fractured reservoirs. SPE Journal, 261, 317-326.
Li, H., Lau, H.C., Huang, S., 2018. China’s coalbed methane development: a review of the challenges and opportunities in subsurface and surface engineering. Journal of Petroleum Science and Engineering, 166, 621-635.
Li, H., Zhou, G., Chen, S. et al., 2025. In situ gas content and extraction potential of ultra-deep coalbed methane in the Sichuan Basin, China. Nature Resources Research, 34(1), 563-579.
Li, Z., Yu, H., Bai, Y., et al., 2023. Numerical study on the influence of temperature on CO2-ECBM. Fuel, 348, 128613.
Liu, X., 2023. Study on numerical simulation of CO2-ECBM for Shizhuangnan Demonstration Project in Qinshui Basin. Ph.D. Dissertation, China University of Mining and Technology.
Lu, S., Shi, J., Jiao, L., et al., 2024. A review of coal permeability models including the internal swelling coefficient of matrix. International Journal of Coal Science & Technology, 11(1), 50.
Meng, S., Liu, C., Ji, Y., 2013. Geological conditions of coalbed methane and shale gas exploitation and their comparison analysis. Journal of China Coal Society, 38(5), 728-736. (In Chinese)
Nguyen, T., N., 2016. Simulating unconventional gas flow in stimulated fractured shale reservoirs. MSc Thesis, Colorado School of Mines.
Okolo, G. N., Everson, R. C., Neomagus, H. W. J. P., et al., 2019. The carbon dioxide, methane and nitrogen high-pressure sorption properties of South African bituminous coals. International Journal of Coal Geology, 209, 40-53.
Palmer, I. and Mansoori, J., 1998. How permeability depends on stress and pore pressure in coalbeds: a new model. SPE Reservoir Evaluation & Engineering, 1(06), 539-544.
Peng, D.Y. and Robinson, D.B., 1976. A new two-constant equation of state. Industrial & Engineering Chemistry Fundamentals, 15(1), 59-64.
Pruess, K. and Narasimhan, T.N., 1985. A practical method for modeling fluid and heat flow in fractured porous media. SPE Journal, 25(01), 14-26.
Serikov, G., Wang, L., Asif, M., et al., 2022. Simulation evaluation of CO2-ECBM potential in Karaganda Coal Basin in Kazakhstan. In SPE Europec featured at EAGE Conference and Exhibition. SPE-209698-MS.
Sobecki, N., Wang, S., Ding, D. Y., et al., 2020. A multi-scale modeling of confined fluid: from nanopore to unconventional reservoir simulation. Journal of Petroleum Science and Engineering, 193, 107364.
Standardization Administration of China., 2018. Natural gas, GB 17820-2018. China Standard Press.
Tao, S., Chen, S., Pan, Z., 2019. Current status, challenges, and policy suggestions for coalbed methane industry development in China: A review. Energy Science & Engineering, 7(4), 1059-1074.
Wang, L., Miskimins, J.L., Wu, Y.S., et al., 2016. Waterless fracturing technologies for unconventional reservoirs-opportunities for liquid nitrogen. Journal of Natural Gas Science and Engineering, 35, 160-174.
Warren, J.E. and Root, P.J., 1963. The behavior of naturally fractured reservoirs. Society of Petroleum Engineers Journal, 3(03), 245-255.
Wei, M., Liu, J., Elsworth, D., et al., 2021. Impact of equilibration time lag between matrix and fractures on the evolution of coal permeability. Fuel, 290(1), 120029.
Wei, M., Liu, J., Elsworth, D., et al., 2019. Influence of gas adsorption induced non-uniform deformation on the evolution of coal permeability. International Journal of Rock Mechanics and Mining Sciences, 114, 71-78.
Wu, Y. and Pruess, K., 1988. A multiple-porosity method for simulation of naturally fractured petroleum reservoirs. SPE Reservoir Engineering, 3(01), 327-336.
Xu, F., Hou, W., Xiong, X., et al., 2023. The status and development strategy of coalbed methane industry in China. Petroleum Exploration and Development, 50(4), 765-783.
Yang, F., 2016. Numerical simulation of coalbed methane in Shizhuang South Block, southern Qinshui Basin. Ph.D. Dissertation.
Zhang, S., Sang, S., Wu, J., 2022. Progress and application of key technologies for CO2 enhancing coalbed methane. Journal of China Coal Society, 47(11), 3952-3964. (In Chinese)
Zhao, Y., Zhao, Y., Liu, J., et al., 2025. Why does coal permeability time dependency matter? Fuel, 381, 133373.
Additional Files
Published
How to Cite
Issue
Section
License
Copyright (c) 2025 Zuying Wang, Yuyuan Lou, Bo Gou, Rui Wang, Umer Shafiq, Muhammad Haris, Haiyan Zhu, Lei Wang
This work is licensed under a Creative Commons Attribution-NonCommercial-NoDerivatives 4.0 International License.