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Non-linear gas transport inside an ultra-tight Longmaxi shale core under thermal stimulation conditions

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  • Chen, Wei
  • Yang, Yunfeng
  • Wang, Tengxi

Abstract

Gas adsorption/desorption and non-linear mass transport in ultra-tight shale were very sensitive to temperature and they become even more intricate as temperature changed. In this study, a self-similarity mathematical model was developed to simulate the gas decline process under thermal stimulation conditions. This model not only incorporated slip and free molecular flow but also gas adsorption/desorption. Besides, a canister test was conducted to study the effect of heating temperature on gas production rates of a fresh shale core. The experiment results showed that gas production rate was increased by raising the heating temperature. Free gas is the main source for the gas flow under 55 °C, while adsorbed gas is the main source under 110 °C. Lastly, the declined trend of simulated gas production rate followed a power law of t−0.509+t−0.736 at 55 °C and t−0.169+t−1.828 under at 110 °C, which matched the experimental data well. From the scaling data, it was suggested that free molecular diffusion was the main gas transport form inside the shale both under 55 °C–110 °C. Our experimental results and theoretic model showed that higher heating temperature could promote the gas production rate significantly, and the model can well predict the non-linear gas transport process.

Suggested Citation

  • Chen, Wei & Yang, Yunfeng & Wang, Tengxi, 2019. "Non-linear gas transport inside an ultra-tight Longmaxi shale core under thermal stimulation conditions," Energy, Elsevier, vol. 186(C).
    • Handle: RePEc:eee:energy:v:186:y:2019:i:c:s036054421931518x
    DOI: 10.1016/j.energy.2019.07.176
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    Citations

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    Cited by:

    1. Shan, Baochao & Wang, Runxi & Guo, Zhaoli & Wang, Peng, 2021. "Contribution quantification of nanoscale gas transport in shale based on strongly inhomogeneous kinetic model," Energy, Elsevier, vol. 228(C).
    2. Yang, Xu & Zhou, Wenning & Liu, Xunliang & Yan, Yuying, 2020. "A multiscale approach for simulation of shale gas transport in organic nanopores," Energy, Elsevier, vol. 210(C).
    3. Liu, Jia & Xue, Yi & Fu, Yong & Yao, Kai & Liu, Jianqiang, 2023. "Numerical investigation on microwave-thermal recovery of shale gas based on a fully coupled electromagnetic, heat transfer, and multiphase flow model," Energy, Elsevier, vol. 263(PE).
    4. Xu, WenLong & Yu, Hao & Micheal, Marembo & Huang, HanWei & Liu, He & Wu, HengAn, 2023. "An integrated model for fracture propagation and production performance of thermal enhanced shale gas recovery," Energy, Elsevier, vol. 263(PA).
    5. Fan, Zhanglei & Fan, Gangwei & Zhang, Dongsheng & Zhang, Lei & Zhang, Shuai & Liang, Shuaishuai & Yu, Wei, 2021. "Optimal injection timing and gas mixture proportion for enhancing coalbed methane recovery," Energy, Elsevier, vol. 222(C).
    6. Cao, Gaohui & Jiang, Wenbin & Lin, Mian & Ji, Lili & Xu, Zhipeng & Zheng, Siping & Hao, Fang, 2021. "Mortar dynamic coupled model for calculating interface gas exchange between organic and inorganic matters of shale," Energy, Elsevier, vol. 236(C).

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