The Stefan moving boundary models for the heat-dissociation hydrate with a density difference

Li, Mingchuan; Fan, Shuanshi; Su, Yuliang; Li, Yan; Lu, Mingjing; Sheng, Guanglong; Yan, Ke‐Le

doi:10.1016/j.energy.2018.07.101

Cited by 6 publications

(1 citation statement)

References 16 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…An analytical solution was derived, and results were used to evaluate gas production. Later, the authors in [3][4][5][6][7][8] generalized the analytical model to radial symmetric decomposition model, well structure, etc. For hydrate decomposition model solved numerically, we refer to references [9,10] and their related references.…”

Section: Introductionmentioning

confidence: 99%

Hydrate Dissociation Model with Time Fractional Derivative

et al. 2022

View full text Add to dashboard Cite

In this paper, we shall investigate fractional partial differential equations with fractional moving boundary condition to study the dissociation of natural gas hydrate under heat injection. The moving boundary separates the hydrate reservoir into the dissociated zone and the hydrate one. By using the self-similar transformation and Wright function, we obtain the explicit solutions for two zones. We present simulations with steam and hot water injection and show the dissociation temperature in graphical mode from injection temperature to reservoir temperature with respect to the time, distance, and fractional order. Our analysis of fractional model turns out to be a successful generalization of the classical one; i.e., it can well describe the dissociation of natural gas hydrate and is theoretically consistent with the existing integer hydrate dissociation model. When the factional order tends to 1, the “limit solution” becomes the classical one.

show abstract

Section: Introductionmentioning

confidence: 99%

Hydrate Dissociation Model with Time Fractional Derivative

et al. 2022

View full text Add to dashboard Cite

show abstract

Interface coupling model of Stefan phase change during thermal dissociation of natural gas hydrate

Fan

2021

International Journal of Heat and Mass Transfer

View full text Add to dashboard Cite

Integrated flow model for evaluating maximum fracture spacing in horizontal wells

Liu

Duan

et al. 2023

Physics of Fluids

View full text Add to dashboard Cite

Multi-stage fractured horizontal wells are extensively used in unconventional reservoir; hence, optimizing the spacing between these hydraulic fractures is essential. Fracture spacing is an important factor that influences the production efficiency and costs. In this study, maximum fracture spacing in low-permeability liquid reservoirs is studied by building an integrated flow model incorporating key petrophysical characteristics. First, a kinematic equation for non-Darcy seepage flow is constructed using the fractal theory to consider the non-homogeneous characteristics of the stimulated rock volume area (StRV) and its stress sensitivity (SS). Then, the kinematic equation is used to build an integrated mathematical model of one-dimensional steady-state flow within the StRV to analytically determine the pressure distribution in StRV. The resultant pressure distribution is utilized to propose an optimal value for the maximum fracture spacing. Finally, the effects of fractal index, initial matrix permeability, depletion, and stress sensitivity coefficient on the limit disturbed distance and pressure distribution are studied. This study not only enriches the fundamental theory of nonlinear seepage flow mechanics but also provides some technical guidance for choosing appropriate fracture spacing in horizontal wells.

show abstract

The Stefan moving boundary models for the heat-dissociation hydrate with a density difference

Cited by 6 publications

References 16 publications

Hydrate Dissociation Model with Time Fractional Derivative

Hydrate Dissociation Model with Time Fractional Derivative

Interface coupling model of Stefan phase change during thermal dissociation of natural gas hydrate

Integrated flow model for evaluating maximum fracture spacing in horizontal wells

Contact Info

Product

Resources

About