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Modeling of Shale Gas Transport in Multi-Scale Complex Fracture Networks Considering Fracture Hits

  • S.I.: Geological Systems with Fractured Porous Media
  • Published:
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Abstract

Shale gas reservoir is a complex multi-scale system containing micro-nanopores and micro-fractures. Understanding shale gas transport mechanism in fractured porous media is important to predict shale gas production performance accurately. This paper established a shale gas production prediction model, considering gas rarefaction effects, adsorption, diffusion, and stress sensitivity. The variation in production and drainage patterns with production time by multi-stage and multi-cluster fracturing considering fracture hit was studied by using this model. In addition, the influences of connecting hydraulic fractures, natural fracture conductivity, and stress sensitivity on shale gas production are discussed. When the spacing between the connecting fractures exceeds 4 stages (176 m), the production of the child well and parent well tends to be stable as the spacing between connecting hydraulic fractures increases. The child well production decreases, and the parent well production increases by considering fracture hits. The cumulative production of both parent and child wells increases with the increase in natural fracture conductivity. The results show that the production of parent and child wells considering stress sensitivity is, respectively, 14.31% and 18.73% lower than that without considering stress sensitivity. The key findings of this study can be expected to provide theoretical supports for the shale gas transport mechanisms in fractured porous media.

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Abbreviations

D e :

Effective diameter of nanopores for gas transport, m

k bulk :

Bulk diffusion apparent permeability, m2

k f :

Permeability of the fractures, m2

k k :

Knudsen diffusion apparent permeability, m2

k m :

Permeability of shale matrix, m2

k m0 :

Permeability at atmospheric pressure

k s :

Surface diffusion apparent permeability, m2

k vs :

Slip flow apparent permeability, m2

M :

Gas molar mass, kg/mol

n :

Number of moles of gas, mol

n a :

Adsorption amount, mol/kg

n 0 :

Maximum adsorption capacity, mol/kg

p :

Pressure, Pa

p L :

Langmuir pressure, Pa

p 0 :

Gas pressure at a certain time during depressurization, Pa

R :

Universal gas constant, Pa·m3/(mol·K)

T :

Temperature, K

T c :

Critical temperature of gas, K

u :

Gas velocity in fractures, m/s

u m :

Velocity, m/s

V :

Volume, m3

w f :

Fracture width, m

Z :

Gas compressibility factor

μ :

Gas viscosity, Pa·s

ξ b :

Coefficient factor of adsorption gas for bulk gas transport

ξ s :

Coefficient factor of adsorption gas for surface diffusion

ρ g :

Gas density, kg/m3

ρ r :

Shale density, kg/m3

φ f :

Fracture porosity

φ m :

Shale matrix porosity

φ m0 :

Porosity at atmospheric pressure

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Acknowledgements

The authors would like to thank the Research on Key Technologies for CUCBM's Production of 6 Billion Cubic Meters (CNOOC-KJ 135 ZDXM 40) for financial support.

Funding

This work has been funded by the Research on Key Technologies for CUCBM's Production of 6 Billion Cubic Meters (CNOOC-KJ 135 ZDXM 40).

Conflict of interest

The authors have not disclosed any competing interests.

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  1. China United Coalbed Methane Corporation Ltd, Beijing, China

    Bin Li

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  1. Bin Li
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Li, B. Modeling of Shale Gas Transport in Multi-Scale Complex Fracture Networks Considering Fracture Hits. Transp Porous Med 149, 71–86 (2023). https://doi.org/10.1007/s11242-022-01835-y

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