An Analytic Model for Shale Gas Permeability
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What you will learn
- Shale apparent permeability
- R13 AP model
- Molecular adsorption
Recent laboratory studies have revealed previously unknown behaviors in shale gas which unlock secrets of permeability and sweet spots in shale gas reservoirs. The presentation presents the findings and also goes into detail about how the new information can be applied in order to potentially improve recovery in reservoirs.
Based on the kinetic theory of gases and using the regularized 13-moment method, analytical R13 AP model is introduced for predicting gas apparent permeability of nanoporous shale samples. These samples are characterized by ultratight pores and may introduce significant rarefaction effects, especially under the laboratory conditions, which cannot be accounted for in the classical hydrodynamic equations.
Due to the significance of the rarefaction effects, measured values of the gas apparent permeability depend on the
operating parameters, such as pressure and temperature, and gas type in addition to pore size. The R13 AP model incorporates these parameters and can predict the apparent permeability for Knudsen numbers up to unity.
- Different scales in shale gas recovery
- Velocity profiles for different knudsen numbers & permeability of the channel
- Model verification
- Permeability vs. gas molecular weight
- Permeability measurement techniques
- Double slippage correction
- Steady state permeability measurement
Specification: An Analytic Model for Shale Gas Permeability
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