Simulation of Fracturing Induced Formation Damage and Gas Production from Fractured Wells in Tight Gas Reservoirs

Ding, Yu; Langouët, Hoel; Jeannin, Laurent

doi:10.2118/153255-ms

Cited by 3 publications

(1 citation statement)

References 20 publications

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“…[135] A coarse-grid model incorporating numerical dynamic skin factor is presented for shale reservoirs with hydraulic fractures. [136] To handle practical well performance in a long term as well as common transient behavior, the coarse-grid model is improved to better describe the fractures and wells. [137] For different connections in organic matters with different pore sizes, free gas flow mechanism varies.…”

Section: Gas Flow Simulation At Reservoir Scale 31 Flow Modelsmentioning

confidence: 99%

Flow Mechanism and Simulation Approaches for Shale Gas Reservoirs: A Review

2018

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The past two decades have borne remarkable progress in our understanding of flow mechanisms and numerical simulation approaches of shale gas reservoir, with much larger the number of publications in recent five years compared to that before year 2012. In this paper, a review is constructed with three parts: flow mechanism, reservoir models and numerical approaches. In mechanism, it is found that gas adsorption process can be concluded into different isotherm models for various reservoir basins. Multi-component adsorption mechanism are taken into account in recent years. Flow mechanism and equations vary with different Knudsen number, which could be figured out in two ways: Molecular Dynamics (MD) and Lattice Boltzmann Method (LBM). MD has been successfully applied in the study of adsorption, diffusion, displacement and other mechanisms. LBM has been introduced in the study of slippage, Knudsen diffusion and apparent permeability correction. The apparent permeability corrections are introduced to improve classic Darcy's model in matrix with low velocities and fractures with high velocities. At reservoir scale simulation, gas flow models are presented with multiple-porosity classified into organic matrix with nanopores, organic matrix with micropores, inorganic matrix and natural fractures. A popular trend is to incorporate geomechanism with flow model in order to better understand the shale gas production. Finally, to solve the new models based on enhanced flow mechanisms, improved macroscopic numerical approaches, including the finite difference method (FDM) and finite element method (FEM) are common used in this area. Other approaches, like finite volume method (FVM) and fast matching method(FMM) are also developed in recent years.

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Section: Gas Flow Simulation At Reservoir Scale 31 Flow Modelsmentioning

confidence: 99%

Flow Mechanism and Simulation Approaches for Shale Gas Reservoirs: A Review

2018

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Sharp Reductions in High-Productivity Well Due to Formation Damage: Case Study in Tarim Basin, China

Liu

Yuan

Jian

et al. 2018

Springer Series in Geomechanics and Geoengineering

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Efficient simulation of hydraulic fractured wells in unconventional reservoirs

Ding

Jeannin

2014

Journal of Petroleum Science and Engineering

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Reservoir simulators remain essential tools for improved reservoir management in order to optimize hydraulic fracturing design in unconventional low permeability reservoirs. However, the commonly-used simulator requires too much computational efforts for the description of local phenomena in the vicinity of the hydraulic fractures, and is practically infeasible for field applications, due to large number of gridblocks involved in a full-field simulation with many multifractured complex wells. Therefore, coarse grid simulations have been widely used, but the techniques for the coarse grid simulation of fractured wells need to be improved. In this paper, we present efficient numerical methods to handle both long-term well performance and transient behaviour simulations for hydraulic fractured wells in unconventional reservoirs with a coarse grid. To simulate correctly the long-term behavior, transimissibilities around the fracture and the connection factor between a fractured block and the fracture are computed, based on a (pseudo)-steady-state near-fracture solution. This approach provides not only an accurate long-term well production calculation, but also a correct pressure distribution in the near-fracture region. In unconventional reservoirs, the transient effects cannot be ignored, due to the very low reservoir permeability and near-well/near-fracture physical processes such as fracturing fluid induced formation damage. In order to handle the transient effect, the coupled modeling technique is used, and its efficiency is demonstrated with a tight-gas reservoir.

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Simulation of Fracturing Induced Formation Damage and Gas Production from Fractured Wells in Tight Gas Reservoirs

Cited by 3 publications

References 20 publications

Flow Mechanism and Simulation Approaches for Shale Gas Reservoirs: A Review

Flow Mechanism and Simulation Approaches for Shale Gas Reservoirs: A Review

Sharp Reductions in High-Productivity Well Due to Formation Damage: Case Study in Tarim Basin, China

Efficient simulation of hydraulic fractured wells in unconventional reservoirs

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