Modeling and Simulation of Shale Gas Production in Multi-Staged Hydraulic-Fractured Formations

Lee, S. H.; Jensen, Clair; Lunati, Ivan

doi:10.3997/2214-4609.20143216

Cited by 2 publications

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“…In [24,35], the authors discuss a general framework, where the equations also include nonlinear diffusivity due to adsorbed gas in a shale formation. In [22], the nonlinear terms appear due to barotropic effects.…”

Section: Model Problemmentioning

confidence: 99%

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Multiscale model reduction for shale gas transport in fractured media

2016

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In this paper, we develop a multiscale model reduction technique that describes shale gas transport in fractured media. Due to the pore-scale heterogeneities and processes, we use upscaled models to describe the matrix. We follow our previous work [1], where we derived an upscaled model in the form of generalized nonlinear diffusion model to describe the effects of kerogen. To model the interaction between the matrix and the fractures, we use Generalized Multiscale Finite Element Method [13,17]. In this approach, the matrix and the fracture interaction is modeled via local multiscale basis functions. In [17], we developed the GMsFEM and applied for linear flows with horizontal or vertical fracture orientations on a Cartesian fine grid. In this paper, we consider arbitrary fracture orientations and use triangular fine grid and developed GMsFEM for nonlinear flows. Moreover, we develop online basis function strategies to adaptively improve the convergence. The number of multiscale basis functions in each coarse region represents the degrees of freedom needed to achieve a certain error threshold. Our approach is adaptive in a sense that the multiscale basis functions can be added in the regions of interest. Numerical results for two-dimensional problem are presented to demonstrate the efficiency of proposed approach.

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Section: Model Problemmentioning

confidence: 99%

“…Error estimators for the spatial discretization error take into account the dependence of the elliptic problem (22) on the time step parameter τ and we will use the τ -weighted H 1 norm…”

Section: Residual Based Adaptive Online Gmsfemmentioning

confidence: 99%

Multiscale model reduction for shale gas transport in fractured media

2016

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A Statistical Dual-Tube Model to Analyze Gas Production from Shale Formations

Lee

Jensen

Lunati³

2015

SPE Reservoir Simulation Symposium

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Gas flow through fractured nano-porous shale formations is complicated by a hierarchy of structural features and fluid transport mechanisms. Structural features include tight porous rock with a variety of fractures. Gas transport mechanisms include self diffusion, Knudsen diffusion, advection, gas expansion, adsorption, and slippage effects at the pore walls. In nanopores, as encountered in tight shale gas reservoirs, the effects of diffusion can overcome advection and should be included in reservoir flow calculations. As the permeability of shale is very low, conventional reservoir simulation modeling and production estimation methods, which are designed for fluid-flow processes dominated by viscous forces, may not be reliable to predict the reservoir production rate. We present a pore-based mechanistic model (the Bundle of Dual-Tube Model, BoDTM), which includes complex gas dynamics in fractured nanoporous shale formations. The pore-based model provides a quick and reliable means for modeling tight rock gas flow that includes known and uncertain reservoir properties, such as rock permeability, diffusion, pore volume, pore throat size, rock tortuosity and fracture characteristics. Gas flow is modeled in the shale matrix and production rate is estimated with a simple bundle of dual-tubes. Each dual-tube idealizes a gas pathway formed by pore bulbs and throats and is characterized by two diameters (a conductive diameter and a storage diameter) and one length. The two diameters permit modeling slow recovery of large gas volumes; the tube length takes into account the pathway length from the matrix into the fracture network, which is the length that controls the travel time and the production rate. To construct the BoDTM, a statistical estimate of the fracture-network and shale-matrix parameters is necessary. Production rate is controlled by flow from the tight shale rock matrix (which has the largest storage capacity but the lowest diffusivity) into the fracture network, and we assume that gas in the fractures is produced instantaneously. Applying statistical distribution functions, we examine the effect of model input properties on gas production. By applying the BoDTM to field data from the Barnett and Fayetteville Plays, we demonstrate that the model provides a means to quickly assess gas production rates from shale formations.

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Modeling and Simulation of Shale Gas Production in Multi-Staged Hydraulic-Fractured Formations

Cited by 2 publications

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Multiscale model reduction for shale gas transport in fractured media

Multiscale model reduction for shale gas transport in fractured media

A Statistical Dual-Tube Model to Analyze Gas Production from Shale Formations

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