Development of innovative and efficient hydraulic fracturing numerical simulation model and parametric studies in unconventional naturally fractured reservoirs

Ahn, Chong Hyun; Dilmore, Robert; Wang, John Yilin

doi:10.1016/j.juogr.2014.06.003

Cited by 21 publications

(14 citation statements)

References 43 publications

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“…In addition to matrix permeability reduction with increasing net stress, propped and unpropped fracture permeability also decreases with increasing net stress (Schubarth et al, 1997;Miller et al, 2011;Ahn et al, 2014). Because fractures represent an important pathway for the movement of fluid through shales, this represents a significant potential source of injectivity and effective storativity reduction.…”

Section: Geologic Properties and Production Of Shalementioning

confidence: 99%

U.S. DOE NETL methodology for estimating the prospective CO2 storage resource of shales at the national and regional scale

Levine

Fukai

Soeder

et al. 2016

International Journal of Greenhouse Gas Control

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a b s t r a c tWhile the majority of shale formations will serve as reservoir seals for stored anthropogenic carbon dioxide (CO 2 ), hydrocarbon-bearing shale formations may be potential geologic sinks after depletion through primary production. Here we present the United States-Department of Energy-National Energy Technology Laboratory (US-DOE-NETL) methodology for screening-level assessment of prospective CO 2 storage resources in shale using a volumetric equation. Volumetric resource estimates are produced from the bulk volume, porosity, and sorptivity of the shale and storage efficiency factors based on formationscale properties and petrophysical limitations on fluid transport. Prospective shale formations require: (1) prior hydrocarbon production using horizontal drilling and stimulation via staged, high-volume hydraulic fracturing, (2) depths sufficient to maintain CO 2 in a supercritical state, generally >800 m, and (3) an overlying seal. The US-DOE-NETL methodology accounts for storage of CO 2 in shale as a free fluid phase within fractures and matrix pores and as an sorbed phase on organic matter and clays. Uncertainties include but are not limited to poorly-constrained geologic variability in formation thickness, porosity, existing fluid content, organic richness, and mineralogy. Knowledge of how these parameters may be linked to depositional environments, facies, and diagenetic history of the shale will improve the understanding of pore-to-reservoir scale behavior, and provide improved estimates of prospective CO 2 storage.Published by Elsevier Ltd.

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Section: Geologic Properties and Production Of Shalementioning

confidence: 99%

U.S. DOE NETL methodology for estimating the prospective CO2 storage resource of shales at the national and regional scale

Levine

Fukai

Soeder

et al. 2016

International Journal of Greenhouse Gas Control

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“…Dynamic coordinates are used to represent hydraulic fracture network propagation and static coordinates to represent natural fractures that have not been activated. 23 The overall dynamic and static coordinates constitute the solution region (Figure 1). Natural fractures open and propagate in the process of fluid injection.…”

Section: Methods Of Fracture Net Work Propagationmentioning

confidence: 99%

“…Therefore, based on the basic parameters shown in Table 3, the results calculated by Ahn et al 23 were used for comparison with the results of the proposed model in this paper (Figure 7). We observed that the calculation results of the proposed model were generally consistent with those of Ahn et al, 23 which verified the correctness of the model used to simulate the propagation of fracture networks. Figure 8 shows the geometric shape of a fracture network and fracture width profile calculated according to basic parameters listed in Table 1, and Figure 9 shows the pore pressure distribution of the reservoir matrix considering pressure-dependent filtration.…”

Section: Check the Convergencementioning

confidence: 99%

New algorithm to simulate fracture network propagation using stationary and moving coordinates in naturally fractured reservoirs

Zhang

Yan

et al. 2020

Energy Science & Engineering

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“…There are many examples in the literature of studies using different numerical methods to solve the problem of fracturing in brittle substances. These numerical methods include the finite difference method (FDM), 12 the boundary element method (BEM), 13,14 the discrete element method (DEM), 15,16 discrete fracture networks (DFNs), 17 the finite element method (FEM), 18–23 the extended finite element method (XFEM), 24 the numerical manifold method (NMM) 25, 26 and discontinuous deformation analysis (DDA) 27 . In addition, particular computer codes, for example, Universal Distinct Element Code (UDEC), 28 the FROCK code, 29 two‐dimensional (2D) particle flow code (PFC 2D ) 30 and rock failure process analysis (RFPA), 31 have been applied to model the failure mechanism of brittle materials such as rock.…”

Section: Introductionmentioning

confidence: 99%

Three‐dimensional finite element simulation of fracture propagation in rock specimens with pre‐existing fissure(s) under compression and their strength analysis

Pakzad

Wang

Sloan

2020

Num Anal Meth Geomechanics

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A FORTRAN program, consistent with the commercially available finite element (FE) code ABAQUS, is developed based on a three-dimensional (3D) linear elastic brittle damage constitutive model with two damage criteria.To consider the heterogeneity of rock, the developed FORTRAN program is used to set the stiffness and strength properties of each element of the FE model following a Weibull distribution function. The reliability of the program is assessed against available experimental results for granite cylindrical specimens with a throughgoing, flat and inclined fissure. The calibration procedure of the material parameters is explained in detail, and it is shown that the compressive to tensile strength ratio can have a substantial influence on the failure response of the specimens. Numerical simulations are conducted for models with different levels of heterogeneity. The results show a smaller load bearing capacity for models with less homogeneity, representing gradual coalescence of fully damaged elements forming throughout the models during loading. The maximum load bearing capacity is studied for various combinations of inclination angles of two centrally aligned, throughgoing and flat fissures of equal length embedded in cylindrical models under uniaxial and multiaxial loading conditions. The key role of the compressive to tensile strength ratio is highlighted by repeating certain simulations with a lower compressive to tensile strength ratio. It is proven that the peak loads of the rock models with sufficiently small compressive to tensile strength ratios containing two throughgoing fissures of equal length are similar, provided that the minimum inclination angles of the models are the same. The results are presented and discussed with respect to the existing experimental findings in the literature, suggesting that the numerical model applied in this study can provide useful insight into the failure behaviour of rock-like materials. K E Y W O R D S3D fracture propagation and coalescence, ABAQUS (UMAT), linear elastic brittle damage constitutive model, Weibull heterogeneity

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Development of innovative and efficient hydraulic fracturing numerical simulation model and parametric studies in unconventional naturally fractured reservoirs

Cited by 21 publications

References 43 publications

U.S. DOE NETL methodology for estimating the prospective CO2 storage resource of shales at the national and regional scale

U.S. DOE NETL methodology for estimating the prospective CO2 storage resource of shales at the national and regional scale

New algorithm to simulate fracture network propagation using stationary and moving coordinates in naturally fractured reservoirs

Three‐dimensional finite element simulation of fracture propagation in rock specimens with pre‐existing fissure(s) under compression and their strength analysis

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