Geologic Analysis of Naturally Fractured Reservoirs

Nelson, Ronald A.

doi:10.1016/b978-0-88415-317-7.x5000-3

Cited by 206 publications

(8 citation statements)

References 175 publications

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“…We consider a fully penetrated well in an infinite porous media with a single porosity system, i.e., a Type I fractured system of Nelson [19], constant initial pressure, permeability, density and viscosity. Furthermore, we consider that the fluid flow at a given point is governed not only by the properties of the pressure field at that specific position but also depends on the global spatial distribution of that field, and lastly, we consider that the radial symmetry is valid.…”

Section: Model Developmentmentioning

confidence: 99%

Spatial Fractional Darcy’s Law on the Diffusion Equation with a Fractional Time Derivative in Single-Porosity Naturally Fractured Reservoirs

et al. 2022

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Due to the complexity imposed by all the attributes of the fracture network of many naturally fractured reservoirs, it has been observed that fluid flow does not necessarily represent a normal diffusion, i.e., Darcy’s law. Thus, to capture the sub-diffusion process, various tools have been implemented, from fractal geometry to characterize the structure of the porous medium to fractional calculus to include the memory effect in the fluid flow. Considering infinite naturally fractured reservoirs (Type I system of Nelson), a spatial fractional Darcy’s law is proposed, where the spatial derivative is replaced by the Weyl fractional derivative, and the resulting flow model also considers Caputo’s fractional derivative in time. The proposed model maintains its dimensional balance and is solved numerically. The results of analyzing the effect of the spatial fractional Darcy’s law on the pressure drop and its Bourdet derivative are shown, proving that two definitions of fractional derivatives are compatible. Finally, the results of the proposed model are compared with models that consider fractal geometry showing a good agreement. It is shown that modified Darcy’s law, which considers the dependency of the fluid flow path, includes the intrinsic geometry of the porous medium, thus recovering the heterogeneity at the phenomenological level.

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Section: Model Developmentmentioning

confidence: 99%

Spatial Fractional Darcy’s Law on the Diffusion Equation with a Fractional Time Derivative in Single-Porosity Naturally Fractured Reservoirs

et al. 2022

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“…Naturally Fractured Reservoirs (NFRs) are reservoirs with naturally occurring fractures that significantly impact porosity, permeability, production rate, and recovery (Narr et al, 2006;Nelson, 2001). Therefore, they differ considerably in many areas, including geology, geophysics, performance, and economics (Warren & Root, 1963).…”

Section: Implication Of Fracturesmentioning

confidence: 99%

“…Therefore, they differ considerably in many areas, including geology, geophysics, performance, and economics (Warren & Root, 1963). Nelson (2001) defined fractured reservoirs based on the impact of the fracture on porosity and permeability (He, Santoso, et al, 2021;He, Sinan, et al, 2021;Lyons et al, 2015;Nelson, 2001). The four types of fractures are summarized in Table 2 (Nelson, 2001).…”

Section: Implication Of Fracturesmentioning

confidence: 99%

An Experimental and Numerical Approach for the Best Enhanced Oil Recovery Strategy in Capillary-Dominant Reservoirs

Alabdulghani

Hoteit

Abdullah

2022

Day 1 Mon, March 21, 2022

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Working with naturally fractured reservoirs (NFRs) can be challenging. Inadequate understanding of the enhanced oil recovery (EOR) driving forces in these reservoirs may result in serious conformance issues due to excessive water production. As a result, this work investigates and numerically validates some fundamental flow mechanisms in heterogeneous reservoirs, particularly capillary-dominant ones, to highlight the best EOR strategy for this specific case. Consequently, a two-dimensional lab-scale reservoir model with injection and production ports was designed, fabricated, and tested in single-phase and two-phase flow scenarios, simulating a water-wet fractured system. First, a single-phase flow waterflood baseline was studied, compared to the literature, verified by commercial reservoir simulation software, and eventually considered to calibrate the porosity and permeability model in the simulation model where the controlling variables are limited. Based on this work, the same procedures were experimentally repeated and verified by simulation, where waterflooding and polymer injection were used to displace oil with more governing variables. The single-phase scenarios aided in distinguishing between the waterflood and polymer flood cases. Water prefers to channel through high permeable streaks when injected into a fractured water-wet reservoir, resulting in poor volumetric sweep and significant bypassed zones. Whereas the controlling variables in two-phase flow were increased, capillarity and mobility ratio were dominant in the simulation. During waterflooding, flow divergence was observed faster toward the matrix medium, overriding the high permeability front in the fracture due to the strong capillarity contrast between the matrix and fracture media. Even when capillarity is strongly present, polymer flooding demonstrated a better volumetric sweep in all scenarios. The unique demonstration of fluid flow inside the two-dimensional lab-scale reservoir model, as well as numerical simulation, shed light on the efficacy of these EOR strategies in fractured reservoirs. Furthermore, for the first time, the behavior of capillary-dominant reservoirs with an advancing flow path within smaller pores compared to larger ones within the reservoir media has been experimentally captured. Understanding reservoir characteristics and having the know-how to implement the best recovery scenario can, in fact, maximize the field's life cycle and increase the Recovery Factor (RF).

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“…Fault zones may cut across several geological units and provide catchment scale preferential flow paths in the form of strongly connected clusters of fractures (Bodvarsson et al, 1997;Flint et al, 2001; H. H. Liu et al, 2004). Tectonically induced stress fields and stress field changes generally promote the formation of local discontinuities, such as fractures, joints and fault zones in consolidated porous rocks (Ford & Williams, 2013;Neslon, 2001). What sets such features apart from typical pore space geometries is their strong anisotropic character, i.e., their length or spatial extent is orders of magnitude larger than their aperture.…”

Section: Accepted Articlementioning

confidence: 99%

“…H. Liu et al, 2004). Tectonically induced stress fields and stress field changes generally promote the formation of local discontinuities, such as fractures, joints, and fault zones in consolidated porous rocks (Ford & Williams, 2013;Neslon, 2001). What sets such features apart from typical pore space geometries is their strong anisotropic character, that is, their length or spatial extent is orders of magnitude larger than their aperture.…”

mentioning

confidence: 99%

Numerical and Analytical Modeling of Flow Partitioning in Partially Saturated Fracture Networks

Kordilla

Dentz

Tartakovsky

2021

Water Resources Research

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Geologic Analysis of Naturally Fractured Reservoirs

Cited by 206 publications

References 175 publications

Spatial Fractional Darcy’s Law on the Diffusion Equation with a Fractional Time Derivative in Single-Porosity Naturally Fractured Reservoirs

Spatial Fractional Darcy’s Law on the Diffusion Equation with a Fractional Time Derivative in Single-Porosity Naturally Fractured Reservoirs

An Experimental and Numerical Approach for the Best Enhanced Oil Recovery Strategy in Capillary-Dominant Reservoirs

Numerical and Analytical Modeling of Flow Partitioning in Partially Saturated Fracture Networks

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