Simulation of a multistage fractured horizontal well in a tight oil reservoir using an embedded discrete fracture model

Zhao, Yulong; Liu, Lingfu; Zhang, Liehui; Zhang, Xu‐Yang; Li, Bo

doi:10.1002/ese3.379

Cited by 19 publications

(6 citation statements)

References 47 publications

(95 reference statements)

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“…Before the mathematical model is established, the fracture network needs to be characterized explicitly. Many fracture models have been developed in the past few years, such as discrete fracture network model (DFN), discrete fracture model (DFM), and embedded discrete fracture model (EDFM) . In the DFN, fluid flow can only occur in the fracture medium, which means the permeability of the matrix is neglected.…”

Section: Governing Equations For Fracture Flowsmentioning

confidence: 99%

A Galerkin‐free/equation‐free model reduction method for single‐phase flow in fractured porous media

Han

Tang

et al. 2020

Energy Science & Engineering

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Using traditional high‐fidelity numerical simulation to simulate fluid flow in fractured porous media in a real field remains challenging. It involves a large number of degrees of freedom when matrix and fracture equations are solved. To address this challenge, we propose a Galerkin‐free framework to construct a reduced‐order model (ROM) based on the proper orthogonal decomposition (POD). Compared with the typical POD‐based modeling process commonly used in previous studies, the POD‐ROM can be built without performing the Galerkin projection of flow equations onto the low‐dimensional space spanned by the POD basis functions. The numerical integration method was incorporated to obtain the POD time coefficients based on the flow equations solved by the conventional finite volume method. Two complex fracture cases reflecting high‐contrast porous media in a two‐dimensional domain were designed to verify the accuracy and efficiency of the established Galerkin‐free POD‐ROM. Sensitivity analysis of parameters was conducted to examine the adaptability of the ROM. The results illustrate that, compared with the fine‐scale model, the ROM can significantly reduce the CPU time without compromising the quality of the numerical solutions.

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Section: Governing Equations For Fracture Flowsmentioning

confidence: 99%

A Galerkin‐free/equation‐free model reduction method for single‐phase flow in fractured porous media

Han

Tang

et al. 2020

Energy Science & Engineering

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“…And there are many models that have been proposed, such as the liner flow model, discrete fracture models, and fractured horizontal well in different outer boundaries, so the readers can utilize the models presented in this paper to analyze the well production performance of different models. Besides, the conceptual model can also be considered in the numerical simulation [82][83][84][85].…”

Section: Geofluidsmentioning

confidence: 99%

A Review of Gas Flow and Its Mathematical Models in Shale Gas Reservoirs

et al. 2020

Self Cite

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The application of horizontal wells with multistage hydraulic fracturing technologies has made the development of shale gas reservoirs become a worldwide economical hotspot in recent years. The gas transport mechanisms in shale gas reservoirs are complicated, due to the multiple types of pores with complex pore structure and special process of gas accumulation and transport. Although there have been many attempts to come up with a suitable and practical mathematical model to characterize the shale gas flow process, no unified model has yet been accepted by academia. In this paper, a comprehensive literature review on the mathematical models developed in recent years for describing gas flow in shale gas reservoirs is summarized. Five models incorporating different transport mechanisms are reviewed, including gas viscous flow in natural fractures or macropores, gas ad-desorption on shale organic, gas slippage, diffusion (Knudsen diffusion, Fick diffusion, and surface diffusion), stress dependence, real gas effect, and adsorption layer effect in the nanoshale matrix system, which is quite different from conventional gas reservoir. This review is very helpful to understand the complex gas flow behaviors in shale gas reservoirs and guide the efficient development of shale gas. In addition to the model description, we depicted the type curves of fractured horizontal well with different seepage models. From the review, it can be found that there is some misunderstanding about the essence of Knudsen/Fick diffusion and slippage, which makes different scholars adopt different weighting methods to consider them. Besides, the contribution of each mechanism on the transport mechanisms is still controversial, which needs further in-depth study in the future.

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“…With the rapid depletion of reservoir energy, the oil production declines rapidly. 23 − 27 To improve the production and recovery factor (RF) of TSTRs, the Tuha Oilfield has conducted a lot of research in the past five years and found that the water huff-n-puff (WHP) technology has great application prospects. 28 − 34 In the pilot test area, a total of 52 wells have been conducted with WHP, and the efficiency rate is 92.3%.…”

Section: Introductionmentioning

confidence: 99%

Study on Influencing Factors of Water Huff-n-Puff Oil Recovery in Matrix-Fracture Systems of the Tight Sedimentary Tuff Reservoirs

Yang

Jin

et al. 2022

ACS Omega

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Tight sedimentary tuff reservoirs (TSTRs) are a new type of tight oil reservoirs, which are mainly developed by water huff-n-puff (WHP). However, there is no quantitative study on the effect of water injection pressure (WIP) and fracture density (FD) on the oil recovery effect of WHP, and the reasons for the low flow-back rate (FR) of the injected water are also not fully explained. In this study, the real cores of TSTRs were used to simulate the seepage state of the matrix-fracture systems of the reservoir, the effects of WIP and FD on the WHP were quantitatively studied, and the reasons for the low FR of the injected water were comprehensively analyzed. The result shows that in five cycles of WHP, the recovery factor (RF) of the core only increases from 8.72 to 10.91% with the WIP increasing from 25 to 30 MPa. However, when the WIP is 40 MPa (rock breakdown pressure), the RF of the core reaches 16.47%, indicating that overfracture-pressure water injection has an obvious improvement effect on the oil recovery effect of WHP in TSTRs. Increasing the FD can also significantly improve the RF and oil recovery efficiency (ORE) of WHP in TSTRs. When the FD of the core increases from 0.34 to 0.44 cm –1 , the RF of five cycles of WHP increases by 9.26%, the ORE increases by 8.61%, and the FR of the injected water decreases by 0.56%. The reasons for the low FR of the injected water in WHP in tight oil reservoirs are matrix water locking, fracture water locking, and reservoir nonconstant-volume water locking. The study can provide an important reference for the efficient development of the WHP in TSTRs.

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Simulation of a multistage fractured horizontal well in a tight oil reservoir using an embedded discrete fracture model

Cited by 19 publications

References 47 publications

A Galerkin‐free/equation‐free model reduction method for single‐phase flow in fractured porous media

A Galerkin‐free/equation‐free model reduction method for single‐phase flow in fractured porous media

A Review of Gas Flow and Its Mathematical Models in Shale Gas Reservoirs

Study on Influencing Factors of Water Huff-n-Puff Oil Recovery in Matrix-Fracture Systems of the Tight Sedimentary Tuff Reservoirs

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