Improving coarse-scale simulation models with a dual-porosity dual-permeability upscaling technique and a near-well approach

Rios, Victor de Souza; Schiozer, Denis José; Santos, Luiz Otávio Schmall dos; Skauge, Arne

doi:10.1016/j.petrol.2020.108132

Cited by 7 publications

(3 citation statements)

References 18 publications

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“…Furthermore, there are various investigations performed in the literature based on a bridge between the dual-porosity approach and other techniques to enhance the accuracy of the dual-porosity results. [54][55][56][57][58][59][60][61][62][63] However, in most of the aforementioned studies, the applied shape factor is assumed to be constant in both unsteady and steady-state situations and only depends on the geometry of blocks. Accordingly, these assumptions lead to significant errors in the simulations, especially in the transient stages.…”

Section: Introductionmentioning

confidence: 99%

“…A summary of the dimensionless shape factors obtained from the previous studies is presented in Table 1. Furthermore, there are various investigations performed in the literature based on a bridge between the dual‐porosity approach and other techniques to enhance the accuracy of the dual‐porosity results 54–63 . However, in most of the aforementioned studies, the applied shape factor is assumed to be constant in both unsteady and steady‐state situations and only depends on the geometry of blocks.…”

Section: Introductionmentioning

confidence: 99%

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A computational dual‐porosity approach for the coupled hydro‐mechanical analysis of fractured porous media

Khoei,

Taghvaei

2024

Num Anal Meth Geomechanics

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Dual‐porosity simulation is one of the most used and efficient approaches in modeling fractured porous media. The performance of this approach is highly dependent on the accuracy of the definition of matrix‐fracture transfer shape factor. In this paper, a two‐step computational algorithm is developed to enhance the accuracy of the dual‐porosity method in modeling large‐scale deformable porous media, particularly in the transient stage when the conventional dual‐porosity models are associated with some errors. Moreover, in the proposed finite element method (FEM)‐based algorithm, the interaction between the fluid and solid phases is taken into account using a modified expression for the conventional shape factor. To this end, an extended relationship is derived to calculate the hydro‐mechanical shape factor for deformable saturated porous media. An appropriate unit cell along with the consistent boundary conditions is introduced, and the corresponding hydro‐mechanical shape factor is numerically evaluated for the unit cell at each time step. Finally, the calculated time‐varying shape factors are employed in a dual‐porosity framework to simulate various case studies and investigate the influence of different parameters, including the boundary conditions, the fracture to matrix permeability ratio, and the fracture compressibility coefficient on the hydraulic and hydro‐mechanical time‐varying shape factors. Numerical simulations are carried out by employing the proposed dual‐porosity algorithm through two general problems and the results are compared with the fine‐grid direct numerical simulation. The results are promising and show that the present algorithm effectively and efficiently increases the precision of the dual‐porosity method in modeling large‐scale deformable problems.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

A computational dual‐porosity approach for the coupled hydro‐mechanical analysis of fractured porous media

Khoei,

Taghvaei

2024

Num Anal Meth Geomechanics

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“…e only difference is that, in all cases, the matrix can also produce into the well [21]. Many researches have been conducted on naturally fractured reservoirs applying the dual-porosity and dual-permeability model [36,[38][39][40][41][42][43][44][45][46][47][48][49][50][51].…”

Section: Introductionmentioning

confidence: 99%

Numerical Well Test Analysis of Condensate Dropout Effects in Dual-Permeability Model of Naturally Fractured Gas Condensate Reservoirs: Case Studies in the South of Iran

Safari-Beidokhti¹,

Hashemi

Abdollahi³

et al. 2021

Mathematical Problems in Engineering

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Naturally fractured reservoirs (NFR) represent an important percentage of worldwide hydrocarbon reserves and production. The performance of naturally fractured gas condensate reservoirs would be more complicated regarding both rock and fluid effects. In contrast to the dual-porosity model, dual-porosity/dual-permeability (dual-permeability) model is considered as a modified model, in which flow to the wellbore occurs through both matrix and fracture systems. Fluid flow in gas condensate reservoirs usually demonstrates intricate flow behavior when the flowing bottom-hole pressure falls below the dew point. Accordingly, different regions with different characteristics are formed within the reservoir. These regions can be recognized by pressure transient analysis. Consequently, distinguishing between reservoir effects and fluid effects is challenging in these specific reservoirs and needs numerical simulation. The main objective of this paper is to examine the effect of condensate banking on the pressure behavior of lean and rich gas condensate NFRs through a simulation approach. Subsequently, evaluation of early-time characteristics of the pressure transient data is provided through a single well compositional simulation model. Then, drawdown, buildup, and multirate tests are conducted to establish the condition in which the flowing bottom-hole pressure drops below the dew point causing retrograde condensation. The simulation results are confirmed through well test analysis in both Iranian naturally fractured rich and lean gas condensate fields. Interpretations of simulation analysis revealed that the richer gas is more prone to condensation. When the pressure drops below the dew point, the pressure derivative curves in the rich gas system encounter a more shift to the right, and the trough becomes more pronounced as compared to the lean one.

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Simulation Enhancement GAN for Efficient Reservoir Simulation at Fine Scales

Liu,

Yang,

Zhang

et al. 2024

Math Geosci

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Improving coarse-scale simulation models with a dual-porosity dual-permeability upscaling technique and a near-well approach

Cited by 7 publications

References 18 publications

A computational dual‐porosity approach for the coupled hydro‐mechanical analysis of fractured porous media

A computational dual‐porosity approach for the coupled hydro‐mechanical analysis of fractured porous media

Numerical Well Test Analysis of Condensate Dropout Effects in Dual-Permeability Model of Naturally Fractured Gas Condensate Reservoirs: Case Studies in the South of Iran

Simulation Enhancement GAN for Efficient Reservoir Simulation at Fine Scales

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