A critical review on coupled geomechanics and fluid flow in naturally fractured reservoirs

Hawez, H.; Sanaee, Reza; Faisal, Nadimul Haque

doi:10.1016/j.jngse.2021.104150

Cited by 24 publications

(10 citation statements)

References 149 publications

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“…In the fractured reservoir, the research mainly focuses on oil displacement effect, percolation characteristics, , fracture network model construction, − and mobility control. , Among them, mobility control is an important content in the late stage of fractured reservoir development. At present, the main plugging agents used for mobility control include polymer, , gel, foam, etc.…”

Section: Introductionmentioning

confidence: 99%

Dynamic Simulation Research on Microprofile Control Mechanism of Foam in Fractured Media Based on Level Set Method

Wang,

Yu,

Chen

et al. 2024

Langmuir

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Fractured reservoirs are an important source of oil and gas energy. After depletion of production, the production capacity of this reservoir decreases rapidly. Effective profile control is needed to improve the sweep efficiency and reservoir heterogeneity. Foam can solve such problems, but its profile control mechanism is not fully understood. Based on this, this paper uses the level set method to study the microscale control mechanism of foam in fractured media. The results show that artificial fractures and high-permeability microfractures are tighter than natural fractures, the Jamin effect of foam is stronger, and the secondary foaming ability is better. Therefore, the plugging ability of foam to natural fractures is far less than that of foam to artificial fractures and highpermeability microfractures. The larger the fracture opening, the larger the foam volume and the smaller the flow rate. As the opening ratio increases gradually, the generated foam flows more to the natural fractures with a large opening, and the effect of foam blocking large fractures becomes worse. The diversion rate curves of different opening ratios show that the foam has a good profile control effect when the opening ratios are 4:1 and 2:1, and even the diversion rate overturns, while the profile control diversion effect is poor when the opening ratio is 10:1, so it cannot play an effective role in profile control. The foam shows the profile control process of preferentially plugging the high-permeability area and allowing more subsequent fluids to enter the low-permeability area. The research reveals the profile control mechanism of foam on fractured reservoirs from the micro level, which is the supplement and verification of relevant macro research and provides a theoretical basis for the efficient development of fractured reservoirs.

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Section: Introductionmentioning

confidence: 99%

Dynamic Simulation Research on Microprofile Control Mechanism of Foam in Fractured Media Based on Level Set Method

Wang,

Yu,

Chen

et al. 2024

Langmuir

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“…By implementing measures to adjust particle flow channels, significant changes have been observed in the flow characteristics of fractured reservoirs, and positive production feedback has been obtained onsite [16,17]. However, due to the intricate nature of karst caves and fractures as well as their interconnections within fractured reservoirs, the field implementation of flow channel adjustments for different well conditions requires distinct process parameters [18].…”

Section: Introductionmentioning

confidence: 99%

CFD−DEM Simulation of a Jamming Mechanism and Influencing Factors of a Fracture-Shrinking Model

Zhang,

Lu,

Zhang

et al. 2024

Processes

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Fractured-vuggy reservoirs are crucial for increasing unconventional oil storage and production, but the controlling mechanism of this dominant flow channel remains vague, and the jamming mechanism of modulator particles is unclear. This study explores the filling and jamming processes of particles in the fractures by conducting a computational fluid dynamics−discrete element method (CFD−DEM) coupled simulation, considering the variation of fracture width, fluid velocity, particle size, and concentration. Results suggest that four sealing modes are proposed: normal filling, local jamming, complete sealing, and sealing in the main fracture. The ratio of particle size to the main fracture width exerts the primary role, with the ratio having a range of 0.625 < D/W ≤ 0.77 revealing complete jamming. Furthermore, an optimal particle size for achieving stable sealing is observed when the particle size varies from 2 to 2.5 mm. A higher concentration of particles yields better results in the fracture-shrinking model. Conversely, a greater velocity worsens the sealing effect on fractures. This research can offer technical support for the large-scale dissemination of flow regulation technology.

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“…Multiphase fow modeling in naturally fractured reservoirs has been considered an issue for petroleum reservoir engineers [9,10]. Warren and Root have shown a dualporosity model which presents multiphase behavior in fractured reservoirs [11].…”

Section: Introductionmentioning

confidence: 99%

Fluid Flow Behavior Prediction in Naturally Fractured Reservoirs Using Machine Learning Models

et al. 2023

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The naturally fractured reservoirs are one of the most challenging due to the tectonic movements that are caused to increase the permeability and conductivity of the fractures. The instability of the permeability and conductivity effects on the fluid flow path causes problems during the transfer of the fluids from the matrix to the fractures and fluid losses during production. In addition, these complications made it difficult for engineers to estimate fluid flow during production. The fracture properties’ study is important to model the fluid flow paths such as the fracture porosity, permeability, and the shape factor, which are considered essential in the stability of fluid flow. To examine this, this research introduced new models including decision tree (DT), random forest (RF), K-nearest regression (KNR), ridge regression (RR), and LASSO regression model,. The research studied the fracture properties in naturally fractured reservoirs like the fracture porosity (FP) and the shape factor (SF). The datasets used in this study were collected from previous studies “i.e., Texas oil and gas fields” to build an intelligence-based predictive model for fluid flow characteristics. The prediction process was conducted based on interporosity flow coefficient, storativity ratio, wellbore radius, matrix permeability, and fracture permeability as input data. This study revealed a positive finding for the adopted machine learning (ML) models and was superior in using statistical accuracy metrics. Overall, the research emphasized the implementation of computer-aided models for naturally fractured reservoir analysis, giving more details on the extensive execution techniques, such as injection or the creation of artificial cracks, to minimize hydrocarbon losses or leakage.

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A critical review on coupled geomechanics and fluid flow in naturally fractured reservoirs

Cited by 24 publications

References 149 publications

Dynamic Simulation Research on Microprofile Control Mechanism of Foam in Fractured Media Based on Level Set Method

Dynamic Simulation Research on Microprofile Control Mechanism of Foam in Fractured Media Based on Level Set Method

CFD−DEM Simulation of a Jamming Mechanism and Influencing Factors of a Fracture-Shrinking Model

Fluid Flow Behavior Prediction in Naturally Fractured Reservoirs Using Machine Learning Models

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