A heterogeneous model for simulating fluid flow in naturally fractured-vuggy carbonate reservoirs

Zhang, Haixiang; Peng, Weihong; Hao, Pengfei; Du, Menglin

doi:10.1504/ijogct.2019.099175

Cited by 5 publications

(1 citation statement)

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“…These methods have also achieved some results in practical applications, but they also have obvious limitations. In addition, for offshore low-permeability reservoirs with strong heterogeneity and natural fractures, there are relatively few studies on capacity evaluation, and a large number of scholars refer to the Jubilee formula [18] for capacity calculation. Under the influence of sedimentation, diagenesis, and tectonic movement, natural fractures in offshore low-permeability limestone reservoirs are more developed, and the presence of fractures improves the physical properties of the reservoir and increases the production capacity of oil wells.…”

Section: Introductionmentioning

confidence: 99%

New Method for Capacity Evaluation of Offshore Low-Permeability Reservoirs with Natural Fractures

Wang,

Xie,

Liu

et al. 2024

Processes

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In recent years, the development of two offshore low-permeability oil fields has revealed unexpected challenges. The actual productivity of these fields significantly deviates from the designed capacity. Some wells even outperform the expectations for low-permeability limestone fields. This discrepancy primarily stems from a lack of accurate understanding of natural fractures before and after drilling, resulting in substantial errors in capacity assessment. This paper addresses these challenges by proposing a new production capacity model and evaluation method for both vertical and horizontal wells in low-permeability limestone reservoirs. The method leverages logging curve data, incorporating vertical gradation and fractal analysis to effectively represent the fracture’s complexity and connectivity. It uniquely considers factors such as fracture fractal dimensions, threshold pressure, and stress sensitivity, significantly enhancing prediction accuracy. Furthermore, by analyzing the longitudinal gradient in logging curves, the method effectively identifies strong heterogeneity, leading to more accurate capacity evaluations in actual fields. The results demonstrate that our model reduces the average prediction error to less than 15%, markedly outperforming traditional methods. Calculation results of the newly developed capacity formula align closely with actual production data and tracer test results, showcasing its practical applicability and potential for widespread use. This study notably advances the evaluation of reasonable production capacity in similar offshore reservoirs.

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Section: Introductionmentioning

confidence: 99%

New Method for Capacity Evaluation of Offshore Low-Permeability Reservoirs with Natural Fractures

Wang,

Xie,

Liu

et al. 2024

Processes

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Novel methodology to couple decline curve analysis with CFD reservoir simulations for complex shale gas reservoirs

Khadri,

Al‐Marri,

Nasser

et al. 2024

Can J Chem Eng

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Shale reservoirs are highly complex and are difficult to study using conventional reservoir simulation tools. This study introduces a novel methodology for estimating production from complex shale gas reservoirs by coupling decline curve analysis (DCA) with computational fluid dynamics (CFD) simulations. The proposed method uses exponential DCA to analyze production data from a dual porosity–permeability shale gas transport model. These complexities include fracture characteristics, geomechanical properties, nanopore confinement effects, and multiple flow mechanisms contributing to the total production performance. The shale gas transport model is validated through historical production data from Marcellus shale. The new methodology also tests fracture characteristics. It shows that increased porosity and permeability will increase the recoverable reserves but will have varying effects on the decline rate. The paper demonstrates the advantages of the proposed methodology over conventional reservoir simulation tools. It provides insights into the factors affecting shale gas production performance through the inclusion of the complexities of an unconventional shale gas reservoir. The paper provides a proof of concept on the particular reservoir of which the field data is provided—Barnett and Marcellus Shale.

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Study on the surface crack propagation mechanism of coal and sandstone subjected to cryogenic cooling with liquid nitrogen

Gao

Cai

et al. 2020

Journal of Natural Gas Science and Engineering

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A heterogeneous model for simulating fluid flow in naturally fractured-vuggy carbonate reservoirs

Cited by 5 publications

References 0 publications

New Method for Capacity Evaluation of Offshore Low-Permeability Reservoirs with Natural Fractures

New Method for Capacity Evaluation of Offshore Low-Permeability Reservoirs with Natural Fractures

Novel methodology to couple decline curve analysis with CFD reservoir simulations for complex shale gas reservoirs

Study on the surface crack propagation mechanism of coal and sandstone subjected to cryogenic cooling with liquid nitrogen

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