Characterizing hydraulic and natural fractures properties in shale oil well in Permian basin using assisted history matching

Tripoppoom, Sutthaporn; Wang, Xin; Liu, Zhe; Yu, Wei; Xie, Heping; Sepehrnoori, Kamy; Miao, Jijun

doi:10.1016/j.fuel.2020.117950

Cited by 21 publications

(12 citation statements)

References 11 publications

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“…The secondary pores are formed after the formation of the shale. They are mainly fractures/microfractures formed as a result of the stress change during tectonic movement and uplift or dissolution by the underground fluid. , The factures formed by stress change are generally vertical, therefore, they can be easily distinguished from the interlaminar fractures . More details of the pore classification are included in Table , which is modified from Jiang et al by adding more information.…”

Section: Shale Mineralogy Pore Structure and Fluid Propertiesmentioning

confidence: 99%

Laboratory Characterization of Shale Oil Storage Behavior: A Comprehensive Review

Pan

Liu

et al. 2021

Energy Fuels

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Shale oil has become an important oil resource over the past decade. The oil storage behavior, including the adsorbed oil and free oil, is one of the most important controlling factors for shale oil production. Because the shale oil storage behavior is largely determined by the fluid and solid interactions, this review first evaluates the shale mineralogy, pore structure, and oil properties. Then, the experimental methods to characterize the free oil and adsorbed oil are reviewed. The relationship between the oil storage behavior and shale and oil properties are then discussed. It is concluded from the literature work that the organic matter has the highest adsorption capacity for oil, followed by clay minerals, quartz, and calcite. While it is well-known that heavier oil components are adsorbed more than the lighter components, a relationship between the ratio of pore size to oil molecular size and the ratio of free oil to adsorbed oil is suggested and plotted. Finally, it is found from the literature that accurate experimental methods and theoretical models on free oil and adsorbed oil characterization are still missing; therefore, these topics require attention in future researches on shale oil.

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Section: Shale Mineralogy Pore Structure and Fluid Propertiesmentioning

confidence: 99%

Laboratory Characterization of Shale Oil Storage Behavior: A Comprehensive Review

Pan

Liu

et al. 2021

Energy Fuels

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“…In addition, the longitudinal fluid flow inside the fracture channels follows the cubic law of parallel plates considering an initial fracture The proxy model of the KGD problem was built using several hydraulic fracturing numerical models based on the governing equations presented in Section 2. The Latin hypercube method generated 1000 sample points combining the geomechanical parameters investigated in the inverse analysis: Young's modulus 𝐸, tensile strength 𝜎 𝑡 , in situ compressive stress 𝜎 𝑜 , and rock permeability 𝑘. Tripoppoom et al [43][44][45][46] and Kohler et al 60 also employed this technique to build proxy models.…”

Section: Numerical Model and Dataset Generationmentioning

confidence: 99%

“…The Latin hypercube method generated 1000 sample points combining the geomechanical parameters investigated in the inverse analysis: Young's modulus E , tensile strength

{\sigma _t}

, in situ compressive stress

{\sigma _o}

, and rock permeability k . Tripoppoom et al 43–46 . and Kohler et al 60 .…”

Section: Parameter Identification Applicationmentioning

confidence: 99%

“…Several history matching procedures have considered uncertainty quantification of oil and gas applications using machine learning modeling to develop proxy models. Production data of hydraulic-fractured shale wells were matched using Markov chain Monte Carlo and k-nearest neighbors algorithm, 43 artificial neural networks, 44,45 or both. 46 However, these authors used the proxy model to perform predictions in some specified measured times.…”

Section: Introductionmentioning

confidence: 99%

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Inverse analysis of hydraulic fracturing tests based on artificial intelligence techniques

Abreu

Mejia

Roehl

2022

Num Anal Meth Geomechanics

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In the last decades, the study of fluid flow through discontinuities such as fractures has received significant attention from the petroleum industry owing to the discovery of naturally fractured reservoirs. Predicting the behavior of this type of reservoir is challenging and includes, as a crucial step, determining its geomechanical parameters. Several in situ tests and empirical relationships have been established to estimate these parameters. Nevertheless, these procedures have important limitations. This work proposes an artificial intelligence-based methodology to identify geomechanical parameters from borehole injection pressure curves obtained during hydraulic fracturing tests. This methodology applies a genetic algorithm to minimize the sum of squared differences between the observed and predicted borehole pressure curves. Furthermore, an artificial neural network is adopted to build a proxy model that substitutes hydraulic fracturing numerical simulations, substantially reducing computational time. A proper recursive strategy is adopted to predict the borehole pressure curves.Additionally, a hyperparameter tuning technique selects appropriate neural network hyperparameters based on the multistep-ahead prediction error. Finally, the framework is applied in a KGD problem that models hydraulic fracture propagation. The benchmark confirms the capability of the proposed methodology to identify geomechanical parameters from fracturing tests.

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“…In recent years, shale oil has become an essential source of energy. 1 Owing to their low porosity, compactness, and no natural productivity, 2 shale reservoirs are developed and increased production using technologies like horizontal wells and multi-stage fracturing. Currently, an oil field in eastern China is vigorously developing shale oil 3 and increasing well productivity through fracturing.…”

Section: Introductionmentioning

confidence: 99%

Theoretical study on the hydraulic sealing integrity of cement sheath in horizontal shale oil wells under fracturing: Crack propagation mode and mechanism

Huang

et al. 2022

Advances in Mechanical Engineering

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The cement sheath-formation interface is a weak link in wellbore isolation systems, which is prone to the failure of sealing integrity during fracturing, affecting the fracturing effect, and wellbore safety. In this study, we establish a new model to evaluate the failure mode and crack propagation of cement sheath-formation interface. Using the proposed model, we predicted the propagation direction and length of the interface and zigzag cracks caused by the interface stress, fracturing load, and stress intensity factor (SIF) under temperature and pressure in the shale oil well X in the eastern China oil field. The prediction results were consistent with the distribution law of measured microseismic events. In addition, we analyzed the influence of the internal casing pressure, mechanical properties of cement sheath, and formation on the sealing integrity failure and cracks. At the same time, we discussed the influence of these mechanical properties on the propagation length of interface and zigzag cracks and the propagation direction of the zigzag crack in detail, and proposed the optimal mechanical properties design to avoid the crack propagating to the cement sheath and causing its failure. The results can provide effective guidance for sealing integrity prediction and cement sheath mechanical performance design.

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Characterizing hydraulic and natural fractures properties in shale oil well in Permian basin using assisted history matching

Cited by 21 publications

References 11 publications

Laboratory Characterization of Shale Oil Storage Behavior: A Comprehensive Review

Laboratory Characterization of Shale Oil Storage Behavior: A Comprehensive Review

Inverse analysis of hydraulic fracturing tests based on artificial intelligence techniques

Theoretical study on the hydraulic sealing integrity of cement sheath in horizontal shale oil wells under fracturing: Crack propagation mode and mechanism

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