The Simulation Study of Fracture Vertical Propagation in 3D Model

Fu, Haifeng; Liang, Tiancheng; Qiu, Jinping; Chen, Bo; Yuzhong, Yan; Nailing, Xiu; Liu, Yunzhi; Meng, Cai

doi:10.1007/978-981-15-2485-1_236

Cited by 2 publications

(2 citation statements)

References 4 publications

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“…The extension of fracture height is also affected by the change in the minimum horizontal principal stress of the formation near the target layer. If the net pressure value in a fracture exceeds the minimum horizontal principal stress of the adjacent formation, the fracture will propagate through the layer; otherwise, the layer will act as a barrier [16,17]. Overall, China's low-permeability bottom-water reservoirs have significant potential, and with the application of volume fracturing and the improvement of production techniques, oil and gas production in these reservoirs can be greatly enhanced.…”

Section: Introductionmentioning

confidence: 99%

Simulation and Control Strategies for Longitudinal Propagation of Acid Fracture in a Low-Permeability Reservoir Containing Bottom Water

Li,

Fan,

Guo

et al. 2024

Processes

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The reservoir in the Anyue gas field, located in the Sichuan basin of China, belongs to the second member of the Dengying formation and has distinctive geological features. It is characterized by strong heterogeneity, low porosity, low permeability, and locally developed natural fractures. The reservoir space consists primarily of corrosion holes, natural fractures, and similar voids. Moreover, the lower reservoir exhibits high water saturation and a homogeneous bottom-water interface. Since it is a carbonate-based hydrocarbon reservoir with low porosity and permeability, deep acid fracturing has proven to be an efficient method for enhancing individual well production. However, the reconstruction of the second member of the Dengying formation reservoir poses significant challenges. The reservoir contains high-angle natural fractures, small vertical stress differences, and is located in close proximity to the gas–water interface. As a result, it becomes difficult to control the height of the acid break. Improper acid break treatment may easily result in water production affecting gas well production. To explore ways to control the longitudinal extension of acid fractures, 3D numerical models focusing on the initiation and expansion of acid fractures have been developed. This model takes into account geological and engineering factors such as stress differences, acid fracture displacements and scales, and their effects on the longitudinal extension of acid fractures. It was revealed that the pressure difference is the main controlling factor for the acid fracture height, followed by the reservoir thickness, the interlayer thickness, and the viscosity of the working fluid. Technical countermeasures for controlled fracture and high-acid fracturing tailored to different reservoir characteristics have been proposed, and design parameters for controlled fracture and high-acid fracturing can be optimized. By effectively controlling the vertical extension of the acid fracture, it is possible to maximize production from a single well while avoiding interference from the lower water layer. This study provides theoretical guidance for the application of deep-acid-fracturing techniques in low-permeability bottom-water gas reservoirs.

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Section: Introductionmentioning

confidence: 99%

Simulation and Control Strategies for Longitudinal Propagation of Acid Fracture in a Low-Permeability Reservoir Containing Bottom Water

Li,

Fan,

Guo

et al. 2024

Processes

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“…To date, numerous researchers have performed true triaxial experiments on outcrops to investigate the behavior of hydraulic fracture propagation. Some studies [3][4][5][6][7][8][9][10] utilized outcrops consisting of sandstone and sand-coal inter-beds. The findings indicate that when the fracture propagation reaches the interface, the fracture either ceases growth, changes its propagation direction, bifurcates into multiple directions, or continues to propagate along the original path and penetrates the bedding interface.…”

Section: Introductionmentioning

confidence: 99%

Impact of Formation Dip Angle and Wellbore Azimuth on Fracture Propagation for Shale Reservoir

Yang

Wang

Ge³

et al. 2023

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The significant vertical heterogeneity, variations in ground stress directions, and irregular bedding interfaces make it extremely challenging to predict fracture propagation in continental shale reservoirs. In this article, we conducted a series of triaxial laboratory experiments on continental shale outcrop rocks to investigate the effects of formation dip angle and wellbore orientation on crack propagation under horizontal well conditions. Our study revealed that fracture propagation features can be categorized into four distinct types: (1) hydraulic fractures pass through the bedding interface without activating it; (2) fractures pass through and activate the bedding interface; (3) hydraulic fractures open and penetrate the bedding interface while also generating secondary fractures; and (4) hydraulic fractures open but do not penetrate the bedding interface. We found that as the dip angle decreases, the likelihood of fractures penetrating through the bedding interface increases. Conversely, as the dip angle increases, fractures are more likely to simply open the interface without penetrating it. Moreover, we observed that the well azimuth significantly affects the degree of fracture distortion. Specifically, higher azimuth angles corresponded to a higher degree of fracture distortion.

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The Simulation Study of Fracture Vertical Propagation in 3D Model

Cited by 2 publications

References 4 publications

Simulation and Control Strategies for Longitudinal Propagation of Acid Fracture in a Low-Permeability Reservoir Containing Bottom Water

Simulation and Control Strategies for Longitudinal Propagation of Acid Fracture in a Low-Permeability Reservoir Containing Bottom Water

Impact of Formation Dip Angle and Wellbore Azimuth on Fracture Propagation for Shale Reservoir

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