Experimental Study of Hydraulic Fracturing for Unconsolidated Reservoirs

Yan, Chuanliang; Chen, Yong; Chen, Tianqing; Cheng, Yuanfang; Yan, Xiangqiao

doi:10.1007/s00603-022-02827-6

Cited by 16 publications

(9 citation statements)

References 30 publications

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“…The proposed technology not only provides a cost-effective approach but also allows for the redevelopment of old and decommissioned deposits with a depletion rate of 30-40%. When combining radial drilling with hydraulic fracturing in low-permeability deposits, there is a potential to significantly increase the volume of extractable resources from the reservoir layer [7]. Particularly in favorable lithological conditions, radially reaming the production seam up to 200 m from the main well enables the inflow of reservoir fluid that was previously inaccessible due to insufficient reservoir energy.…”

Section: Development Of the Radial Drilling Technologymentioning

confidence: 99%

“…The unique characteristics of this technology, specifically, the capability to achieve an exceptionally short radius of curvature, of approximately 30 cm, and the remarkable increase in the angle of curvature of the hole (100-250 • /30 m), have led to the classification term URRS (Ultrashort-Radius Radial System) [3][4][5]. Radial drilling finds application in both existing and new production as well as exploration wells [1,6,7]. In this context, "radial drilling" does not solely refer to a small radius of curvature but emphasizes the ability to drill in various directions at the same level.…”

Section: Introductionmentioning

confidence: 99%

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Enhancing Deposit Exploitation Efficiency Utilizing Small-Diameter Radial Boreholes via Hydraulic Drilling Nozzles for Optimal Resource Recovery

Toczek,

Wisniowski

2024

Applied Sciences

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The exploration and development of new hydrocarbon deposits is facing increasing challenges as the global shift to renewable energy sources, such as shallow geothermal deposits, wind farms, and photovoltaics, reduces the dependence on hydrocarbons. To navigate this evolving landscape, it becomes crucial to find solutions that optimize the energy extraction efficiency while maximizing the use of hydrocarbon deposits. This requires exploring opportunities in existing fields and wells, including those slated for decommissioning. This article discusses the potential for extracting resources from seemingly depleted fields, where some 60–70% of the resources remain unrecoverable due to low reservoir energy. Meeting this challenge requires the implementation of secondary and tertiary EOR methods that involve the introduction of external energy to increase reservoir pressure and enhance resource recovery. One of the proposed innovative tertiary methods involves reaming the reservoir using multiple small-diameter radial boreholes generated by a hydraulic drilling nozzle. This strategy is designed to intensify the contact between the production hole and the reservoir layer, resulting in increased or commenced production in certain cases. The described method proves to be a practical application in hydrocarbon deposits, offering the dual benefits of mitigating environmental pollution by eliminating the need for drilling new boreholes and providing a cost-effective means of accessing resources in decommissioned deposits with insufficient reservoir energy for self-exploitation. Another article points out the design variation of a hydraulic drilling nozzle tailored specifically for reaming a reservoir layer. Taking the above into account, this article provides very practical information for future projects in which paths should be sought for the design and development of hydraulic wellheads, among other things, in order to intensify the production from hydrocarbon deposits.

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Section: Development Of the Radial Drilling Technologymentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Enhancing Deposit Exploitation Efficiency Utilizing Small-Diameter Radial Boreholes via Hydraulic Drilling Nozzles for Optimal Resource Recovery

Toczek,

Wisniowski

2024

Applied Sciences

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“…As the burial depth increases in deep reservoirs, there is a corresponding increase in the ground pressure. The rocks in these reservoirs primarily exhibit a strengthening of elastic modulus and compressive strength, while brittleness is weakened. , These changes in physical parameters and mechanical properties of deep shale, compared to shallow shale reservoirs, can result in variations in the propagation of hydraulic fractures and communication behavior with the bedding plane. − These variations have a significant impact on the effectiveness of fracturing.…”

Section: Introductionmentioning

confidence: 99%

Influence of Engineering Parameters on Fracture Vertical Propagation in Deep Shale Reservoir: A Numerical Study Based on FEM

Zhang,

Liao,

et al. 2024

ACS Omega

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The geometry of hydraulic fractures in deep shale facies is significantly affected by the longitudinal inhomogeneity of rock physical properties and stresses. Numerous studies have been conducted on the influence of the longitudinal inhomogeneity of rocks on fracture morphology. However, there is still a lack of research that simultaneously considers the reservoir dip, bedding plane interface, and longitudinal inhomogeneity of the reservoir. To fill this gap, a three-dimensional (3D) numerical model of multireservoir hydraulic fracturing, which takes into account the bedding plane interface, was developed using the finite element method (FEM). The Drucker−Prager elastic-plasticity criterion was incorporated to accurately represent the plasticity of deep shale. The research revealed the influence of the formation dip angle on fracture morphology. Additionally, the perforation layer position and pump rate were optimized based on the actual geological parameters in North Jiangsu shale reservoir. The study findings indicate that reservoir fractures with a formation dip are easily detected by the interface. However, it is not necessarily true that the larger the formation dip, the easier it is for fluids to enter the interface. Fracturing from high-strength and stress reservoirs to lower reservoirs promotes the propagation of fracture height and the connectivity of multiple reservoirs. On the other hand, fractures initiated from low-strength and stress reservoirs tend to be confined to adjacent reservoirs more easily. The pump rate significantly affects the vertical propagation of fractures. At high interface strength, fractures with pump rate below 2.4 m 3 /min can only propagate at the perforation layer. The limited fracture height in shale reservoirs is likely due to substantial energy consumption by the fracturing fluid at the bedding plane interface. These studies offer theoretical guidance for understanding the vertical propagation of fractures in a deep multilayer reservoir.

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“…Industrial oil and gas flow can hardly be obtained from shale reservoir with extremely low porosity and permeability in natural state. − Horizontal drilling and multistage fracturing technology have realized large-scale commercial exploitation of shale oil and gas, which is changing the world energy pattern. − As shown in the Figure , the shale reservoir after fracturing becomes a multiscale complex fracture network structure composed of a matrix, natural microfractures, and hydraulic fractures; the gas flow characteristics in the pore and fracture structures of different scales are quite different. − The Knudsen number K n can be used to divide the gas flow regime based on the pore and fracture size. When K n > 0.2, the flow regime is dominated by the diffusion effect; when K n < 0.01, the flow is dominated by seepage; and when 0.001 < K n < 0.2, the gas flow is in the form of coexistence of multiple flow patterns mainly including slip flow, surface diffusion, Fick diffusion, and Knudsen diffusion. − Shale gas is stored in various states in a shale reservoir, mainly including free gas, adsorbed gas, and dissolved gas; the gas mass transfer is the common result of the above multiple flow regimes.…”

Section: Introductionmentioning

confidence: 99%

Study on Multiscale Fluid–Solid Coupling Theoretical Model and Productivity Analysis of Horizontal Well in Shale Gas Reservoirs

et al. 2023

Self Cite

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In order to study the productivity dynamic evolution laws of shale gas horizontal well, a multiscale seepage theoretical model considering the fluid–solid coupling effect is proposed first in this paper, which introduces an anisotropic matrix permeability model that comprehensively considers multiple flow regimes and an artificial hydraulic fracture conductivity model that considers proppant deformation and embedment. Then the reliability of the theoretical model is verified by the field production data obtained from the Marcellus shale. Based on the established productivity model, the evolution laws of pore pressure and permeability in different areas of the reservoir with different production periods are studied first, and then the shale gas production rate and cumulative production under different physical mechanisms, different shale gas flow regimes, and different reservoir parameters are quantified and analyzed. The simulation results show that the pore pressure in the hydraulic fracture area decreases rapidly at the initial stage of production, resulting in large deformation, and the fracture conductivity tends to be stable gradually at the later stage of production. The desorption effect will increase shale gas production, while the stress sensitivity is just the opposite. When only real gas flow is considered, the gas cumulative production is the highest. The fluid–solid coupling of hydraulic fractures has a great impact on the production, while the fluid–solid coupling in the matrix area has a small impact on the production, which can be ignored if appropriate. During the sensitivity analysis of reservoir parameters, it is observed that the influence of parameters of hydraulic fractures on production is much higher than that of matrix regional parameters. During the production process, these influencing factors can be adjusted according to the change of production data to achieve the optimization of shale gas production. In a word, the new model proposed in this paper provides a more accurate method to estimate the impact of multiple physical mechanisms, especially the fluid–solid coupling effect, on shale gas production compared with the existing model. The research results of this study can provide some reference and guidance for the dynamic prediction of shale gas production and optimization of production parameters.

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Experimental Study of Hydraulic Fracturing for Unconsolidated Reservoirs

Cited by 16 publications

References 30 publications

Enhancing Deposit Exploitation Efficiency Utilizing Small-Diameter Radial Boreholes via Hydraulic Drilling Nozzles for Optimal Resource Recovery

Enhancing Deposit Exploitation Efficiency Utilizing Small-Diameter Radial Boreholes via Hydraulic Drilling Nozzles for Optimal Resource Recovery

Influence of Engineering Parameters on Fracture Vertical Propagation in Deep Shale Reservoir: A Numerical Study Based on FEM

Study on Multiscale Fluid–Solid Coupling Theoretical Model and Productivity Analysis of Horizontal Well in Shale Gas Reservoirs

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