Modeling of Hydraulic Fracture Propagation in Shale Gas Reservoirs: A Three-Dimensional, Two-Phase Model

Ahn, Chong Hyun; Dilmore, Robert; Wang, John Yilin

doi:10.1115/1.4033856

Cited by 34 publications

(4 citation statements)

References 43 publications

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“…Consequently, conventional depressurization methods cannot achieve commercial exploitation of shale gas. Nevertheless, massive hydraulic fracturing has become a key technology for commercial exploitation of shale gas [4][5][6], as the horizontal wells associated with massive hydraulic fracturing can connect natural cracks to allow the form of flow channels for shale gas [7][8][9] through the bulk volume of reservoirs near to the wells. Ten thousand cubic meters of water-based fracturing fluid can be injected into shale formations during hydraulic fracturing [10].…”

Section: Introductionmentioning

confidence: 99%

An Optimal Model for Determination Shut-In Time Post-Hydraulic Fracturing of Shale Gas Wells: Model, Validation, and Application

Li,

Tian,

Chen

et al. 2024

Processes

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The global shale gas resources are huge and have good development prospects, but shale is mainly composed of nanoscale pores, which have the characteristics of low porosity and low permeability. Horizontal drilling and volume fracturing techniques have become the effective means for developing the shale reservoirs. However, a large amount of mining data indicate that the fracturing fluid trapped in the reservoir will inevitably cause hydration interaction between water and rock. On the one hand, the intrusion of fracturing fluid into the formation causes cracks to expand, which is conducive to the formation of complex fracture networks; on the other hand, the intrusion of fracturing fluid into the formation causes the volume expansion of clay minerals, resulting in liquid-phase trap damage. At present, the determination of well closure time is mainly based on experience without theoretical guidance. Therefore, how to effectively play the positive role of shale hydration while minimizing its negative effects is the key to optimizing the well closure time after fracturing. This paper first analyzes the shale pore characteristics of organic pores, clay pores, and brittle mineral pores, and the multi-pore self-absorption model of shale is established. Then, combined with the distribution characteristics of shale hydraulic fracturing fluid in the reservoir, the calculation model of backflow rate and shut-in time is established. Finally, the model is validated and applied with an experiment and example well. The research results show that the self-imbibition rate increases with the increase in self-imbibition time, and the flowback rate decreases with the increase in self-imbibition time. The self-imbibition of slick water is the maximum, the self-imbibition of breaking fluid is the minimum, and the self-imbibition of mixed fluid is the middle, and the backflow rates of these three liquids are in reverse order. It is recommended the shut-in time of Longmaxi Formation shale is 17 days according to the hydration and infiltration model.

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Section: Introductionmentioning

confidence: 99%

An Optimal Model for Determination Shut-In Time Post-Hydraulic Fracturing of Shale Gas Wells: Model, Validation, and Application

Li,

Tian,

Chen

et al. 2024

Processes

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“…Many scholars have studied the propagation pattern of an artificial fracture intersecting with a single natural fracture by physical modeling and numerical modeling [5,6]. It is generally believed that there are three situations of the intersection between an artificial fracture and a single natural fracture [7][8][9][10][11]: the artificial fracture intersects with the natural fracture, the natural fracture intercepts, and the artificial fracture is deflected into the natural fracture.…”

Section: Introductionmentioning

confidence: 99%

Numerical Simulation of Artificial Fracture Propagation in Shale Gas Reservoirs Based on FPS-Cohesive Finite Element Method

Liu

Guo

et al. 2019

Geofluids

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The simulation of hydraulic fracturing by the conventional ABAQUS cohesive finite element method requires a preset fracture propagation path, which restricts its application to the hydraulic fracturing simulation of a naturally fractured reservoir under full coupling. Based on the further development of a cohesive finite element, a new dual-attribute element of pore fluid/stress element and cohesive element (PFS-Cohesive) method for a rock matrix is put forward to realize the simulation of an artificial fracture propagating along the arbitrary path. The effect of a single spontaneous fracture, two intersected natural fractures, and multiple intersected spontaneous fractures on the expansion of an artificial fracture is analyzed by this method. Numerical simulation results show that the in situ stress, approaching angle between the artificial fracture and natural fracture, and natural fracture cementation strength have a significant influence on the propagation morphology of the fracture. When two intersected natural fractures exist, the second one will inhibit the propagation of artificial fractures along the small angle of the first natural fractures. Under different in situ stress differences, the length as well as aperture of the hydraulic fracture in a rock matrix increases with the development of cementation superiority of natural fractures. And with the increasing of in situ horizontal stress differences, the length of the artificial fracture in a rock matrix decreases, while the aperture increases. The numerical simulation result of the influence of a single natural fracture on the propagation of an artificial fracture is in agreement with that of the experiment, which proves the accuracy of the PFS-Cohesive FEM for simulating hydraulic fracturing in shale gas reservoirs.

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“…[1][2][3] Shale gas reservoirs are being developed with horizontal wells and multistage hydraulic fracturing. [4][5][6][7] It is generally believed that transient flow lasts a very long time in the plays. However, some well test data from horizontal shale gas wells have been observed in a pseudo-steady flow state after a few years of production.…”

Section: Introductionmentioning

confidence: 99%

“…Unconventional shale gas reservoirs have been important sectors of global resources . Shale gas reservoirs are being developed with horizontal wells and multistage hydraulic fracturing . It is generally believed that transient flow lasts a very long time in the plays.…”

Section: Introductionmentioning

confidence: 99%

Analytical modeling of productivity of multi‐fractured shale gas wells under pseudo‐steady flow conditions

Zhang

Wang

Guo

et al. 2018

Energy Science & Engineering

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Multistage hydraulic fracturing has become a common well completion for horizontal shale gas wells. Some well test data from horizontal shale gas wells have shown pseudo‐steady flow conditions after a period of production. Considering linear flow from reservoir to fracture and linear flow in the fracture, an analytical model is established to calculate the productivity of horizontal shale gas wells under pseudo‐steady flow conditions. The equations in the analytical model are very simple. The production rates calculated by the analytical productivity model are in good agreement with actual gas wells production rates of a well in North American field and 12‐2 well in Fuling shale gas reservoir of China. Sensitivity analysis with the analytical productivity model shows that the different matrix permeability corresponds to the different reasonable fracture conductivity, and the higher the matrix permeability is, the greater the reasonable fracture conductivity. In the process of fracturing for a well, in order to increase production and save fracturing costs, there is no need to generate high‐conductivity fractures, the reasonable fracture conductivity should be determined based on economic evaluations in the real production process. The analytical model provides a practical way to predict production rate for optimization of fracturing design.

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Modeling of Hydraulic Fracture Propagation in Shale Gas Reservoirs: A Three-Dimensional, Two-Phase Model

Cited by 34 publications

References 43 publications

An Optimal Model for Determination Shut-In Time Post-Hydraulic Fracturing of Shale Gas Wells: Model, Validation, and Application

An Optimal Model for Determination Shut-In Time Post-Hydraulic Fracturing of Shale Gas Wells: Model, Validation, and Application

Numerical Simulation of Artificial Fracture Propagation in Shale Gas Reservoirs Based on FPS-Cohesive Finite Element Method

Analytical modeling of productivity of multi‐fractured shale gas wells under pseudo‐steady flow conditions

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