Study on CO2 foam fracturing model and fracture propagation simulation

Cong, Ziyuan; Li, Yuwei; Pan, Yishan; Liu, Bo; Shi, Ying; Wei, Jiang; Li, Wei

doi:10.1016/j.energy.2021.121778

Cited by 104 publications

(33 citation statements)

References 46 publications

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“…But complex fractures would not surely represent high conductivity. The permeability damage caused by the swelling of clay mineral should also be evaluated, which is one of the critical disadvantages of the application of water based fracturing fluid Cong et al, 2022. Extra permeability tests should be conducted. The ideal water based fracturing fluid should not only create complex fractures, but also keep good fracture conductivity.…”

Section: Discussionmentioning

confidence: 99%

Experimental Investigation on the Crack Evolution of Marine Shale with Different Soaking Fluids

Wang

Zeng

et al. 2021

Front. Earth Sci.

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Hydration induced cracks could promote the complexity of hydraulic fractures in marine shale gas reservoir. But the evolution process and forming mechanism has not been fully investigated. In this paper, Longmaxi marine shale were collected and immersed in three types of fluids (distilled water, fracturing fluid, and mineral oil) for more than 10 days. The spatial-temporal evolution of soaking fractures was recorded and analyzed. A fracture mechanical model was established, considering the effects of in-situ stress, fluid pressure, hydration stress, and capillary force. The promotion mechanism of hydration cracks in forming complex fracking network was discussed. Results showed that hydration fractures were extremely developed and evenly distributed in a state of network for specimens immersed in distilled water. For specimens soaked in fracturing fluid, the hydration cracks were moderately developed for the addition of anti-swelling agent. Fractures were rarely developed for specimens treated in mineral oil. The hydration fractures were mainly formed in the first 5 h and showed strong anisotropy. Cracks parallel to the bedding planes accounted for the vast majority, with a small proportion developed in vertical direction. Theoretical calculations indicated that the stress intensity factor (SIF) caused by hydration stress and capillary force was greater than the measured fracture toughness. The micro crack would probably propagate along bedding planes and grow up into macro horizontal fractures, which promoted the formation of crisscrossing fracture network in shale gas formation.

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Section: Discussionmentioning

confidence: 99%

Experimental Investigation on the Crack Evolution of Marine Shale with Different Soaking Fluids

Wang

Zeng

et al. 2021

Front. Earth Sci.

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“…Due to the low permeability of unconventional reservoirs (Tang et al, 2019;Xie et al, 2020;Shao et al, 2019;Wang et al, 2020), application of hydraulic fracturing technology for unconventional oil and gas production has many problems, such as low flowback and damage to the reservoir, which has been unable to meet the technical requirements of unconventional oil and gas development. CO 2 fracturing is widely recognized by engineers, experts, and scholars because it can achieve several times higher permeability than hydraulic fracturing (Wang et al, 2012;He et al, 2016;Wanniarachchi et al, 2018;Cong et al, 2022), and has little damage to the reservoir and easy flowback during fracturing (Gupta et al, 2005;Wang et al, 2011;Yi et al, 2019). Nowadays, CO 2 fracturing technology is mainly divided into CO 2 foam fracturing, CO 2 dry fracturing, supercritical CO 2 fracturing, CO 2 dry foam fracturing, and the other special CO 2 fracturing (Sun F et al, 2017).…”

Section: Introductionmentioning

confidence: 99%

Flow Simulation and Influence Factors Analysis of CO2 Foam Fracturing in Annulus Injection

Peng

2022

Front. Earth Sci.

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CO2 foam fracturing fluid is widely used in unconventional oil and gas production because of its easy flowback and low damage to the reservoir. Nowadays, the fracturing process of CO2 foam fracturing fluid injected by coiled tubing is widely used. However, the small diameter of coiled tubing will cause a large frictional pressure loss in the process of fluid flow, which is not beneficial to the development of fracturing construction. In this paper, the temperature and pressure calculation model of gas, liquid, and solid three-phase fluid flow in the wellbore under annulus injection is established. The model accuracy is verified by comparing the calculation results with the existing gas, solid, and gas and liquid two-phase model of CO2 fracturing. The calculation case of this paper shows that compared with the tubing injection method, the annulus injection of CO2 foam fracturing fluid reduces the friction by 3.06 MPa, and increases the wellbore pressure and temperature by 3.06 MPa and 5.77°C, respectively. Increasing the injection temperature, proppant volumetric concentration, and foam quality will increase the wellbore fluid temperature and make the CO2 transition to the supercritical state while increasing the mass flow rate will do the opposite. The research results verify the feasibility of the annulus injection of CO2 foam fracturing fluid and provide a reference for the improvement of CO2 foam fracturing technology in the field.

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“…The displacement discontinuity method (DDM) is widely used in dealing with fracture deformation problems for its high computational efficiency (Tang et al, 2018;Tang et al, 2019;Cong et al, 2021a;Cong et al, 2021b;Li et al, 2021). In this paper, we adopt a nonplanar 3D fracture model, based on 3D DDM, to investigate the fracture propagation behavior of zipper fracturing.…”

Section: Introductionmentioning

confidence: 99%

Numerical Analysis of Zipper Fracturing Using a Non-Planar 3D Fracture Model

et al. 2022

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Zipper fracturing has become one of the routine reservoir stimulation methods for developing unconventional resources such as shale oil and gas. A non-planar 3D fracture propagation model is used to study the fracture propagation behavior of zipper fracturing. The effects of stage time lag, staggered perforation cluster spacing, and horizontal principal stress contrast on the fracture geometry are analyzed through numerical simulation. The simulation results show that increasing the stage time lag can increase the fracture length and improve inter-well stimulation. For the formation with higher horizontal principal stress contrast, the staggered perforation cluster spacing has a minimum effect on the fracture configuration of zipper fracturing. For the formation with lower horizontal principal stress contrast, the fractures follow the curved paths and intersect with each other, which potentially has adverse effects on the stimulation of the subsequent stages.

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Study on CO2 foam fracturing model and fracture propagation simulation

Cited by 104 publications

References 46 publications

Experimental Investigation on the Crack Evolution of Marine Shale with Different Soaking Fluids

Experimental Investigation on the Crack Evolution of Marine Shale with Different Soaking Fluids

Flow Simulation and Influence Factors Analysis of CO2 Foam Fracturing in Annulus Injection

Numerical Analysis of Zipper Fracturing Using a Non-Planar 3D Fracture Model

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