Effect of the variation of phase-transition fracturing fluid thermophysical properties on the wellbore temperature

Zhang, Nanlin; Luo, Zhifeng; Chen, Xiang; Miao, Weijie; Xie, Yang; Cheng, Long; Yu, Jiajie; He, Jie

doi:10.1016/j.geoen.2023.211587

Cited by 4 publications

(1 citation statement)

References 20 publications

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“…In situ-generated proppant fracturing technology (Figure ) was created to solve the issues of equipment wear by proppant, limited migration distance of proppant, and difficulties in supporting narrow fractures in conventional hydraulic fracturing technology. − It utilizes an immiscible two-phase fracturing fluid for work. One phase, known as phase change liquid (PCL), undergoes a phase transition and transforms into solid proppant particles when stimulated by the formation temperature.…”

Section: Introductionmentioning

confidence: 99%

Research on Flow Patterns of Two-Phase Fracturing Fluid in Hydraulic Fracture Considering the Fluid Leak-off

Chen,

Li,

Song

et al. 2024

ACS Omega

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In in situ-generated proppant fracturing technology without proppant injection, the distribution of the flow pattern of two-phase fracturing fluid in the fracture determines the concentration of proppant particles formed by phase change in different positions. Therefore, the study of a two-phase fracturing fluid flow pattern is of great significance to reveal the formation mechanisms of different flow patterns and guide the on-site implementation of the technology. This paper establishes a mathematical model for the two-phase fracturing fluids in fractures based on their physical properties and presents numerical experiments on the flow pattern of two-phase fracturing fluids under different conditions of injection displacement, interfacial tension, and phase change liquid (PCL) ratio. The results show that at lower injection displacements, such as 3 or 4 m 3 /min, it is easier to form striped shape distributions, and at higher injection displacements, such as 5 or 6 m 3 /min, it is easier to form droplet shape distributions. When the interfacial tension is low (15 mN/ m), PCL shrinks less and is distributed in strips; when the interfacial tension is high (25, 35, and 45 mN/m), PCL shrinks more and mainly forms droplet-shaped distributions. PCL tends to form discrete droplet shape distributions at PCL volume fractions of 10, and 20%. At 30% volume fraction, PCL is distributed in strips, and at 40% volume fraction, PCL forms strips of a larger size. These findings reveal the changing pattern of two-phase fracturing fluid flow and enrich the theoretical system of in situ-generated proppant fracturing technology, which can provide theoretical support for the on-site implementation of this technology.

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Section: Introductionmentioning

confidence: 99%

Research on Flow Patterns of Two-Phase Fracturing Fluid in Hydraulic Fracture Considering the Fluid Leak-off

Chen,

Li,

Song

et al. 2024

ACS Omega

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Coupled THMC model-based prediction of hydraulic fracture geometry and size under self-propping phase-transition fracturing

Zhang,

Liu,

Jiang

et al. 2024

Int J Coal Sci Technol

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The Self-Propping Phase-transition Fracturing Technology (SPFT) represents a novel and environmentally friendly approach for a cost-effective and efficient development of the world’s abundant unconventional resources, especially in the context of a carbon-constrained sustainable future. SPFT involves the coupling of Thermal, Hydraulic, Mechanical, and Chemical (THMC) fields, which makes it challenging to understand the mechanism and path of hydraulic fracture propagation. This study addresses these challenges by developing a set of THMC multifield coupling models based on SPFT parameters and the physical/chemical characteristics of the Phase-transition Fracturing Fluid System (PFFS). An algorithm, integrating the Finite Element Method, Discretized Virtual Internal Bonds, and Element Partition Method (FEM-DVIB-EPM), is proposed and validated through a case study. The results demonstrate that the FEM-DVIB-EPM coupling algorithm reduces complexity and enhances solving efficiency. The length of the hydraulic fracture increases with the quantity and displacement of PFFS, and excessive displacement may result in uncontrolled fracture height. Within the parameters considered, a minimal difference in fracture length is observed when the PFFS amount exceeds 130 m3, that means the fracture length tends to stabilize. This study contributes to understanding the hydraulic fracture propagation mechanism induced by SPFT, offering insights for optimizing hydraulic fracturing technology and treatment parameters.

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The experimental study on multiple mechanisms of enhanced CBM recovery by autogenous nitrogen fracturing fluid

Su,

Wang,

Wang

2024

Geoenergy Science and Engineering

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Effect of the variation of phase-transition fracturing fluid thermophysical properties on the wellbore temperature

Cited by 4 publications

References 20 publications

Research on Flow Patterns of Two-Phase Fracturing Fluid in Hydraulic Fracture Considering the Fluid Leak-off

Research on Flow Patterns of Two-Phase Fracturing Fluid in Hydraulic Fracture Considering the Fluid Leak-off

Coupled THMC model-based prediction of hydraulic fracture geometry and size under self-propping phase-transition fracturing

The experimental study on multiple mechanisms of enhanced CBM recovery by autogenous nitrogen fracturing fluid

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