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 2 publications

(1 citation statement)

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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%