Effect of the phase-transition fluid reaction heat on wellbore temperature in self-propping phase-transition fracturing technology

Zhang, Nanlin; Chen, Zhangxin; Luo, Zhifeng; Liu, Pingli; Chen, Wei-Yu; Liu, Fushen

doi:10.1016/j.energy.2022.126136

Cited by 10 publications

(3 citation statements)

References 24 publications

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“…One phase, known as phase change liquid (PCL), undergoes a phase transition and transforms into solid proppant particles when stimulated by the formation temperature. The other phase (NPCL, nonphase change liquid) occupies part of the fracture space, and the space liberated by its backflow functions as an oil and gas high-conductivity flow channel. , Due to the different physical properties, such as density and viscosity, of PCL and NPCL, as well as the existence of interfacial tension between the two immiscible fluids, they will flow in fractures in different ways. The distribution of the flow pattern is determined by the concentration of proppant particles at different positions in the fracture after the phase transition, which affects the support effect and conductivity.…”

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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“…Current temperature-responsive materials used as a fracturing fluid in self-generated proppants fracturing technology include unsaturated polyester, phenolic resin, urea–formaldehyde resin, and epoxy resin. Epoxy resin has become the first choice for self-generated proppant fracturing fluids due to its excellent physical and chemical properties, such as low volume shrinkage of cured product, no byproduct produce, good heat resistance of the cured product, simple synthesis process, and so on. − At present, research studies of a self-generated proppant fracturing fluid mainly focuses on two parts: liquid and solidified product. The research on liquid mainly includes rheology, filtration, compatibility, damage, and friction .…”

Section: Introductionmentioning

confidence: 99%

Liquid–Solid Phase-Change Autogenous Proppant Fracturing Fluid─Phase-Change Behavior Research and Field Application

Chen,

Sang,

Guo

et al. 2023

Energy Fuels

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Hydraulic fracturing is an important technology for the stimulation of oil and gas reservoirs. In recent years, a new technology called self-generated proppant fracturing that abandons the traditional "sand-carrying" mode has become a research hot spot. This technology can solve many deficiencies and limitations of a conventional fracturing technology, so it has been widely studied by scholars at home and abroad. This article studies the phase-change behavior of the self-generated proppant fracturing fluid system for this new technology, specifically analyzing the effects of temperature, time, and accelerants on the phase-change behavior and conducting on-site applications. The research shows that (1) the phase-change behavior can be divided into three parts: initiation of phase-change, solid production, and pressure-resistant solid formation. Tertiary amines were selected as the best accelerant for the new fracturing fluid system to control the time and temperature of phase-change. (2) The accelerant can reduce the phasechange temperature with a non-linear trend. (3) When the temperature is below 40 °C, the dosage of the accelerant is more than 0.6%; when the temperature is in the range of 40−60 °C, the dosage of the accelerant is about 0.4−0.6%; when the temperature is higher than 80 °C, the accelerant dosage design should be less than 0.2%. (4) Through on-site application, it has been confirmed that the new fracturing fluid system is feasible for normal construction under the existing construction conditions and effective for reservoir transformation. Under the same renovation scale, interval, and production system, the daily gas production of the well (2.23 × 10 4 m 3 /d) which used the new fluid system is higher than the adjacent wells (1.68 × 10 4 m 3 /d) according to production data.

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“…Jianye Mou et al [16] designed a multistage triaxial fracturing system and experimental procedures to satisfy the requirements of diverted fracturing in horizontal wells. Nanlin Zhang et al [17] proposed self-supporting fracturing technology, established a transient temperature model considering reaction heat based on the first law of thermodynamics, and clarified the impact of phase change reaction heat on wellbore temperature. Nanlin Zhang et al [18] used Permian cores from Sichuan Basin to evaluate fracture conductivity under different conditions, such as proppant size and concentration, acid concentration and activity, and the separate or combined application of acid and proppant.…”

mentioning

confidence: 99%

Study and application of temporary plugging agent for temporary plugging acid fracturing in ultra-deep wells of Penglai gas field

Wang¹,

Fan²

2023

Front. Phys.

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The burial depth of Penglai gas field reservoir in the Sichuan Basin of China exceeds 7,000 m, and the reservoir temperature is 160°C. Penglai gas field belongs to the fractured reservoir, and there are many natural fractures distributed in the reservoir. Natural fractures are not only the storage place of natural gas, but also the transportation channel of natural gas. Gas wells mainly increase natural gas production through acid fracturing. In the early stage, Penglai Gas Field mainly used gelled acid fracturing technology to create an artificial fracture in the reservoir by injecting a large amount of acid fluid. However, the stimulation range of gelled acid fracturing is very small. After acid fracturing, gas wells can only produce 120,000 cubic meters of natural gas per day. To obtain higher natural gas production, this paper proposes a multi-stage temporary acid fracturing technology that can greatly improve the effect of acid fracturing. The temporary plugging agent for acid fracturing has been developed to meet the high-temperature requirements of the Penglai gas field. Based on the simulation of fracture propagation, the feasibility of acid fracturing expansion of natural fractures in the Penglai Gas Field is clarified. Fiber and granular temporary plugging agents that meet the plugging strength greater than 20 MPa are selected by using the dynamic temporary plugging instrument. MultiFracS software is used to optimize the multi-stage temporary acid fracturing process parameters. The research results in this paper have been applied to wells PS101, PS102, and PS103. After fracturing, compared with the gelling acid fracturing, the natural gas production has increased by more than three times, and the multi-stage temporary plugging acid fracturing has achieved a very good stimulation effect.

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Effect of the phase-transition fluid reaction heat on wellbore temperature in self-propping phase-transition fracturing technology

Cited by 10 publications

References 24 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

Liquid–Solid Phase-Change Autogenous Proppant Fracturing Fluid─Phase-Change Behavior Research and Field Application

Study and application of temporary plugging agent for temporary plugging acid fracturing in ultra-deep wells of Penglai gas field

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