Experimental Study on the Damage of Artificial Fracture Permeability in Coal during the Flow Back of Guar-Based Fracturing Fluid

Liu, Sheng-Gui; Huang, Jinkuang; Tang, Songlei; Shi, Shixiong; Wu, Xuan; Liu, Xin

doi:10.1155/2020/8302310

Cited by 4 publications

(5 citation statements)

References 27 publications

(29 reference statements)

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“…(2) Clay minerals in igneous rock cores produce particle migration. Due to pressure, migrating particles accumulate in the pore throat and produce compaction, resulting in excess pore space and increased porosity Figures and show the core CT scan data obtained from 3, 6, 9, and 12 h of core displacement with 4% KCl solution and gel breaking liquid.…”

Section: Discussionmentioning

confidence: 96%

“…Due to pressure, migrating particles accumulate in the pore throat and produce compaction, resulting in excess pore space and increased porosity. 46 Figures 12 and 13 show the core CT scan data obtained from 3, 6, 9, and 12 h of core displacement with 4% KCl solution and gel breaking liquid. The results show that as the experiment time increases, the internal pores of the igneous rocks gradually increase.…”

Section: Discussionmentioning

confidence: 99%

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Study on the Effect of Fracturing Fluid on the Structure and Mechanical Properties of Igneous Rock

et al. 2022

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Igneous rock oil and gas reservoirs have great development potential. Hydraulic fracturing is an important means for the development of these reservoirs. In the process of fracturing and increasing production, fracturing fluid is prone to a hydration reaction with clay minerals in igneous rock, and then, the structure and mechanical properties of the igneous rock are changed, affecting increased production. Therefore, it is necessary to establish a systematic water–rock reaction experiment method to understand the influence of fracturing fluid on the structure and mechanical properties of igneous rocks and to optimize the fracturing fluid system of igneous rock reservoirs. In this experiment, four solutions were used: slickwater, guar fracturing fluid, 2% KCl aqueous solution, and 4% KCl aqueous solution. Acoustic testing, porosity and permeability testing, XRD analysis, micro-CT scanning, and displacement experiments were performed. The influence of different fracturing fluids on the structure and mechanical properties of igneous rocks was studied. Igneous rock samples with a permeability of 0.05–0.1 mD and average porosity of 7–14% were used. The results show that all four liquid systems will reduce the permeability, Young’s modulus, and brittleness index and increase the porosity and Poisson’s ratio of the rock after fracturing. Among them, the permeability damage rate is as high as 37.37%, which may be related to the plugging of pores with solid residues in the gel breaking liquid; CT results show that there are microcracks in the rock, which increase over time, up to 13.54%. The brittleness index decreases. Among the fluids, the influence of slickwater on the rock brittleness index is the smallest, no more than 5%. Guar gum had the greatest effect on the Gel breaking liquid, up to 58%. One of the reasons for the increase in porosity is that adding a clay stabilizer composed of inorganic salts and organic cationic polymers to the slickwater fracturing fluid can effectively reduce the damage caused by the fracturing fluid to the rock during the fracturing process and can reduce the maximum by 50%. This paper can clarify the damage law of fracturing fluid systems to igneous rock reservoirs and provide the theoretical basis for the hydraulic fracturing of igneous rock reservoirs.

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Section: Discussionmentioning

confidence: 96%

Section: Discussionmentioning

confidence: 99%

Study on the Effect of Fracturing Fluid on the Structure and Mechanical Properties of Igneous Rock

et al. 2022

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“…The reduction of permeability by an undisturbed gel based on guar can reach 85%. Depending on the permeability of the collector, the quality of the colmatant can be affected by the types of salts present in the formation water and dissolved gases (hydrogen sulfide, for example) [ 45 , 46 ]. According to the researchers, a strong adsorption of polymer molecules also contributes to a decrease in permeability.…”

Section: Hydraulic Fracturing Gelsmentioning

confidence: 99%

Application of Hydrogels and Hydrocarbon-Based Gels in Oil Production Processes and Well Drilling

Telin,

Lenchenkova,

Yakubov

et al. 2023

Gels

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The use of gels in oil production processes has become a regular practice in oilfield operations and is constantly developing in all oil-producing countries of the world, as evidenced by the growth of publications and patent activity on this topic. Many oil production processes, such as hydraulic fracturing, conformance control, water, and gas shutoff, cannot be imagined without the use of gel technologies. Inorganic, organic, and hybrid gels are used, as well as foams, gel-forming, and gel-dispersed systems. The possibility of a broad control of structural and mechanical properties, thermal stability, and shear resistance by introducing microscale and nanoscale additives made hydrogels and hydrocarbon-based gels indispensable tools for oil engineers.

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“…The first generation of foam fracturing fluids primarily consisted of water, brine, acid, alcohol, and crude oil as base fluids, and were prepared by mixing nitrogen and foaming agents with the base fluids. These fluids feature low filtration loss, strong sand carrying capacity, and fast flowback, but have low viscosity and short foam lifetime, making them only suitable for shallow wells and small-scale fracturing construction (Liu et al, 2020). The second generation of foam fracturing fluid is formed by adding linear glue, a foam stabilizer, to the first generation.…”

Section: Introductionmentioning

confidence: 99%

Research and performance optimization of carbon dioxide foam fracturing fluid suitable for shale reservoir

Li¹,

Fan²,

He³

et al. 2023

Front. Energy Res.

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Compared to conventional fracturing techniques, foam fracturing has numerous advantages, including good shear resistance, strong sand carrying capacity, low fluid loss, low damage, and fast return rates. It is particularly suitable for stimulation in low pressure, low permeability, and water-sensitive formations. Specifically, CO2 foam fracturing is crucial in energy savings and emission reductions, controlling the expansion of reservoir clay minerals, reducing crude oil viscosity, and improving the production of water-locked reservoirs. In this paper, we investigate the foam fracturing fluid and evaluate its performance. We selected thickeners with good foaming stability and foaming agents with excellent performance at low dosage levels, based on experimental evaluation. We finally determined the formulation of the foam fracturing fluid by analyzing the experimental data, such as foam half-life, foam mass, and viscosity. We experimentally evaluated the viscosity, static sand settling properties, and rheological properties of the fluid. After being tested on the reservoir core, the foam fracturing fluid has a viscosity of 2 mPas. Moreover, the residue content is 1.1 mg/L, the surface tension is 24.5 mN/m, and the interfacial tension is 1.5 mN/m. The fluid-carrying sand experiment of 40–70 mesh ceramic particles, commonly used in shale gas fracking, was evaluated. The sand-to-liquid ratio was set at 40% for the static sand-carrying experiment. The flow of the fluid-carrying sand was good, and the settling property was satisfactory for 3 h. We used shale reservoir cores from well W-1 to assess the rate of foam fracture, which was less than 19%. Under the experimental conditions of a shear rate of 170 S−1 and a temperature of 90°C, the viscosity of fracturing fluid was measured to be greater than 50 mPas, 90 min after shear, demonstrating the excellent temperature and shear resistance of the foam fracturing fluid. Using CO2 foam fracturing fluid can significantly improve the reconstruction effect of low permeability hydrocarbon reservoirs (especially unconventional reservoirs) and solve problems related to water resources and environmental protection during the process of oil and gas reservoir development. It will be a major factor in improving construction impacts and addressing water and environmental concerns for low permeability hydrocarbon reservoirs, particularly unconventional ones that utilize CO2 foam fracturing fluids.

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Experimental Study on the Damage of Artificial Fracture Permeability in Coal during the Flow Back of Guar-Based Fracturing Fluid

Cited by 4 publications

References 27 publications

Study on the Effect of Fracturing Fluid on the Structure and Mechanical Properties of Igneous Rock

Study on the Effect of Fracturing Fluid on the Structure and Mechanical Properties of Igneous Rock

Application of Hydrogels and Hydrocarbon-Based Gels in Oil Production Processes and Well Drilling

Research and performance optimization of carbon dioxide foam fracturing fluid suitable for shale reservoir

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