Feasibility investigation of cryogenic effect from liquid carbon dioxide multi cycle fracturing technology in coalbed methane recovery

Xu, Jizhao; Zhai, Cheng; Liu, Shimin; Qin, Lei; Sun, Yong

doi:10.1016/j.fuel.2017.05.096

Cited by 67 publications

(19 citation statements)

References 37 publications

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“…A temperature gradient is generated inside the coal matrix scaffold, forming thermal stress. During the injection of liquid CO 2 , heat exchange with the coal mass takes place when CO 2 infiltrates the pores and fractures, causing a cryogenic freezing damage effect [22], triggering a shrinkage of the coal matrix scaffold and damaging the structure of the pores and fractures of the coal mass. During the heat exchange between liquid CO 2 and coal, liquid CO 2 undergoes a phase transformation and an increase in both temperature and pressure as the coal matrix swells [23], inducing a compressive or tensile stress in the pore network inside the coal mass, which forces coal pores to restructure and cracks to extend and elongate.…”

Section: The Principle Of Liquid Co 2 Enhancementioning

confidence: 99%

Gas Displacement Engineering Test by Combination of Low and Medium Pressure Injection with Liquid CO2 in High Gas and Low Permeability Coal Seam

et al. 2020

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Mining high-gas coal seams in China has the characteristics mining of deep, high storage and low permeability, and low drainage efficiency, which seriously restrict the efficient prevention and control of mine gas disasters. Based on the characteristics of low viscosity and permeability, phase change pressurization, and strong adsorption potential energy of liquid CO2, the technology system of liquid CO2 displacement for high-gas and low-permeability coal seam was developed, and field industrial of low-pressure (0.5~2.5 MPa) and medium-pressure (2.5~15.0 MPa) combined injection test was carried out. In this test, the mode of injection followed by drainage was adopted, and the gas drainage effect was investigated for 30 days. The test results show that the effective influence radius of CO2 in this test is 20 m, and the liquid seepage radius is 5 to 7 m. After the injection of liquid CO2 into coal seam, the average gas drainage concentration and drainage purity of all drainage holes were increased by 3.2 and 3.4 times, respectively, and the gas promotion effect was significant. Taking the liquid CO2 low-medium-pressure displacement gas test area as the calculation unit, from the comprehensive benefit analysis, compared with the original drainage mode, the liquid CO2-combined pressure injection process can save 34.7% of the engineering cost and shorten the gas drainage standard time by 45.9%. Therefore, the application of this technology has important technical support and reference significance for the efficient management of gas in the same type of mine.

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Section: The Principle Of Liquid Co 2 Enhancementioning

confidence: 99%

Gas Displacement Engineering Test by Combination of Low and Medium Pressure Injection with Liquid CO2 in High Gas and Low Permeability Coal Seam

et al. 2020

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“…Coal is known as its low permeability due to its tight structure (Liu and Harpalani 2013;Zhai et al 2016;Zou et al 2015;Guo et al 2020). Hydraulic fracturing is widely used in the coalbed methane (CBM) extraction (Montgomery and Smith 2010;Cao et al 2017;Xu et al 2017). In hydraulic fracturing operation, the high-pressure proppant-carrying fluid is injected into the coal formation and the proppants are trapped in the CBM fracture system to maintain high permeability pathway after the flowback (Ma et al 2017;Lv et al 2018;Zhai et al 2018;Zhi et al 2018).…”

Section: Introductionmentioning

confidence: 99%

Experimental study on the adverse effect of gel fracturing fluid on gas sorption behavior for Illinois coal

Huang

Liu

et al. 2021

Int J Coal Sci Technol

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Hydraulic fracturing is an effective technology for coal reservoir stimulation. After fracturing operation and flowback, a fraction of fracturing fluid will be essentially remained in the formation which ultimately damages the flowability of the formation. In this study, we quantified the gel-based fracturing fluid induced damages on gas sorption for Illinois coal in US. We conducted the high-pressure methane and CO2 sorption experiments to investigate the sorption damage due to the gel residue. The infrared spectroscopy tests were used to analyze the evolution of the functional group of the coal during fracturing fluid treatment. The results show that there is no significant chemical reaction between the fracturing fluid and coal, and the damage of sorption is attributed to the physical blockage and interactions. As the concentration of fracturing fluid increases, the density of residues on the coal surface increases and the adhesion film becomes progressively denser. The adhesion film on coal can apparently reduce the number of adsorption sites for gas and lead to a decrease of gas sorption capacity. In addition, the gel residue can decrease the interconnectivity of pore structure of coal which can also limit the sorption capacity by isolating the gas from the potential sorption sites. For the low concentration of fracturing fluid, the Langmuir volume was reduced to less than one-half of that of raw coal. After the fracturing fluid invades, the desorption hysteresis of methane and CO2 in coal was found to be amplified. The impact on the methane desorption hysteresis is significantly higher than CO2 does. The reason for the increasing of hysteresis may be that the adsorption swelling caused by the residue adhered on the pore edge, or the pore blockage caused by the residue invasion under high gas pressure. The results of this study quantitatively confirm the fracturing fluid induced gas sorption damage on coal and provide a baseline assessment for coal fracturing fluid formulation and technology.

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“…Hydraulic fracturing is widely used in the coalbed methane (CBM) extraction (Montgomery and Smith 2010;Cao et al 2017;Xu et al 2017). In hydraulic fracturing operation, the high-pressure proppant-carrying fluid is injected into the coal formation and the proppants are trapped in the CBM fracture system to maintain high permeability pathway after the flowback (Ma et al 2017;Lv et al 2018;Zhai et al 2018;Zhi et al 2018).…”

Section: Introductionmentioning

confidence: 99%

Experimental Study on the Adverse Effect of Gel Fracturing Fluid on Gas Sorption Behavior for Illinois Coal

Huang

Liu

et al. 2021

Preprint

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View full text Add to dashboard Cite

Hydraulic fracturing is an effective technology for coal reservoir stimulation. After fracturing operation and flowback, a fraction of fracturing fluid will be essentially remained in the formation which ultimately damages the flowability of the formation. In this study, we quantify the gel-based fracturing fluid induced damages on gas sorption for Illinois coal in US. We conducted the high-pressure methane and CO2 sorption experiments to investigate the sorption damage due to the gel residue. The infrared spectroscopy tests were used to analyze the evolution of the functional group of the coal during fracturing fluid treatment. The results show that no significant chemical alteration of coal due to the fracturing fluid injection, and the damage of sorption is attributed to the physical blockage and interactions. As the concentration of fracturing fluid increases, the density of residues on the coal surface increases and the adhesion film becomes progressively denser. The adhesion film on coal can apparently reduce the number of adsorption sites for gas and lead to a decrease of gas sorption capacity. In addition, the gel residue can decrease the interconnectivity of pore structure of coal which can also limit the sorption capacity by isolating the gas from the potential sorption sites. For the low concentration of fracturing fluid, the Langmuir volume was reduced to less than one-half of that of raw coal. After the fracturing fluid invades, the desorption hysteresis of methane and CO2 in coal was found to be amplified. The impact on the methane desorption hysteresis is significantly higher than CO2 does. The reason for the increasing of hysteresis may be that the adsorption swelling caused by the residue adhered on the pore edge, or the pore blockage caused by the residue invasion under high gas pressure. The results of this study quantitatively confirm the fracturing fluid induced gas sorption damage on coal and provide a baseline assessment for coal fracturing fluid formulation and technology.

show abstract

Feasibility investigation of cryogenic effect from liquid carbon dioxide multi cycle fracturing technology in coalbed methane recovery

Cited by 67 publications

References 37 publications

Gas Displacement Engineering Test by Combination of Low and Medium Pressure Injection with Liquid CO2 in High Gas and Low Permeability Coal Seam

Gas Displacement Engineering Test by Combination of Low and Medium Pressure Injection with Liquid CO2 in High Gas and Low Permeability Coal Seam

Experimental study on the adverse effect of gel fracturing fluid on gas sorption behavior for Illinois coal

Experimental Study on the Adverse Effect of Gel Fracturing Fluid on Gas Sorption Behavior for Illinois Coal

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