Economic assessment and review of waterless fracturing technologies in shale resource development: A case study

Kohshour, Iman Oraki; Barati, Reza; Yorro, Meaghan Cassey; Leshchyshyn, Tim; Adejumo, Adebola T; Ahmed, Usman; Kugler, Imre; Reynolds, Murray; McAndrew, James

doi:10.1007/s12583-017-0781-1

Cited by 7 publications

(3 citation statements)

References 32 publications

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“…CO 2 fracturing can avoid water sensitivity and water block effects, as it replaces waterbased fracturing fluids with CO 2 [25][26][27]. Therefore, it has been widely applied in shale reservoir development in recent years [28,29].…”

Section: Introductionmentioning

confidence: 99%

Research on Evolutionary Laws of Mechanical Properties and Pore Structure during CO2 Pre-Injection Fracturing in Shale Reservoirs

Tao,

Meng,

et al. 2024

Energies

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CO2 pre-injection fracturing is a promising technology for shale reservoirs development, with multiple advantages for improving the complexity of fractures, the production of crude oil, and the sequestration of CO2. Previous research mostly focused on the CO2 effect on macroscopic mechanical properties of shale. However, there are many phenomena closely related to shale micro mechanical behavior. Therefore, this study presents a systematic investigation into the effects of CO2 on both macro and micro mechanical properties, as well as pore-fracture structures during CO2 pre-injection fracturing in shale reservoirs. The results show that CO2 can significantly decrease the tensile strength, uniaxial compressive strength, and elastic modulus of shale. With the increasing CO2 treatment time, the macro mechanical properties of shale decrease gradually. The microscopic experiments show that this significant decrease may be due to two mechanisms. The first is the significant decrease in the micro-mechanical properties of shale. The results of indentation analysis show that the microscopic elastic modulus and hardness of shale decrease by 51.3% and 63.3% after CO2 treatment. The second is the changes of the original shale framework. Pore-fractures structure analysis showed that after CO2 treatment, a large number of dissolution pores are generated in the shale matrix. Meanwhile, there are propagation of original fractures and opening of structural weak planes, which lead to the form of new fractures. Under the action of these two mechanisms, the macro mechanical strength of shale is reduced significantly. Therefore, in the field application, proper soaking following CO2 injection could lead to a significant overall reduction in mechanical strength, potentially lowering formation breakdown pressure, easing the requirements for treatment equipment, and enhancing fracturing effects.

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Section: Introductionmentioning

confidence: 99%

Research on Evolutionary Laws of Mechanical Properties and Pore Structure during CO2 Pre-Injection Fracturing in Shale Reservoirs

Tao,

Meng,

et al. 2024

Energies

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“…It is difficult to realize gas control due to low permeability and the extraction concentration of gas [3][4][5][6][7], which seriously threatens the safety production of mines. In order to effectively extract the gas in the coal seam, it is necessary to improve the permeability of the coal seam characterized by rich gas and low permeability [8][9][10][11]. As an effective method of improving the permeability of the coal seam, hydraulic fracturing has been applied many mines.…”

Section: Introductionmentioning

confidence: 99%

Experimental Study on Crack Extension Rules of Hydraulic Fracturing Based on Simulated Coal Seam Roof and Floor

et al. 2022

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Hydraulic fracturing can increase the fracture of coal seams, improve the permeability in the coal seam, and reduce the risk of coal and gas outburst. Most of the existing experimental specimens are homogeneous, and the influence of the roof and floor on hydraulic fracture expansion is not considered. Therefore, the hydraulic fracturing test of the simulated combination of the coal seam and the roof and floor under different stress conditions was carried out using the self-developed true triaxial coal mine dynamic disaster large-scale simulation test rig. The results show that (1) under the condition of triaxial unequal pressure, the hydraulic fractures are vertical in the coal seam, and the extension direction of hydraulic fractures in the coal seam will be deflected, with the increase of the ratio of the horizontal maximum principal stress to the horizontal minimum principal stress. The angle between the extension direction of the hydraulic fracture and the horizontal maximum principal stress decreases. (2) Under the condition of triaxial equal confining pressure, the extension of hydraulic fractures in the coal seam are random, and the hydraulic fracture will expand along the dominant fracture surface and form a unilateral expansion fracture when a crack is formed. (3) When the pressure in one direction is unloaded under the condition of the triaxial unequal pressure, the hydraulic fractures in the coal seam will reorientate, and the cracks will expand in the direction of the decreased confining pressure, forming almost mutually perpendicular turning cracks.

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“…The technical and environmental issues associated with the use of water-based fluids for hydraulic fracturing in shale motivated researchers to develop effective waterless fracturing fluid alternatives. − Among the available options are foam-based fluids that have attracted more attention recently. − Foam in porous media is as dispersions of gas in liquid. The liquid phase is continuous, while the continuity of the gas phase is disturbed by the existence of thin liquid films called “lamellae” .…”

Section: Introductionmentioning

confidence: 99%

Synergetic Effect of Surfactant Concentration, Salinity, and Pressure on Adsorbed Methane in Shale at Low Pressure: An Experimental and Modeling Study

et al. 2020

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The influence of an anionic surfactant, a cationic surfactant, and salinity on adsorbed methane (CH 4 ) in shale was assessed and modeled in a series of systematically designed experiments. Two cases were investigated. In case 1, the crushed Marcellus shale samples were allowed to react with anionic sodium dodecyl sulfate (SDS) and brine. In case 2, another set of crushed Marcellus shale samples were treated with cetyltrimethylammonium bromide (CTAB) and brine. The surfactant concentration and salinity of brine were varied following the Box–Behnken experimental design. CH 4 adsorption was then assessed volumetrically in the treated shale at varying pressures (1–50 bar) and a constant temperature of 30 °C using a pressure equilibrium cell. Mathematical analysis of the experimental data yielded two separate models, which expressed the amount of adsorbed CH 4 as a function of SDS/CTAB concentration, salinity, and pressure. In case 1, the highest amount of adsorbed CH 4 was about 1 mmol/g. Such an amount was achieved at 50 bar, provided that the SDS concentration is kept close to its critical micelle concentration (CMC), which is 0.2 wt %, and salinity is in the range of 0.1–20 ppt. However, in case 2, the maximum amount of adsorbed CH 4 was just 0.3 mmol/g. This value was obtained at 50 bar and high salinity (∼75 ppt) when the CTAB concentration was above the CMC (>0.029 wt %). The findings provide researchers with insights that can help in optimizing the ratio of salinity and surfactant concentration used in shale gas fracturing fluid.

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Economic assessment and review of waterless fracturing technologies in shale resource development: A case study

Cited by 7 publications

References 32 publications

Research on Evolutionary Laws of Mechanical Properties and Pore Structure during CO2 Pre-Injection Fracturing in Shale Reservoirs

Research on Evolutionary Laws of Mechanical Properties and Pore Structure during CO2 Pre-Injection Fracturing in Shale Reservoirs

Experimental Study on Crack Extension Rules of Hydraulic Fracturing Based on Simulated Coal Seam Roof and Floor

Synergetic Effect of Surfactant Concentration, Salinity, and Pressure on Adsorbed Methane in Shale at Low Pressure: An Experimental and Modeling Study

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