Affecting analysis of the rheological characteristic and reservoir damage of CO2 fracturing fluid in low permeability shale reservoir

Li, Qiang; Wang, Fuling; Forson, Kobina; Zhang, Jinyan; Zhang, Chenglin; Chen, Juan; Xu, Nai; Wang, Yanling

doi:10.1007/s11356-021-18169-9

Cited by 23 publications

(9 citation statements)

References 33 publications

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“…In addition, 3 wt % ADP can increase the apparent viscosity of CO 2 from 0.04 to 7 mPa·s, while PDMS can only increase the apparent viscosity of the CO 2 fracturing fluid by 2.96 mPa·s. The apparent viscosity improvement occurred because of the inter-reaction among CO 2 , thickener, and cosolvent (cyclohexane), and the interactions among molecules can form a dense grid structure. , Furthermore, the grid structure could be more dense with increasing the thickener content, and the apparent viscosity increases with the increase of thickener content macroscopically . However, ADP at the same concentration exhibits a more excellent thickening ability compared to PDMS, mainly because CO 2 -philic group of ADP such as ester and carbonyl group could contribute to construct the intermolecular chemical bond, but the construction of chemical bonds was hindered due to the lack of functional groups in PDMS. , …”

Section: Resultsmentioning

confidence: 99%

“…Two reasons can explain the above phenomenon: ① Reservoir pressure reduced the microscopic distance between dissociative molecules, which was instrumental in enhancing the interaction between the thickener and supercritical CO 2 . The dispersed thickeners are soluble in supercritical CO 2 easily due to the enhanced intermolecular forces, which avoided or reduced the sealing of fractures by undissolved thickener . ② The undissolved PDMS sealed in reservoir fractures was also compressed and reduced due to the increase in reservoir pressure; more voids in reservoir fractures alleviate the sealing effect of thickeners, and more fracturing fluid can pass through the fractures more smoothly and enter deeper reservoirs (Figure ).…”

Section: Resultsmentioning

confidence: 99%

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Influence of Supercritical CO₂ Fracturing Fluid on the Permeability of Shale Reservoir and Mechanism Analysis

Guo,

Li,

Zeng

et al. 2024

ACS Omega

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Reduction of the reservoir permeability during supercritical CO 2 fracturing caused significant reservoir damage, which directly affects the crude oil recovery rate. This investigation explored a novel thickener for supercritical CO 2 fracturing fluid, this CO 2 thickener not only effectively improves the viscosity and rheological properties of CO 2 fracturing fluid but also contributes to reduce reservoir damage and improve permeability. The research results indicated that the synthesized CO 2 thickener (3 wt %) can increase the apparent viscosity of supercritical CO 2 fracturing fluid to 7 mPa•s, and a 9% matrix permeability damage rate and a 0.5 mD permeability decrease value are shown in a 3% CO 2 fracturing fluid. However, 3 wt % of commercial CO 2 thickener only increases the apparent viscosity of supercritical CO 2 fracturing fluid to 3 mPa•s, while the reservoir damage rate increases to 13%. Two thickeners exhibit completely different damage capabilities to the reservoir, and the synthesized CO 2 thickener shows excellent characteristics of reducing reservoir permeability and is also conducive to protecting shale reservoirs. Furthermore, supercritical CO 2 fracturing fluid containing synthetic thickeners has better temperature and shear resistance compared with commercial thickeners. This may be because the synthesized thickener and the micro grid formed by supercritical CO 2 reduce the adsorption in shale crevices, but a large amount of commercial thickeners can adsorb on the surface of shale.

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Section: Resultsmentioning

confidence: 99%

Section: Resultsmentioning

confidence: 99%

Influence of Supercritical CO₂ Fracturing Fluid on the Permeability of Shale Reservoir and Mechanism Analysis

Guo,

Li,

Zeng

et al. 2024

ACS Omega

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“…Synthetic and natural polymers were added to the electrolyte as additives to drilling fluids to improve wellbore stability [ 21 , 22 , 23 ]. Despite the polymer providing the needed viscosity required for improving the rheological properties of the drilling fluid, the macromolecular structure of the polymer form multilayers which cannot intercalate in the clay interlayer and, consequently, limit their efficiency as an additive for shale inhibition [ 24 ]. Moreover, the polymers degrade at high temperatures, thereby limiting their properties.…”

Section: Introductionmentioning

confidence: 99%

A Magnetic Surfactant Having One Degree of Unsaturation in the Hydrophobic Tail as a Shale Swelling Inhibitor

et al. 2023

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One of the foremost causes of wellbore instability during drilling operations is shale swelling and hydration induced by the interaction of clay with water-based mud (WBM). Recently, the use of surfactants has received great interest for preventing shale swelling, bit-balling problems, and providing lubricity. Herein, a novel synthesized magnetic surfactant was investigated for its performance as a shale swelling inhibitor in drilling mud. The conventional WBM and magnetic surfactant mixed WBM (MS–WBM) were formulated and characterized using Fourier Transform Infrared (FTIR) and Thermogravimetric analyzer (TGA). Subsequently, the performance of 0.4 wt.% magnetic surfactant as shale swelling and clay hydration inhibitor in drilling mud was investigated by conducting linear swelling and capillary suction timer (CST) tests. Afterward, the rheological and filtration properties of the MS–WBM were measured and compared to conventional WBM. Lastly, the swelling mechanism was investigated by conducting a scanning electron microscope (SEM), zeta potential measurement, and particle size distribution analysis of bentonite-based drilling mud. Experimental results revealed that the addition of 0.4 wt.% magnetic surfactant to WBM caused a significant reduction (30%) in linear swelling. SEM analysis, contact angle measurements, and XRD analysis confirmed that the presence of magnetic surfactant provides long-term swelling inhibition via hydrophobic interaction with the bentonite particles and intercalation into bentonite clay layers. Furthermore, the inhibition effect showed an increase in fluid loss and a decrease in rheological parameters of bentonite mixed mud. Overall, the use of magnetic surfactant exhibits sterling clay swelling inhibition potential and is hereby proffered for use as a drilling fluid additive.

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“…Over the years, numerous studies have been conducted to investigate the impacts of CO 2 on shale. Thickened liquid carbon dioxide fracturing fluid, reflux better, less damage to the reservoir, and low adsorption performance, can more effectively penetrate into the reservoir and thickened liquid carbon dioxide fracturing fluid also prevents leakage of methane in the reservoir 14 , Adsorption of SC-CO 2 in shale specimens caused expansion 15 , which can break cross links between aromatic nuclei in coal 16 and lead to the reduction in permeability 17 . The interaction with SC-CO 2 caused the greater changes in mechanical properties compared with sub-CO 2 18 .…”

Section: Introductionmentioning

confidence: 99%

The permeability of shale exposed to supercritical carbon dioxide

Zhai

Liu

et al. 2023

Sci Rep

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Permeability is a critical parameter of tight reservoir rocks and one of the important parameters for characterizing fluid flow and production from reservoirs. It determines the feasibility of its commercial development. SC-CO2 has been used in shale gas exploitation for efficient fracturing and the added benefit of CO2 geo-storage. And SC-CO2 plays an important role in permeability evolution of shale gas reservoirs. In this paper, Firstly, the permeability characteristics of shale under CO2 injection are discussed. The experimental results show that the relationship between permeability and gas pressure is not a single exponential relationship, but there is an obvious segmentation phenomenon, which is particularly obvious when it is close to the supercritical state, and the overall trend is first decreased and then increased. Subsequently, other specimens were selected for SC-CO2 immersion, and nitrogen was used to calibrate and compare shale permeability before and after treatment to assess changes in shale permeability after SC-CO2 treatment at pressures from 7.5 to 11.5 MPa and X-ray diffraction (XRD) analysis and scanning electron microscopy (SEM) were used to analyze the raw and CO2-treated shale particle sample, respectively. Results indicate the permeability increases significantly after SC-CO2 treated, and permeability growth is a linear function of SC-CO2 pressure. According to (XRD) analysis and (SEM) analysis, SC-CO2 not only can act as a solvent and dissolve carbonate minerals and clay minerals, but also can complex chemical reactions with mineral components in shale, Further dissolution of carbonate minerals and clay minerals, widened gas seepage channels and enhancing the permeability.

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Affecting analysis of the rheological characteristic and reservoir damage of CO2 fracturing fluid in low permeability shale reservoir

Cited by 23 publications

References 33 publications

Influence of Supercritical CO₂ Fracturing Fluid on the Permeability of Shale Reservoir and Mechanism Analysis

Influence of Supercritical CO₂ Fracturing Fluid on the Permeability of Shale Reservoir and Mechanism Analysis

A Magnetic Surfactant Having One Degree of Unsaturation in the Hydrophobic Tail as a Shale Swelling Inhibitor

The permeability of shale exposed to supercritical carbon dioxide

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Affecting analysis of the rheological characteristic and reservoir damage of CO2 fracturing fluid in low permeability shale reservoir

Cited by 23 publications

References 33 publications

Influence of Supercritical CO2 Fracturing Fluid on the Permeability of Shale Reservoir and Mechanism Analysis

Influence of Supercritical CO2 Fracturing Fluid on the Permeability of Shale Reservoir and Mechanism Analysis

A Magnetic Surfactant Having One Degree of Unsaturation in the Hydrophobic Tail as a Shale Swelling Inhibitor

The permeability of shale exposed to supercritical carbon dioxide

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Product

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Influence of Supercritical CO₂ Fracturing Fluid on the Permeability of Shale Reservoir and Mechanism Analysis

Influence of Supercritical CO₂ Fracturing Fluid on the Permeability of Shale Reservoir and Mechanism Analysis