On the use of espina corona gum as a polymeric additive in water-based drilling fluid

Villada, Yurany Andrea Villada; Taverna, María Eugenia; Maffi, Juan Martín; Giletta, Sebastián; Casís, Natalia; Estenoz, Diana Alejandra

doi:10.1016/j.colsurfa.2022.129601

Cited by 4 publications

(2 citation statements)

References 49 publications

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“…Furthermore, polymers have been examined for their ability to prevent shale swelling and hydration inhibition [ 18 , 19 , 20 ]. 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 ].…”

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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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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“…However, the environmental concerns and disposal of oil-based fluids is the major limitation of using oil-based fluids . Water-based drilling fluids exhibit improved performance and are extensively employed for the drilling of wellbores. , The improved performance of water-based fluids can be achieved with the incorporation of various additives such as viscosity modifiers (polymers), − shale-inhibiting agents (inorganic salts, silicates, surfactants, and ionic liquids), − fluid loss modifiers (polymers and nanoparticles), , and lost circulation materials. , The major complications in the drilling process can be faced due to the instability of the wellbore and formation damage . It happens due to the swelling of wellbore formation when water molecules interact with the sensitive clay in the wellbore .…”

Section: Introductionmentioning

confidence: 99%

Application of Novel Magnetic Surfactant-Based Drilling Fluids for Clay Swelling Inhibition

et al. 2023

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Water-based drilling fluids are widely employed in the oilfield industry for the efficient and smooth drilling of wellbore reservoirs. In this study, a novel drilling formulation was prepared by mixing a magnetic surfactant in the base mud formulation. Several drilling fluid tests were conducted, which include steady shear and dynamic rheology, filtration, clay sedimentation, clay swelling, and particle size distribution analysis. Different analytical techniquesXRD, FTIR, and TGA analyseswere performed to study the interactions of magnetic surfactant with the clay platelets. The experimental results of the surfactant-modified formulations were compared to the base mud formulation. Thermal gravimetric analysis of the surfactant-modified mud showed improved thermal stability compared to the base mud. FTIR analysis results of the base mud and surfactant-modified mud were compared. In the steady shear rheology experiments, the flow curves of the base mud and surfactant-modified mud showed that the addition of surfactant in the base mud affects the shear stress of formulation. The shear stress data of rheology was fitted to the Herschel–Bulkley model, and model parameters trends were assessed with and without the addition of surfactant in the base mud. Shale inhibition tests showed that the incorporation of magnetic surfactant minimized the clay hydration of swelling, thus proving a superior shale inhibitor. The particle size analysis showed that the average particle size of clay particles increased with the increasing concentration of the magnetic surfactant. The linear swelling analysis of clay showed that the rate of swelling was 90% in the surfactant-modified mud as compared to the swelling rate in deionized water. According to the zeta potential, the combination of surfactants significantly affects the electrokinetic behavior of dispersion. Further, the XRD proved that the interlayer spacing of clay increasing while interacting with magnetic surfactant molecules indicates the ability of magnetic surfactant as a shale swelling and hydration inhibitor for water-based drilling formulations.

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Synthesis and properties of poly(acrylamide-co-N-vinylpyrrolidone-co-sodium p-styrene sulfonate) as an anionic fluid loss additive

Bai

et al. 2023

J Polym Res

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On the use of espina corona gum as a polymeric additive in water-based drilling fluid

Cited by 4 publications

References 49 publications

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

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

Application of Novel Magnetic Surfactant-Based Drilling Fluids for Clay Swelling Inhibition

Synthesis and properties of poly(acrylamide-co-N-vinylpyrrolidone-co-sodium p-styrene sulfonate) as an anionic fluid loss additive

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