Synthesis of hollow spherical tin phosphides (Sn4P3) and their high adsorptive and electrochemical performance

Polymer nanocomposite ADA@SM as a high-temperature filtrate reducer for water-based drilling fluids and its filtration loss mechanism

Synthesis and characterization of high NIR reflecting eco-friendly BaMoO4 pigments in scheelite family

EDTA-assisted fabrication of TiO2 core–shell microspheres with improved photocatalytic performance

Controllable route to barium molybdate crystal and their photoluminescence

The rheological and filtration performance of drilling fluids greatly depends on the additives used. To address the negative impact on the drilling fluid performance stemming from electrolyte contamination, a sustainable sodium alginate (SA) biopolymer was employed as an additive in water-based drilling fluids to overcome the performance deterioration caused by the polyelectrolyte effect under salt contamination. The results demonstrated that SA performs better than sodium carboxymethyl cellulose (Na-CMC) and polyanionic cellulose (PAC-LV), the widely used drilling fluid additives. Although exposed to highly concentrated salt contamination, the addition of SA can mitigate viscosity variation and maintain a lower filtration volume of a base fluid (BF), whereas an advanced variation in CMC/BF and PAC/BF was observed. The possible rheology and filtration mechanism of SA under highly concentrated salt contamination were investigated through zeta potential, particle size distribution, and scanning electron microscopy (SEM). The results revealed that the anchoring groups on the SA molecular chain enable them to strongly adsorb on the negatively charged bentonite surface via hydrogen and ionic bond interactions, leading to a significant improvement in both rheological and filtration performance. Therefore, SA with excellent salt tolerance and sustainability confers practical applicability that could extend to the preparation of saltwater-based and other inhibitive drilling fluids.

/pdf/sodium-alginate-as-an-eco-friendly-rheology-modifier-and-1zk7jmu7.pdf

Sodium alginate as an eco-friendly rheology modifier and salt-tolerant fluid loss additive in water-based drilling fluids

One-step fabrication of BaMoO4 microstructures with controlled morphologies via a simple EDTA-mediated route

Wettability alteration of the shale surface is a potential strategy to address wellbore instability issues arising from shale hydration. In this study, we have explored an oil-in-water (o/w) nanoemulsion, in which soluble silicate (lithium silicate and potassium methyl silicate) as the aqueous phase and organosilanes (3-methacryloxypropyltrimethoxysilane (KH570) and n-octyltriethoxysilane (n-OTES)) as the oil phase, as a shale inhibitor via forming a hydrophobic "artificial borehole shield" in situ on shale surfaces to maintain wellbore stability in high-temperature drilling operations. The shale dispersion test showed the highest shale recovery of nanoemulsion was up to 106.4% compared to that of water (20%), and recovered shale cuttings remained at the original integrity after hot rolling at 180 °C, indicating superior inhibition performance and resistance to elevated temperatures. Moreover, recovered shale cuttings manifested water repellency upon reimmersion in water, ascribed to the hydrophobic film, preventing water from permeating into the shale. The results of the contact angle measurement elucidated that the film wettability, from hydrophilic to superhydrophobic (ranging from 9.6-154°), can be achieved by altering the n-OTES-to-KH570 weight ratio from 0.2 to 2.25, and the film with the highest hydrophobicity (154°) and the lowest surface energy (3.17 mJ·m-2) can be obtained at a ratio of 1.3. Scanning electron microscopy images demonstrated that the superhydrophobic film was composed of tightly stacked reticulate nanofilaments with a diameter of 7-17 nm and several micrometers in length and overlapped well-distributed nanospheres with a diameter of 30 nm. X-ray diffraction and Fourier transform infrared spectroscopy confirmed the film was crystalline silica grafted with long-chain alkylsiloxane. It is assumed that the unique micronanostructure combined with the siloxane modification contributed to the hydrophobicity. Consequently, this study provides a potential alternative solution for wellbore stabilization in deep well drilling engineering by employing nanoemulsion as a shale hydration inhibitor via forming a protective film with controllable wettability. Furthermore, it can be conferred a practical application due to easily available, less hazardous, and cost-effective materials.

In Situ Shale Wettability Regulation Using Sophisticated Nanoemulsion to Maintain Wellbore Stability in Deep Well Drilling.

High performance hydration inhibitors are recognized as an attractive solution to address wellbore instability associated with water-based drilling fluids. Nevertheless, conventional inhibitors still face a dilemma regarding the balance between inhibition performance and compatibility, including rheological and filtration properties. Herein, we proposed an organic–inorganic composite inhibitor that combines polymer adsorption and ion intercalation to provide synergistic inhibition properties. The results demonstrated that the composite inhibitors reduced the clay swelling rate from 50.7 to 22.4 % and increased shale recovery from 71.4 to 90.2 % compared with that in K2SiO3 solution, revealing the synergistic inhibition properties between ion exchange and film coating effect. In addition, the hydrogen bonding interaction between potassium alginate (PA) and clay particles effectively alleviates performance deterioration of base fluids containing K2SiO3, as evidenced by the apparent viscosity increased from 14.0 to 35.5 mPa·s, plastic viscosity increased from 4.0 to 25.0 mPa·s and filtration loss reduced from 35.2 to 20.4 mL after rolling at 120 °C. The intermolecular interaction between clay and PA facilitates the adsorption of polysaccharide chains onto clay surface, which was confirmed by scanning electron microscopy (SEM) and Fourier-transform infrared spectroscopy (FTIR). Moreover, X-ray diffraction (XRD), zeta potential and particle size distribution verified the suppression of electric double layers caused by K+ ions intercalation. This study validates the feasibility of organic–inorganic hybrid materials as shale hydration inhibitors, utilizing the synergistic effects of polymer adsorption and cation intercalation. Furthermore, the study highlights the great potential of combining PA with silicates to maintain wellbore stability. 

Synergistic effects of potassium alginate and silicates co-inhibition performance in shale hydration

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Papers

Sodium alginate as an eco-friendly rheology modifier and salt-tolerant fluid loss additive in water-based drilling fluids

One-step fabrication of BaMoO4 microstructures with controlled morphologies via a simple EDTA-mediated route

In Situ Shale Wettability Regulation Using Sophisticated Nanoemulsion to Maintain Wellbore Stability in Deep Well Drilling.

Synergistic effects of potassium alginate and silicates co-inhibition performance in shale hydration