Improving the tribological characteristics of water-based drilling fluids by adding graphene-based lubricants has garnered attention because of the potential for a range of inorganic-material-based additives at high temperature. In this study, we constructed a green and simple adsorption approach to prepare highly dispersed graphite using a cationic surfactant for graphite modification. The findings demonstrated that the prepared graphite was highly dispersed in water and had a low sedimentation rate and small contact angle in distilled water. The concentration dosage of cetyltrimethylammonium chloride (CTAC) on graphite was 0.02 g/g. We evaluated the performance of the modified graphite as a lubricated additive in water-based drilling through a rheological study and viscosity coefficient measurement. The results showed that the viscosity coefficient of drilling fluid with 0.05% modified graphite was reduced by 67% at 180 °C. We proved that the modified graphite can significantly improve the lubrication performance of drilling fluid. Furthermore, we revealed the lubrication mechanism by analyzing the chemical structural and crystalline and morphological features of graphite through a particle size test, zeta potential test, Fourier transform infrared (FTIR) spectroscopy, X-ray powder diffraction (XRD), and scanning electron microscopy (SEM) measurements. The results indicated that the modification of graphite by CTAC only occurs through physical adsorption, without changing the crystal structure. These findings provide a reference for the development of high-performance water-based drilling fluids.

Wellbore instability caused by the hydration of shale formations during drilling is a major problem in drilling engineering. In this paper, the shale inhibition performance of polyhydroxy-alkanolamine was evaluated using an anti-swelling test, linear swelling test, wash-durable test and montmorillonite hydration and dispersion experiment. Additionally, the shale inhibition mechanism of polyhydroxy-alkanolamine was studied via Fourier transform infrared spectroscopy (FTIR), particle size, zeta potential, thermogravimetric analysis (TGA) and scanning electron microscopy (SEM). The results show that the use of polyhydroxy-alkanolamine (EGP-2) could result in a relatively lower linear swelling rate of montmorillonite, and the linear swelling rate of 0.3% EGP-2 is 26.98%, which is stronger than that of 4% KCl. The anti-swelling rate of 0.3% EGP-2 is 43.54%, and the shrinkage–swelling rate of 0.3% EGP-2 is 34.62%. The study on the inhibition mechanism revealed that EGP-2 can permeate and adsorb on the surface of montmorillonite. The rolling recovery rate of easily hydrated shale was as high as 79.36%, which greatly reduces the dispersion ability of water to easily hydrated shale. The results of this study can be used to maintain the stability of a wellbore, which is conducive to related research.

Modified starch is used as a drilling fluid treatment agent in oilfields. During the drilling process, modified starch plays a vital role in the drilling fluid system, but its poor temperature resistance limits its application in oilfields. Therefore, this paper studied the performance of several starches in water-based drilling fluids through co-gelatinization modification; studied the effectiveness of several modifiers in gelatinized starch drilling fluids, combined with flow modification performance tests, bentonite linear expansion rate, salt resistance, and other experimental methods to complete the screening of the best modified starch; and systematically compared the temperature resistance, inhibition, compatibility, and salt resistance before and after gelatinization. The possible mechanism of action of modified starch treatment was analyzed and tested by Fourier-transform infrared spectroscopy (FTIR), thermogravimetric analysis (TGA), laser particle size analyzer and scanning electron microscopy (SEM). The results showed that the decomposition temperatures of cassava starch (TS), potato starch (PS), and corn starch (CS) were different, and the decomposition temperature of cassava starch (TS) was the highest, at 150 °C. At this temperature, the optimal dosage of gelatinized TS is 2.5%, the maximum shear force is 2.25 Pa, and the filtration loss is only 12.6 mL. TS has obvious performance advantages over other starches. After co-gelatinization with 1.0% iodine and 2.5% TS at 140 °C, it has a good viscosity reduction and filtration loss effect, and the filtration loss is only 5.2 mL, which is 31.6% lower than that of untreated TS drilling fluid. The linear expansion rate at 120 min is 10.85%, indicating that it has a strong inhibitory effect on the hydration and dispersion of bentonite. In addition, iodine cassava starch (ITS) has good compatibility in drilling-fluid formulations and shows good salt resistance when mixed with different concentrations of KCl. The results of this study can be used to improve the temperature resistance of filtration agents and facilitate related research.

In this paper, small-molecule quaternary ammonium salts were synthesized by N-alkylation to inhibit hydration swelling and hydration dispersion. The prepared small-molecule quaternary ammonium salt was characterized by Fourier transform infrared (FTIR) spectroscopy, Thermogravimetric analysis (TGA), particle size analysis and Scanning electron microscopy (SEM), and its performance as an inhibitor in clay was evaluated by an anti-swelling test and a linear swelling test. The results show that small-molecule quaternary ammonium salt (TEE-2) synthesized by triethanolamine and epichlorohydrin in ethanol with a molar ratio of 1:1.5 can successfully inhibit the hydration swelling and dispersion of clay. The anti-swelling rate of TEE-2 was 84.94%, the linear swelling rate was 36.42%, and the linear swelling rate of 0.5% TEE-2 was only 29.34%. The hydration swelling of clay in 0.5% TEE-2 solution was significantly inhibited. The hydration inhibition mechanism of the small-molecule quaternary ammonium salt inhibitor 0.5% TEE-2 was analyzed by FTIR, SEM and TGA. It was considered that 0.5% TEE-2 has strong hydration inhibition, which was realized by infiltration and adsorption on the clay surface. Small-molecule quaternary ammonium salts were beneficial for maintaining wellbore stability and reducing the risk of wellbore instability.