Effect of hydrophilic silica nanoparticles on hydrate formation: Insight from the experimental study

Wang, Ren; Liu, Tianle; Ning, Fulong; Ou, Wenjia; Zhang, Ling; Wang, Zhen; Peng, Li; Sun, Jiaxin; Liu, Zhichao; Li, Tianshu; Sun, Huiyu; Jiang, Guosheng

doi:10.1016/j.jechem.2018.02.021

Cited by 70 publications

(47 citation statements)

References 45 publications

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“…The phase equilibrium conditions (5.0 • C, 4.56 MPa) of CH 4 hydrates in pure water, and the temperature-pressure conditions for drilling in the marine hydrate exploration project in the South China Sea were considered [26][27][28]. According to these conditions, the effects of various types and concentrations of the thickeners on hydrate formation were investigated under two different initial experimental conditions that change the driving force of hydrate formation by increasing the pressure [29]: (a) 5.0 • C and 5.0 MPa (the corresponding undercooling of hydrate formation was~1.3 • C) as a weak driving force; and (b) 5.0 • C and 12.0 MPa (the corresponding undercooling of hydrate formation was~10.1 • C) as a strong driving force. To ensure experimental repeatability, each experiment was repeated thrice, and experiments were conducted as follows:…”

Section: Simulated Experiments For Hydrate Formationmentioning

confidence: 99%

“…The start and stop times for the hydrate formation as well as their corresponding values could be obtained from the temperature and pressure curves. During the evaluation of hydrate inhibition, the induction time and the amount and rate of hydrate formed were analyzed in detail [29,31]. Following this suggestion, a generalized method was employed to examine the induction time of hydrate formation [32].…”

Section: Data Processing Of the Simulated Experimentsmentioning

confidence: 99%

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Fundamental Investigation of the Effects of Modified Starch, Carboxymethylcellulose Sodium, and Xanthan Gum on Hydrate Formation under Different Driving Forces

et al. 2019

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The development of a new drilling fluid system with hydrate inhibition is of great significance for drilling safety in gas hydrate-bearing sediments. Considering the importance of the selection of a suitable thickener for drilling fluid systems under weak and strong driving forces, the hydrate inhibition of 0.1–0.5 wt% modified starch (MS), carboxymethylcellulose sodium (CMC), and xanthan gum (XG) aqueous solutions was studied. The applicability of these three thickeners were investigated through hydrate formation experiments, mesostructure observations, water activity tests, bubble retention observations, and rheological property tests. The results show that (1) under weak driving force, 0.3 wt% or higher concentration CMC and 0.3 wt% XG can almost completely inhibit hydrate formation due to the interactions between relatively small amounts of free water and CH4 molecules. Furthermore, the hydrate inhibition of higher XG concentrations was decreased due to their strong foam stability, leading to good contact between free water and CH4 molecules. Meanwhile, the hydrate inhibition of MS was weaker when compared with that of CMC and XG at the same concentrations. (2) Under strong driving force, the existence of the three 0.1–0.5 wt% thickeners could only slow down the hydrate formation rate, and hydrate inhibition due to XG was slightly better than that of the other two. This result implies that the effects of the different mesostructures on hydrate formation were severely weakened. Finally, (3) the tackifying effect of CMC was found to be stronger than that of XG and MS, and the rheological properties of the CMC solution were shown to be relatively weak compared to those of the XG and MS solutions; the CMC solution showed a more significant increase in viscosity with decreasing temperature, which is related to the differences in the mesostructures. Therefore, when the driving force of hydrate formation is relatively low, CMC is a good choice for the drilling fluid system when there is no requirement for cooling, while XG is more applicable for a system that needs cooling. In the case of a stronger driving force, XG is the optimal choice irrespective of whether the drilling fluid system needs cooling or not.

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Section: Simulated Experiments For Hydrate Formationmentioning

confidence: 99%

Section: Data Processing Of the Simulated Experimentsmentioning

confidence: 99%

Fundamental Investigation of the Effects of Modified Starch, Carboxymethylcellulose Sodium, and Xanthan Gum on Hydrate Formation under Different Driving Forces

et al. 2019

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“…In recent decades, classic clay compositions have been replaced by more complex polymer solutions [5][6][7][8]. Clay solutions can be treated with various additives, for example, acrylic polymers, to control the properties of the drilling mud, including rheological characteristics [9].…”

Section: Introductionmentioning

confidence: 99%

Influence of Polymer Reagents in the Drilling Fluids on the Efficiency of Deviated and Horizontal Wells Drilling

et al. 2020

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Improving the efficiency of well drilling process in a reservoir is directly related to subsequent well flow rates. Drilling of deviated and horizontal wells is often accompanied by an increase in pressure losses due to flow resistance caused by small size of the annular space. An important role in such conditions is played by the quality of borehole cleaning and transport capacity of drilling fluid, which is directly related to the rheological parameters of the drilling fluid. The main viscosifiers in modern drilling fluids are polymer reagents. They can be of various origin and structure, which determines their features. This work presents investigations that assess the effect of various polymers on the rheological parameters of drilling fluids. Obtained data are evaluated taking into account the main rheological models of fluid flow. However, process of fluid motion during drilling cannot be described by only one flow model. Paper shows experimentally obtained data of such indicators as plastic viscosity, dynamic shear stress, non-linearity index and consistency coefficient. Study has shown that high molecular weight polymer reagents (e.g., xanthan gum) can give drilling fluid more pronounced pseudoplastic properties, and combining them with a linear high molecular weight polymer (e.g., polyacrylamide) can reduce the value of the dynamic shear stress. Results of the work show the necessity of using combinations of different types of polymer reagents, which can lead to a synergetic effect. In addition to assessing the effect of various polymer reagents, the paper presents study on the development of a drilling fluid composition for specific conditions of an oil field.

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“…For example, when untreated oil and gas reservoirs transported through oil and gas pipelines contain natural gas and water, hydrates can be formed and aggregated at turns, reducers, valves, tee joints, separators, and other locations of the pipelines under appropriate temperature and pressure conditions, which will affect the safe transport of oil and gas [3][4][5]. During the construction of deep-sea conventional oil-and-gas drillings, shallow gas and hydrate decomposition gas will invade the drilling fluid and hydrates may be formed and aggregated in the annulus, and they will deteriorate the performance of drilling fluid and the efficiency of overall production [5][6][7][8]. During the exploiting of the sea area hydrates, the produced gas may form hydrates again at positions, such as wellbore gasliquid separator and sand control liner, which will seriously affect the gas production efficiency [5,9,10].…”

Section: Introductionmentioning

confidence: 99%

Effect of Dissolution and Dispersion Conditions of VC-713 on the Hydrate Inhibition

Wang

Sun

et al. 2019

Journal of Chemistry

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VC-713 is a kind of hydrate kinetics inhibitor, which is widely used because of its strong hydrate inhibition. In this paper, VC-713 was dissolved and dispersed into its solution to various degrees by stirring the solution at the speeds of 600 r·min−1 and 12000 r·min−1. Then, under the condition of normal pressure and temperature change (gradually decreasing from 278.15 K to 273.65 K), the hydrate inhibitory effect of dissolution and dispersion of VC-713 on THF hydrate formation was studied. The variation in the concentration of VC-713 was monitored during the experiments. In addition, the mesoscopic structure characteristics of aqueous solutions were observed, and experimental phenomena in the reactor were recorded along with real time. Then, the experimental data were comprehensively analyzed, and the underlying mechanism of inhibition was revealed. Results showed that VC-713 inhibits hydrate nucleation and growth by adsorbing and binding. When the addition amounts are the same, better dissolution and dispersion of VC-713 can inhibit the hydrate formation more effectively. This is due to more complex skeleton structures formed by the hydrated VC-713 molecule. When the amount of VC-713 is 0.5 wt.%, the induction time, the formation rate, and the degree of supercooling of hydrate formation were extended, mitigated, and increased by 10.30%, 21.43%, and 17.80%, respectively, and changed to values of 8.75%, 14.29%, and 22.50%, respectively, for 1.0 wt.% VC-713.

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Effect of hydrophilic silica nanoparticles on hydrate formation: Insight from the experimental study

Cited by 70 publications

References 45 publications

Fundamental Investigation of the Effects of Modified Starch, Carboxymethylcellulose Sodium, and Xanthan Gum on Hydrate Formation under Different Driving Forces

Fundamental Investigation of the Effects of Modified Starch, Carboxymethylcellulose Sodium, and Xanthan Gum on Hydrate Formation under Different Driving Forces

Influence of Polymer Reagents in the Drilling Fluids on the Efficiency of Deviated and Horizontal Wells Drilling

Effect of Dissolution and Dispersion Conditions of VC-713 on the Hydrate Inhibition

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