Abstract

Four types of nanoparticles, amorphous carbon, iron III oxide, SiO2, and amino-coated SiO2, were tested to determine changes in tetrahydrofuran–water (THF–water) clathrate hydrate nucleation and agglomeration. Rates were experimentally found to determine their viability for preventing natural gas hydrates from developing during offshore drilling operations. THF–water clathrates were chosen as a model to represent gas hydrate growth at atmospheric pressure. Concentrations of each nanoparticle between 0.15% and 1.0% by weight were tested as a kinetic inhibitor to hydrate formation. Tests were repeated at various temperatures below the formation temperature of 4.4 °C for THF–water clathrate hydrates. Measurements were made to identify how the concentration of THF affects the clathrate hydrates forming under static conditions between 20% and 30% by mole of THF. The primary tests in this study were performed using a 20:80 THF/water ratio. Temperature increases during hydrate nucleation for THF–water were measured between − 5 and 3 °C. The range of ideal nanoparticle concentrations was found to be between 0.15% and 0.45% by weight for optimal static, kinetic inhibition of hydrate nucleation. At approximately 0.3% by weight, the most significant inhibition was observed under static conditions for all four types of nanoparticles tested. We found that functionalized amino-coated SiO2 nanoparticles, across all tests, significantly increased the time required for the formation of THF–water clathrate hydrates compared to the other three non-functionalized nanoparticles. The amorphous carbon and iron III oxide nanoparticles performed similarly across each test and were both the least effective in their inhibition of the clathrate hydrates of the four nanoparticles studied compared to a control.

Highlights

  • The formation of gas hydrates during offshore drilling in deep waters is a well-recognized operational hazard

  • Can lead to severe well-control problems (Kim et al 2007). Another major issue arises due to the dissociation of hydrate-bearing sediments (HBS) during drilling operations when they come in contact or are penetrated by drilling fluids that bring about a change in their temperature and pressure conditions (Kjaer 2014; Zerpa 2013)

  • Experimental results show that over this range of THF–water ratios, the ­SiO2+A nanoparticles can inhibit the nucleation of hydrates by requiring a longer nucleation time compared to samples using the other three nanoparticles and the control

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Summary

Introduction

The formation of gas hydrates during offshore drilling in deep waters is a well-recognized operational hazard. Edited by Yan-Hua Sun can lead to severe well-control problems (Kim et al 2007) Another major issue arises due to the dissociation of HBS during drilling operations when they come in contact or are penetrated by drilling fluids that bring about a change in their temperature and pressure conditions (Kjaer 2014; Zerpa 2013). This leads to severe mud gasification, partial washout and caving, casing running problems and casing subsidence. Models can be used to predict how the drilling fluids will interact with these HBS due to the change in temperature distribution and dissociating more substantial amounts of gas within the wellbore. Once the gas has entered the drilling fluid column, it can begin to reform into methane hydrates

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