The influence of corrosion inhibitors on hydrate formation temperature along the subsea natural gas pipelines

Abstract

Pipeline industry annually invests millions of dollar on corrosion inhibitors in order to minimize corrosion's implication on flow assurance; however, attention has never been focused on the possibilities of these chemicals to promote hydrate formation along deepwater pipeline which is also a flow assurance problem. Five inhibitors were investigated in this study at different concentrations and pressures in a cryogenic sapphire cell at static condition. The changes in the formation temperature established that all the inhibitors promote hydrate but at different rates while their hydrate formation patterns also differ from one another. Their ability to promote hydrate could be attributed to their hydrogen bonding properties which is required for hydrate formation. Also, the difference in the promotion rate is attributed to their different sizes and structures, active functional groups and affinity for water molecules which determine the type of hydrogen bonding exhibited by each inhibitor while in solution. The structure and size of each inhibitor also affect its electronegativity and ionization energy since the active electrons of some of the inhibitors have direct exposure to the nucleus while for others; the active electrons at the outermost shell have been shielded from direct influence of the attractive force. Furthermore, the active functional groups obeys electronegativity trend of periodic table to determine whether the resulting bond type will be polar ionic, covalent or ionic with some covalent characteristic in nature. Though, all the inhibitors are foamy; Dodecylpyridinium chloride (DPC) was however the foamiest. DPC also exhibited its highest promotion ability at 200ppm and exhibited specific behaviour at 5000ppm to suggest a change in the hydrate formation rate beyond the critical micelles concentration (CMC). Again, increase in agitation rate prolonged the complete solidification time of the hydrates probably due to the gas solubility. Finally, the feasibility of using this chemical as an additive at high concentrations for natural gas transportation and storage in slurry form was observed due to some exhibited properties, this however requires further investigations.

Influence of natural gas production chemicals on scale production in MEG regeneration systems

“…The reduced affinity of B.D.H.C for water then allows precipitation of more salts that dissociate to produce more scalings. It was further observed that C.P.C and D.P.C that belong to same family exhibited similar trends which might be as a result of their common active functional groups that enabled them to form N--H and H--Cl bonds (Obanijesu et al, 2014b).…”

Influence of Hydrate Formation and Concentration of Salts on the Corrosion of Steel 20 Pipelines

“…Studies [15,17] have shown an increase in the level of localization of corrosion processes, but no explanation for this phenomenon has been provided. In general, most of the results reported in the literature describe hydrate formation during offshore gas [4,23,25] and gas transportation by offshore or onshore pipelines [9,16,20]. Mathematical models of corrosion effects of gas hydrates [1,2,3,6,21,22,24] do not take into account the effect on the metal or passive films of the hydrate itself, but only the pH of the medium or the concentration of CO2 in the gas.…”

Thermodynamic Modeling Of Electrolytic Solutions of Ionic Liquids for Gas Hydrates Inhibition Applications

“…Therefore, the prevention for gas hydrates formation has been in the center of research to improve flow assurance strategies and avoid the problems caused by hydrates formation in pipelines. Several methods exist in this way, like heating, depressurization or dehydration, but the most used in industry is the chemical inhibition [18,27,28].…”