The effects of hydrogen charging time and pressure on the hydrogen embrittlement(HE)susceptibility of X52 pipeline steel material are studied by slow strain rate tensile tests.The fracture morphologies of the specimen...The effects of hydrogen charging time and pressure on the hydrogen embrittlement(HE)susceptibility of X52 pipeline steel material are studied by slow strain rate tensile tests.The fracture morphologies of the specimens are observed by scanning electron microscopy.The HE susceptibility of the X52 pipeline steel material increases with an increase in both hydrogen charging time and hydrogen pressure.At a charging time of 96 h,the HE susceptibility index reaches 45.86%,approximately 3.6 times that at a charging time of 0 h.Similarly,a charging pressure of 4 MPa results in a HE susceptibility index of 31.61%,approximately 2.5 times higher than that at a charging pressure of 0.3 MPa.展开更多
The aim of this study is to evaluate the internal corrosion process on X52 and X80 steels/real petroleum interfaces containing condensed hydrocarbon plus oilfield-produced water,which were subjected to stimulated emul...The aim of this study is to evaluate the internal corrosion process on X52 and X80 steels/real petroleum interfaces containing condensed hydrocarbon plus oilfield-produced water,which were subjected to stimulated emulsions using 50/50 vol ratio mixtures at 45℃,different hydrodynamic conditions,1 h,and 24 h.A washing process by using deionized water was proposed to simulate and identify the corrosiveness of the hydrocarbon phase after 24 h of exposure time.The characterization by electrochemical impedance spectroscopy and the monitoring of the polarization curves indicated that X80 steel/oilfield-produced water interfaces were more susceptible to corrosion than X52 steel exposed to oilfield-produced water.The combined speed rotation of 600 rpm using a magnetic stirrer+600 rpm using a rotating disk electrode decreased the corrosion rate on X52 steel.The stimulated emulsions made of hydrocarbon+oilfield-produced water and hydrocarbon+deionized water at 24 h increased the corrosion rate on X80 steel(0.34 mm/year and 0.43 mm/year,respectively),promoting the formation of erosion and pitting corrosion.These types of corrosion depended mainly on the physicochemical properties of the hydrocarbon,oilfield-produced water,exposure times,and hydrodynamic systems in which the hydrocarbon was studied.展开更多
In the oil and gas industry, it has been established that for pipelines fabricated with carbon steels, their limitation is related to H<sub>2</sub>S and CO<sub>2</sub> environments, which is 7 ...In the oil and gas industry, it has been established that for pipelines fabricated with carbon steels, their limitation is related to H<sub>2</sub>S and CO<sub>2</sub> environments, which is 7 to 10 psia of partial pressure of <span style="white-space:normal;">CO</span><sub style="white-space:normal;">2</sub>. Therefore, in carbon steel cracking is shown, after 7 or 10 psia of partial pressure of <span style="white-space:normal;">CO</span><sub style="white-space:normal;">2</sub>. The experimental work was performed under static conditions in autoclaves within a pH of 3 to 3.8;partial pressures of 16 - 96 psi for H<sub>2</sub>S and 15 - 53 psi for <span style="white-space:normal;">CO</span><sub style="white-space:normal;">2</sub>, in the temperature range of 25<span style="white-space:nowrap;">°</span>C - 150<span style="white-space:nowrap;">°</span>C. It was observed that the average yielding stress used in Sulfide Stress Cracking (SSC) tests decreases with temperature increment. Hydrogen Induced Cracking (HIC) evaluations showed that X52 steel, under conditions, was not susceptible to HIC. Results of SSC did not show indications of cracking after exposure to sour solutions, except for the specimen exposed to high H<sub>2</sub>S and <span style="white-space:normal;">CO</span><sub style="white-space:normal;">2</sub> content (96 psi of H<sub>2</sub>S and 53 psi of <span style="white-space:normal;">CO</span><sub style="white-space:normal;">2</sub> of the partial pressure) and high temperature (150<span style="white-space:nowrap;">°</span>C). Microcracks located between the upper and lower weld beads were also observed. However, the highest average corrosion rate was 0.27 mm/year (10.6 mpy), which occurred in samples exposed to 96 psi of H<sub>2</sub>S and 53 psi of <span style="white-space:normal;">CO</span><sub style="white-space:normal;">2</sub> at 150<span style="white-space:nowrap;">°</span>C. Likewise, the highest localized corrosion (severe pitting attack) was obtained at the same environme展开更多
基金This work was supported by the National Key R&D Program of China(2021YFB4001601)the Youth Innovation Promotion Association CAS(2022187).
文摘The effects of hydrogen charging time and pressure on the hydrogen embrittlement(HE)susceptibility of X52 pipeline steel material are studied by slow strain rate tensile tests.The fracture morphologies of the specimens are observed by scanning electron microscopy.The HE susceptibility of the X52 pipeline steel material increases with an increase in both hydrogen charging time and hydrogen pressure.At a charging time of 96 h,the HE susceptibility index reaches 45.86%,approximately 3.6 times that at a charging time of 0 h.Similarly,a charging pressure of 4 MPa results in a HE susceptibility index of 31.61%,approximately 2.5 times higher than that at a charging pressure of 0.3 MPa.
文摘The aim of this study is to evaluate the internal corrosion process on X52 and X80 steels/real petroleum interfaces containing condensed hydrocarbon plus oilfield-produced water,which were subjected to stimulated emulsions using 50/50 vol ratio mixtures at 45℃,different hydrodynamic conditions,1 h,and 24 h.A washing process by using deionized water was proposed to simulate and identify the corrosiveness of the hydrocarbon phase after 24 h of exposure time.The characterization by electrochemical impedance spectroscopy and the monitoring of the polarization curves indicated that X80 steel/oilfield-produced water interfaces were more susceptible to corrosion than X52 steel exposed to oilfield-produced water.The combined speed rotation of 600 rpm using a magnetic stirrer+600 rpm using a rotating disk electrode decreased the corrosion rate on X52 steel.The stimulated emulsions made of hydrocarbon+oilfield-produced water and hydrocarbon+deionized water at 24 h increased the corrosion rate on X80 steel(0.34 mm/year and 0.43 mm/year,respectively),promoting the formation of erosion and pitting corrosion.These types of corrosion depended mainly on the physicochemical properties of the hydrocarbon,oilfield-produced water,exposure times,and hydrodynamic systems in which the hydrocarbon was studied.
文摘In the oil and gas industry, it has been established that for pipelines fabricated with carbon steels, their limitation is related to H<sub>2</sub>S and CO<sub>2</sub> environments, which is 7 to 10 psia of partial pressure of <span style="white-space:normal;">CO</span><sub style="white-space:normal;">2</sub>. Therefore, in carbon steel cracking is shown, after 7 or 10 psia of partial pressure of <span style="white-space:normal;">CO</span><sub style="white-space:normal;">2</sub>. The experimental work was performed under static conditions in autoclaves within a pH of 3 to 3.8;partial pressures of 16 - 96 psi for H<sub>2</sub>S and 15 - 53 psi for <span style="white-space:normal;">CO</span><sub style="white-space:normal;">2</sub>, in the temperature range of 25<span style="white-space:nowrap;">°</span>C - 150<span style="white-space:nowrap;">°</span>C. It was observed that the average yielding stress used in Sulfide Stress Cracking (SSC) tests decreases with temperature increment. Hydrogen Induced Cracking (HIC) evaluations showed that X52 steel, under conditions, was not susceptible to HIC. Results of SSC did not show indications of cracking after exposure to sour solutions, except for the specimen exposed to high H<sub>2</sub>S and <span style="white-space:normal;">CO</span><sub style="white-space:normal;">2</sub> content (96 psi of H<sub>2</sub>S and 53 psi of <span style="white-space:normal;">CO</span><sub style="white-space:normal;">2</sub> of the partial pressure) and high temperature (150<span style="white-space:nowrap;">°</span>C). Microcracks located between the upper and lower weld beads were also observed. However, the highest average corrosion rate was 0.27 mm/year (10.6 mpy), which occurred in samples exposed to 96 psi of H<sub>2</sub>S and 53 psi of <span style="white-space:normal;">CO</span><sub style="white-space:normal;">2</sub> at 150<span style="white-space:nowrap;">°</span>C. Likewise, the highest localized corrosion (severe pitting attack) was obtained at the same environme
