Effect of silty sand in formation water on CO2 corrosion behavior of carbon steel

2016 ◽  
Vol 367 ◽  
pp. 438-448 ◽  
Author(s):  
Wei Liu ◽  
Juanjuan Dou ◽  
Songle Lu ◽  
Peng Zhang ◽  
Qinghe Zhao
Keyword(s):  
Carbon Steel ◽  
Corrosion Behavior ◽  
Silty Sand ◽  
Co2 Corrosion ◽  
Formation Water

scholarly journals The inhibition performance of mono-ethylene glycol on corrosion rate of x-80 grade carbon steel in saturated brine environment.

2020 ◽  
Vol 1 (1) ◽  
Keyword(s):  
Acetic Acid ◽  
Charge Transfer ◽  
Carbon Steel ◽  
Corrosion Rate ◽  
Ethylene Glycol ◽  
Oil And Gas ◽  
Gas Production ◽  
Electrochemical Measurements ◽  
Co2 Corrosion ◽  
Formation Water

The formation/deposition of hydrate and scale in gas production and transportation pipeline has continue to be a major challenge in the oil and gas industry. Pipeline transport is one of the most efficient, reliable and safer means of transporting petroleum products from the well sites to either the refineries or to the final destinations. Acetic acid (HAc), is formed in the formation water which also present in oil and gas production and transportation processes. Acetic acid aids corrosion in pipelines and in turn aids the formation and deposition of scales which may eventually choke off flow. Most times, Monethylene Glycol (MEG) is added into the pipeline as an antifreeze and anticorrosion agent. Some laboratory experiments have shown that the MEG needs to be separated from unwanted substance such as HAc that are present in the formation water to avoid critical conditions in the pipeline. Internal pipeline corrosion slows and decreases the production of oil and gas when associated with free water and reacts with CO2 and organic acid by lowering the integrity of the pipe. In this study, the effect of Mono-Ethylene Glycol (MEG) and Acetic acid (HAc) on the corrosion rate of X-80 grade carbon steel in CO2 saturated brine were evaluated at 25oC and 80oC using 3.5% NaCl solution in a semi-circulation flow loop set up. Weight loss and electrochemical measurements using the linear polarization resistance (LPR) and electrochemical impedance spectroscope (EIS) were used in measuring the corrosion rate as a function of HAc and MEG concentrations. The results obtained so far shows an average corrosion rate increases from 0.5 to 1.8 mm/yr at 25oC, and from 1.2 to 3.5 mm/yr at 80oC in the presence of HAc. However, there are decrease in corrosion rate from 1.8 to 0.95 mm/yr and from 3.5 to 1.6mm/yr respectively at 25oC and 80oC on addition of 20% and 80% MEG concentrations to the solution. It is also noted that the charge transfer with the electrochemical measurements (EIS) results is the main corrosion controlling mechanism under the test conditions. The higher temperature led to faster film dissolution and higher corrosion rate in the presence of HAc. The EIS results also indicate that the charge transfer controlled behaviour was as a result of iron carbonate layer accelerated by the addition of different concentrations of MEG to the system. Key words: CO2 corrosion, Carbon steel, MEG, HAc, Inhibition, Environment.

scholarly journals Fundamental aspects of the corrosion of N80 steel in a formation water system under high CO2 partial pressure at 100 °C

RSC Advances ◽  
2019 ◽  
Vol 9 (21) ◽  
pp. 11641-11648 ◽  
Author(s):  
Huixin Li ◽  
Dapeng Li ◽  
Lei Zhang ◽  
Yang Bai ◽  
Yun Wang ◽  
...  
Keyword(s):  
High Pressure ◽  
Carbon Steel ◽  
Partial Pressure ◽  
Corrosion Behavior ◽  
Water System ◽  
Formation Water ◽  
High Co2 ◽  
Co2 Partial Pressure ◽  
N80 Steel

The corrosion behavior of N80 carbon steel in a simulated formation water system saturated with CO2 under high pressure at 100 °C was investigated.

scholarly journals Effects of silty sand on CO2 corrosion behavior of low-Cr tubing steel

2012 ◽  
Vol 57 (8) ◽  
pp. 927-934 ◽  
Author(s):  
Wei Yan ◽  
JinGen Deng ◽  
XiaoRong Li ◽  
XingLiang Dong ◽  
ChunYang Zhang
Keyword(s):  
Corrosion Behavior ◽  
Silty Sand ◽  
Co2 Corrosion

scholarly journals A Study of the Pitting and Uniform Corrosion Characteristics of X65 Carbon Steel in Different H2S-CO2-Containing Environments

CORROSION ◽  
10.5006/2537 ◽  
2018 ◽  
Vol 74 (8) ◽  
pp. 886-902 ◽  
Author(s):  
Frederick Pessu ◽  
Yong Hua ◽  
Richard Barker ◽  
Anne Neville
Keyword(s):  
Carbon Steel ◽  
Corrosion Behavior ◽  
Pitting Corrosion ◽  
Critical Concentration ◽  
Small Diameter ◽  
Gas Content ◽  
Co2 Corrosion ◽  
Uniform Corrosion ◽  
Corrosion Attack ◽  
The Impact

There have been increasing concerns related to the challenges posed by hydrogen sulfide (H2S) corrosion to the integrity of oilfield pipeline steels. In environments containing variable quantities of both carbon dioxide (CO2) and H2S gas, the corrosion behavior of carbon steel can be particularly complex. There is still no universal understanding of the changes in the mechanisms, sequence of electrochemical reactions and impact on the integrity of carbon steel materials as a result of changes in H2S-CO2 gas ratio. The film formation process, film characteristics, and morphology in CO2- and H2S-containing systems are also known to be different depending upon the environmental and physical conditions and this influences the rates of both general and pitting corrosion. Questions still remain as to how the combined presence of CO2 and H2S gases at different partial pressure ratios influence the corrosion mechanisms, as well as initiation and propagation of surface pits. This paper presents an investigation into the overall (i.e., general and pitting) corrosion behavior of carbon steel in CO2-H2S-containing environments. The work explores the impact of changes in ratios of CO2 and H2S partial pressures at both 30°C and 80°C in a 3.5 wt% NaCl solution. All experiments are performed at atmospheric pressure, while H2S gas content is varied at 0 ppm (0 mol%), 100 ppm (0.01 mol%), 1,000 ppm (0.1 mol%), 10,000 ppm (1 mol%), and 100,000 ppm (10 mol%) in H2S-CO2 corrosion environments. Corrosion film properties and morphology are studied through a combination of scanning electron microscopy and x-ray diffraction. The results show that the morphology and composition of iron sulfide formed changes with H2S gas concentration because of the continuous interaction of the corrosion interface with the corrosion media even in the presence of initially formed FeS (mainly mackinawite). This often leads to the formation of a different morphology of mackinawite as well as different polymorphs of FeS. This also has the impact of either increasing or decreasing the uniform corrosion rate at low and higher concentration of H2S gas depending on the temperature. Pitting corrosion is also evaluated after 168 h to determine the impact of increasing H2S content on the extent and morphology of pitting corrosion attack. The results from the pitting corrosion investigation show that increased and severe pitting corrosion attack occurs at higher H2S concentration and temperature. The morphology of pitting corrosion attack is also linked to the changes in the H2S content with an indication of a critical concentration range at which the nature of attack changes from narrow and small diameter pits to severe localized attack. The critical concentration threshold for such transition is shown in this study to reduce with increasing temperature.

Corrosion Behavior of The Weld Zone of Carbon Steel Overpack for HLW Geological Disposal

2008 ◽  
Author(s):  
Yutaka Yokoyama ◽  
Rieko Takahashi ◽  
Hidekazu Asano ◽  
Naoki Taniguchi ◽  
Morimasa Naito
Keyword(s):  
Carbon Steel ◽  
Corrosion Behavior ◽  
Weld Zone ◽  
Geological Disposal
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