The effect of different brines and temperatures on the competitive degradation mechanisms of CO2 and H2S in API X65 carbon steel

Santos, Bernardo Augusto Farah; Souza, Rhuan Costa; Serenário, Maria Eduarda Dias; Gonçalves, M.C.; Júnior, E.P. Mendes; Simões, Thiago A.; Oliveira, Jefferson Rodrigues de; Vaz, Gustavo L.; Caldeira, Lecino; Gomes, José Orlando; Bueno, Alysson Helton Santos

doi:10.1016/j.jngse.2020.103405

Cited by 14 publications

(11 citation statements)

References 31 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…This assembly was adopted based on the work developed by Souza et al [8] because, given the aggressiveness of the evaluated environments, the tests would hardly provide reliable and reproducible responses with the use of conventional reference electrodes. Some researchers have used the same assembly and have also observed a good correlation with results obtained with a conventional assembly [26–29].…”

Section: Methodsmentioning

confidence: 84%

The role of acetic acid in FeCO₃ scale deposition on CO₂ corrosion of API X65 carbon steel under high temperatures

Santos

Souza

Serenário

et al. 2021

Corrosion Engineering, Science and Technology

View full text Add to dashboard Cite

The combined effects of high temperatures and different acetic acid (HAc) concentrations on corrosion and deposition of FeCO 3 scales on API X65 carbon steel in CO 2 -saturated brines were investigated. Conditions with the absence and presence of 100 and 600 ppm of HAc were evaluated under high pressure at 90°C and 120°C. Electrochemical impedance spectroscopy, linear polarisation resistance, weight loss and characterisations through scanning electron microscopy, energy-dispersive spectroscopy and X-ray diffraction were conducted. Conditions with the absence of acid presented a huge deposition of sweet corrosion products and low corrosion rates. The addition of 100 ppm of acid at 90°C did not increase significantly corrosion rates; however, it retarded the precipitation of FeCO 3 . Higher temperatures favoured iron carbonate nucleation even in the presence of HAc. The highest corrosion rates were observed for the environment with 600 ppm of HAc at 120°C.

show abstract

Section: Methodsmentioning

confidence: 84%

The role of acetic acid in FeCO₃ scale deposition on CO₂ corrosion of API X65 carbon steel under high temperatures

Santos

Souza

Serenário

et al. 2021

Corrosion Engineering, Science and Technology

View full text Add to dashboard Cite

show abstract

“…Overall, the reaction rate of corrosion induced by carbon dioxide depends on several factors including pressure, [ 40 ] temperature, [ 42,46 ] pH and flow rate, [ 42 ] as well as hydrogen sulfide [ 44 ] and chloride [ 46,47 ] concentrations.…”

Section: Corrosion In Geothermal Systems and Related Fieldsmentioning

confidence: 99%

“…For example, a multilayered carbonate/oxide structure was found on chromium-containing steels in brine saturated in carbon dioxide at 60°C. [45] Overall, the reaction rate of corrosion induced by carbon dioxide depends on several factors including pressure, [40] temperature, [42,46] pH and flow rate, [42] as well as hydrogen sulfide [44] and chloride [46,47] concentrations.…”

Section: Steel Corrosion In the Presence Of Carbon Dioxidementioning

confidence: 99%

“…For their part, Santos et al [46] showed through autoclave electrochemical measurements in brine saturated in carbon dioxide that an increase in the chloride content or in the temperature (from 90°C to 120°C) favors the formation of iron carbonate film on carbon steel, but the quality of this deposit was not enough to reduce corrosion rate at 120°C. It was also reported [47] that, up to a certain value (25 g/L chloride for N80 steel at 100°C, 2 MPa carbon dioxide), an increase in the chloride content increases the corrosion rate of carbon steel in artificial oil and gas fluid due to the destruction of the corrosion product film and the enhancement of the anodic reaction of the corrosion mechanism.…”

Section: Steel Corrosion In the Presence Of Carbon Dioxidementioning

confidence: 99%

Section: Corrosion In Geothermal Systems and Related Fieldsmentioning

confidence: 99%

See 2 more Smart Citations

Monitoring and mitigating corrosion in geothermal systems

Schott

Liautaud

2022

Materials & Corrosion

View full text Add to dashboard Cite

In terms of current needs for renewable resources, geothermal energy is one of the future solutions for heat and electricity generation. However, geothermal plants are exposed to very aggressive media (high-temperature [HT], salt-rich fluid, etc.), leading to extensive corrosion of the metallic parts. Should the corrosion inhibitors work at HT, their injection would be mandatory to ensure the reasonable lifetime of geothermal plants. The first part of this review concerns the degradations observed in geothermal plants, which depend on the site properties and the methods for evaluating the corrosion intensity of such systems. Autoclave experiments, although rarely used for geothermal applications, maybe the most appropriate to measure the representative corrosion rate, that is, under use temperature and pressure conditions. In the second part, clues to evaluate the performance and mechanism of corrosion inhibitors are mentioned, and molecules already used to protect steel are reported. However, this review also highlights the lack of data on HT inhibitors, especially for geothermal applications, where the efficiency of a given molecule is strongly related to the real medium. Thus, the protection of new geothermal plants where HT is reached requires the search for products that are stable and efficient under such conditions.Using the heat derived from the Earth's core, geothermal energy constitutes a renewable solution for future energy. It is already widely used worldwide, especially in Europe with several sites in Iceland and in the Dogger aquifer, Paris basin. Additional sites were recently identified, for example, in Upper Rhine Graben, where the composition of the media and use temperatures may differ from the already established plants.However, due to the aggressiveness of geothermal fluids, one major issue is the reduced lifetime of geothermal plants. Indeed, the steel tubes of such | © 2022 Wiley-VCH GmbH.

show abstract

Influence of parameters related to microstructure, chemical composition and environment characteristics on localized corrosion failure susceptibility of supermartensitic stainless steels

Sabará

Prachedes

Santos

et al. 2021

Engineering Failure Analysis

View full text Add to dashboard Cite

The effect of different brines and temperatures on the competitive degradation mechanisms of CO2 and H2S in API X65 carbon steel

Cited by 14 publications

References 31 publications

The role of acetic acid in FeCO₃ scale deposition on CO₂ corrosion of API X65 carbon steel under high temperatures

The role of acetic acid in FeCO₃ scale deposition on CO₂ corrosion of API X65 carbon steel under high temperatures

Monitoring and mitigating corrosion in geothermal systems

Influence of parameters related to microstructure, chemical composition and environment characteristics on localized corrosion failure susceptibility of supermartensitic stainless steels

Contact Info

Product

Resources

About

The effect of different brines and temperatures on the competitive degradation mechanisms of CO2 and H2S in API X65 carbon steel

Cited by 14 publications

References 31 publications

The role of acetic acid in FeCO3 scale deposition on CO2 corrosion of API X65 carbon steel under high temperatures

The role of acetic acid in FeCO3 scale deposition on CO2 corrosion of API X65 carbon steel under high temperatures

Monitoring and mitigating corrosion in geothermal systems

Influence of parameters related to microstructure, chemical composition and environment characteristics on localized corrosion failure susceptibility of supermartensitic stainless steels

Contact Info

Product

Resources

About

The role of acetic acid in FeCO₃ scale deposition on CO₂ corrosion of API X65 carbon steel under high temperatures

The role of acetic acid in FeCO₃ scale deposition on CO₂ corrosion of API X65 carbon steel under high temperatures