Effect of calcium carbonate on low carbon steel corrosion behavior in saline CO2 high pressure environments

Tavares, Lisiane Morfeo; Costa, Eleani Maria da; Andrade, Jairo José de Oliveira; Hübler, Roberto; Huet, Bruno

doi:10.1016/j.apsusc.2015.10.075

Cited by 79 publications

(42 citation statements)

References 29 publications

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“…On the other hand, Gao, et al, 20 reported that formation of "mixed" metal carbonates (Fe x Ca y CO 3 and Fe x (Mg,Ca) y CO 3 , where x + y = 1) in the precipitated layers was responsible for localized corrosion. Tavares, et al, 21 postulated that the mixed carbonate corrosion product layers are more porous than the iron carbonate layers. From this brief literature review, it remains unclear what mechanism is responsible for localized corrosion resulting from the presence of CaCl 2 in aqueous CO 2 solutions.…”

Section: Introductionmentioning

confidence: 99%

Effect of Incorporation of Calcium into Iron Carbonate Protective Layers in CO₂ Corrosion of Mild Steel

et al. 2016

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The two dominant cationic species in reservoir brine are sodium (Na +) and calcium (Ca 2+). Calcite (CaCO 3) and siderite (FeCO 3) are isostructural, thus Ca 2+ incorporates readily into the hexagonal FeCO 3 lattice, and vice versa. In aqueous carbon dioxide (CO 2) solutions where both Ca 2+ and ferrous iron (Fe 2+) are present (such as downhole gas reservoirs or deep saline aquifers after CO 2 injection), inhomogeneous mixed metal carbonates with the formula Fe x Ca y CO 3 (x + y = 1) can form; their presence on steel has been hypothesized to lead to localized corrosion. During carbon steel corrosion experiments conducted in electrolytes containing high Ca 2+ concentrations, inhomogeneous corrosion product layers with the composition Fe x Ca y CO 3 (x + y = 1) were indeed observed, along with non-uniform corrosion. Determining relative molar fractions of Ca 2+ and Fe 2+ in Fe x Ca y CO 3 is paramount to predicting the relative properties and stability of such mixed metal carbonates. Using Bragg's law and equations to relate interplanar spacings to unit cell parameters, x-ray diffraction patterns yielded values for the mole fraction of Ca 2+ in Fe x Ca y CO 3. Procedures in the current study were designed to develop a range of specific corrosion product layers on mild steel samples. The compositional analysis of these surface layers was used to develop a relationship with the observed corrosion mechanisms. Experiments were conducted at constant chloride (Cl −) concentration with and without 10,000 ppm Ca 2+ in stagnant conditions and for two different flow conditions. In stagnant conditions, localized corrosion was associated with the presence of Ca 2+ and the inhomogeneity of the corrosion product layer. The corrosion attack became uniform when flow was introduced.

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Section: Introductionmentioning

confidence: 99%

Effect of Incorporation of Calcium into Iron Carbonate Protective Layers in CO₂ Corrosion of Mild Steel

et al. 2016

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“…The results for the spectral analysis of the corroded sample surfaces are shown in Table 4. Before CO 2 reached a supercritical state, the samples exhibited dense surface coatings that mainly consisted of FeC 3 and FeCO 3 and almost lacked CaCO 3 [14,17,19,24]. The average corrosion rates and maximum corrosion depths of the samples were low.…”

Section: Resultsmentioning

confidence: 99%

“…The average corrosion rates and maximum corrosion depths of the samples were low. After CO 2 reached the supercritical state, loose surface coatings that mainly consisted of FeCO 3 and CaCO 3 formed and failed to provide effective surface protection to the samples [14,19,24]. Thus, the average corrosion rates and maximum corrosion depths of the samples increased.…”

Section: Resultsmentioning

confidence: 99%

Pitting Corrosion and Microstructure of J55 Carbon Steel Exposed to CO2/Crude Oil/Brine Solution under 2–15 MPa at 30–80 °C

Bai

Wang

et al. 2018

Materials

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This study aimed to evaluate the corrosion properties of J55 carbon steel immersed in CO2/crude oil/brine mixtures present in the wellbores of CO2-flooded production wells. The main corroded position of wellbore was determined and wellbore corrosion law was provided. Corrosion tests were performed in 30% crude oil/brine solution under the simulated temperature (30–80 °C) and pressure (2–15 MPa) conditions of different well depths (0–1500 m). The corrosion behavior of J55 carbon steel was evaluated through weight-loss measurements and surface analytical techniques, including scanning electron microscopy, energy dispersive spectrometer, X-ray diffraction analysis, and optical digital microscopy. Corrosion rate initially increased and then decreased with increasing well depth, which reached the maximum value of 1050 m. At this well depth, pressure and temperature reached 11 MPa and 65 °C, respectively. Under these conditions, FeCO3 and CaCO3 localized on sample surfaces. Microscopy was performed to investigate corrosion depth distribution on the surfaces of the samples.

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“…Once the salt scale is formed and attached on the inner surface of pipeline, under-deposit corrosion and crevice corrosion will occur, leading to localized corrosion damage of the pipeline in CO 2 -containing environments (Zhang et al, 2016). A complicated corrosion product layer may be formed owing to the incorporation of Ca 2+ and Mg 2+ cations, which may have improved protectiveness or increased pitting susceptibility (Esmaeely et al, 2013;Tavares et al, 2015). Recently, Shamsa et al (2019) identified the corrosion products on X65 carbon steel as Fe x Ca y CO 3 in the presence of Ca 2+ cations.…”

Section: Water Treatmentmentioning

confidence: 99%

Corrosion Control in CO2 Enhanced Oil Recovery From a Perspective of Multiphase Fluids

2019

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Carbon capture and storage (CCS) combined with CO 2-enhanced oil recovery (EOR), has been recently viewed as an economical and effective method for the reduction of carbon emissions. However, corrosion is a challenging issue in the whole chain process of CO 2-EOR production if water presents and mild steel pipeline is used. In this paper, the corrosion risk of pipeline at different stages of CO 2-EOR production is systematically assessed based on a detailed analysis of the fluid characteristics. According to the fluid state of CO 2 , water and crude oil, current understandings on the corrosion behavior of steel materials in multiphase flow conditions are reviewed. Furthermore, the intermittent water wetting phenomena and the fluid behavior of water droplets or clusters in an electrolyte/non-electrolyte emulsion are correlated with the steel corrosion performance, providing new insights into the corrosion phenomena. Besides application of corrosion resistant materials and corrosion inhibitors, tailoring of processing parameters, such as enhancing the water entrainment, shortening the water contact time, and reducing the solution corrosivity, is highly recommended as an effective method for corrosion control in aggressive CO 2-EOR production conditions. Based on these, some important future research topics on the corrosion in multiphase fluids are suggested.

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Effect of calcium carbonate on low carbon steel corrosion behavior in saline CO2 high pressure environments

Cited by 79 publications

References 29 publications

Effect of Incorporation of Calcium into Iron Carbonate Protective Layers in CO₂ Corrosion of Mild Steel

Effect of Incorporation of Calcium into Iron Carbonate Protective Layers in CO₂ Corrosion of Mild Steel

Pitting Corrosion and Microstructure of J55 Carbon Steel Exposed to CO2/Crude Oil/Brine Solution under 2–15 MPa at 30–80 °C

Corrosion Control in CO2 Enhanced Oil Recovery From a Perspective of Multiphase Fluids

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Effect of calcium carbonate on low carbon steel corrosion behavior in saline CO2 high pressure environments

Cited by 79 publications

References 29 publications

Effect of Incorporation of Calcium into Iron Carbonate Protective Layers in CO2 Corrosion of Mild Steel

Effect of Incorporation of Calcium into Iron Carbonate Protective Layers in CO2 Corrosion of Mild Steel

Pitting Corrosion and Microstructure of J55 Carbon Steel Exposed to CO2/Crude Oil/Brine Solution under 2–15 MPa at 30–80 °C

Corrosion Control in CO2 Enhanced Oil Recovery From a Perspective of Multiphase Fluids

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Effect of Incorporation of Calcium into Iron Carbonate Protective Layers in CO₂ Corrosion of Mild Steel

Effect of Incorporation of Calcium into Iron Carbonate Protective Layers in CO₂ Corrosion of Mild Steel