Carbon Dioxide Corrosion Inhibitors Research Articles

New Developments in Inhibition of the Sweet Environment in a Variety of Corrosive Media: A Review

This paper aims to look at how pipeline steel and crude oil storage tanks resist corrosion in aqueous carbon dioxide (CO2) environments. To this aim, we have studied different inhibitors, particularly the heterocyclic inhibitor, which is used to prevent mild steel corrosion in various situations. On mild steel, the corrosion-prevention mechanism of heterocyclic inhibitors is also investigated. CO2 corrosion is the most frequent and dreaded type of corrosion in the oil and gas industry, and corrosion inhibitors are the most effective way to fight CO2 corrosion in mild steel. Nonetheless, continual exposure to pollutants and corrosion causes such as sulfur and chromate on pipeline surfaces is unavoidable. Because of their toxicity, commercial corrosion inhibitors are being used less frequently to protect the environment. As a result of the advent of "green" chemistry and fruit waste, both of which have been demonstrated to be efficient corrosion inhibitors, plant extracts have become popular. This research aims to compile a list of carbon dioxide corrosion inhibitors that have been proved to protect against this type of attack. The material on this page is relevant to the gas and oil industries, which rely on steel pipelines and crude oil tanks to transport oil and gas products. This study will also help develop better CO2 corrosion inhibitors for the gas and oil industries.

The Synthesis and Application of Salts and Complexes on the Basis of Petroleum Acid Allyl Ester as Carbon Dioxide Corrosion Inhibitors

The esterification reaction of natural petroleum acids with allyl alcohol in the presence of N-methylpyrrolidone hydrogen sulfate, an ionic liquid, has been studied. An allyl ester of natural petroleum acid has been obtained, on the basis of which nitro derivatives as well as salts and complexes of petroleum acids have been synthesized and tested as inhibitors of acid corrosion. It has been shown that a potassium salt and a monoethanolamine complex obtained on the basis of the nitroproduct of natural petroleum acid have the highest protective effect (98.4 and 98.9%, respectively) at a concentration of 300 ppm and can be proposed as CO2 corrosion inhibitors.

Universalism of Hydrogen Sulfide and Carbon Dioxide Corrosion Inhibitors in Conditions of Oil Production and Processing

Qualitative criteria for the universalism of hydrogen sulfide and carbon dioxide corrosion inhibitors and their quantitative indices for the corrosion of carbon steel are proposed. They include the maximum value of the total corrosion rate in the presence of H2S and CO2 and with simultaneous limitation of the concentration of the inhibitors themselves. The criteria define a minimum reduction in hydrogenation of steel, suppression of hydrogen diffusion into the metal, contain requirements for the bactericidal ability of inhibitors by limiting the number of cells of sulfate-reducing bacteria and producing hydrogen sulfide, and the requirements for their biodegradability. It is shown that a number of domestic inhibitors of hydrogen sulfide and carbon dioxide corrosion of the new generation of the INKORGAZ series fully satisfy the proposed criteria for universalism.

Carbon Dioxide Corrosion Inhibitors: A review

This article intends to summarize the corrosion inhibition of pipeline steels in aqueous carbon dioxide ( $$\hbox {CO}_{2})$$ environments. The emphasis is on various inhibitors, especially imidazolines used to mitigate mild steel corrosion under various conditions. The most predominant and feared type of corrosion attack in oil and gas industries is caused by $$\hbox {CO}_{2}$$ . The application of corrosion inhibitors is considered the most suitable method of combating $$\hbox {CO}_{2 }$$ corrosion of steel pipelines. The prime objective of this work is to summarize carbon dioxide corrosion inhibitors so far tested and reported against this type of attack. The information presented in this article is of significance for oil and gas industries that use steel pipeline for the transportation of oil and gas products. Furthermore, this review would be helpful in designing better inhibitors for the mitigation of $$\hbox {CO}_{2}$$ corrosion in oil and gas industries.

Effect of inhibitors on preferential weld corrosion under sweet conditions

Purpose – The aim of this investigation was to compare the performance of three typical oil field carbon dioxide corrosion inhibitors in controlling preferential weld corrosion (PWC) of X65 pipeline steel in artificial seawater (3.5 weight per cent) saturated with carbon dioxide at one bar pressure. Design/methodology/approach – A novel rotating cylinder electrode (RCE) apparatus was used to evaluate the effect of flow on the inhibition for the weld metal (WM), heat-affected zone (HAZ) and parent material. To fulfill this objective, the galvanic currents flowing between the weld regions were recorded using parallel zero-resistance ammeters, and the self-corrosion rates of the couples were obtained by linear polarization resistance measurements. Findings – The results showed that when 30 ppm of green oil field inhibitors were present in the service environment, a current reversal took place, resulting in accelerated weld corrosion. At high shear stress, the currents increased and further reversals occurred. The inhibitors were more effective in controlling the self-corrosion rates of the parent material than of the WM and HAZ material. It was concluded that PWC was caused by unstable conditions in which the inhibitor film was selectively disrupted from the WM and HAZ, but remained effective on the parent material. Originality/value – Electrochemical corrosion rate measurements were carried out using an RCE produced from the different regions of the weld. An advantage of using the RCE is that the hydrodynamic conditions are very well defined, and it is feasible to translate the conditions that are known to exist in a production pipeline to those used in laboratory tests.

Comparison of the protective efficiency of corrosion inhibitors in oilfield pipelines

This paper is the final article in the series published by the International Journal of Corrosion and Scale Inhibition. The series is dedicated to efficiency evaluation of protection provided by carbon dioxide corrosion inhibitors at oilfield pipelines in West Siberia where the inhibitor selection and efficiency supervision system issues are common in field-wide applications. Laboratory testing is an easy way to properly select corrosion inhibitors by performing a comprehensive set of procedures instead of making a couple of isolated tests trying to simulate most obvious corrosion environment features. Key terms: oilfield pipelines, corrosion, inhibitors, testing techniques.

Performance Evaluation of the Carbon Dioxide Corrosion Inhibitor IMC-1

The carbon dioxide corrosion inhibitor IMC-1 was composed by caprylic acid amide polyoxyethylene ethers (n=4-5) and a small amount of the TX-10(5%). When the concentration was 200 mg/L, N80 steel corrosion rate was less than 0.125mm/a. With the CO2partial pressure and temperature increased, N80 steel corrosion rate was decreased. From the electrochemical polarization curve, the adding corrosion inhibitor prevented the electrode reaction. The corrosion inhibitor IMC-1 was anodic inhibitor.

Rare Earth 4-Hydroxycinnamate Compounds as Carbon Dioxide Corrosion Inhibitors for Steel in Sodium Chloride Solution

A series of rare earth 4-hydroxycinnamate compounds including Ce(4OHCin)3, La(4OHCin)3, and Pr(4OHCin)3 has been synthesized and evaluated as novel inhibitors for carbon dioxide corrosion of steel in CO2-saturated sodium chloride solutions. Electrochemical measurements and surface analysis have shown that these REM(4OHCin)3 compounds effectively inhibited CO2 corrosion by forming protective inhibiting deposits that shut down the active electrochemical corrosion sites on the steel surface. Inhibition efficiency was found to increase in the order Ce(4OHCin)3 < La(4OHCin)3 < Pr(4OHCin)3 and with increase in inhibitor concentration up to 0.63 mM. Detailed insights into corrosion inhibition mechanism of these compounds in carbon dioxide environment are also provided.

Laboratory assessment of the efficiency of corrosion inhibitors at oilfield pipelines of the West Siberia region V. Rotating cylinder and cage

This paper continues a series of publications dedicated to lab assessment of efficiency of carbon dioxide corrosion inhibitors at the oilfield pipelines of West Siberia region. It reviews the results of tests performed on “rotating cylinder” and “rotating cage” facilities. The article reviews the effect of temperature, specimen surface condition, flow velocity, presence of a hydrocarbon phase and inhibitor concentration on corrosion rate and protective properties of a wide range of commercial inhibitors. Recommendations on specific inhibitor test conditions are given to assess their applicability for protection of water lines, oil pipelines with low watercut and oil pipelines with high product watercut.

Laboratory assessment of the efficiency of corrosion inhibitors at oilfield pipelines of the West Siberia region IV. Tests in a flow recirculation loop

This article continues a series of publications dedicated to lab assessment of the efficiency of carbon dioxide corrosion inhibitors at oilfield pipelines of the West Siberia region. Results of the test in a flow recirculation loop are reviewed herein. The paper highlights the effect of temperature, test duration, oxygen concentration, condition of specimen surface, flow velocity, presence of hydrocarbon phase and inhibitor concentration on the corrosion rate and protective properties of a wide range of commercial inhibitors. The paper gives recommendations on specific conditions for testing inhibitors to assess their applicability for the protection of water lines, oil pipelines with low watercut and oil pipelines with high product watercut.

Laboratory assessment of corrosion inhibitors effectiveness at oilfield pipelines of West Siberian region. III. Bubble test

This article continues a series of publications dedicated to lab assessment of carbon dioxide corrosion inhibitors efficiency at the oilfield pipelines of West Siberian region. Results of the bubble test are reviewed. The effect of temperature, test duration, condition of the specimen surface, the presence of a hydrocarbon phase, and concentration of inhibitors on corrosion rate and protective properties of a wide range of commercial inhibitors are analyzed. Recommendations on specific test conditions to assess the applicability of inhibitors for protection of water lines and oil pipelines with low watercut are given.

Laboratory assessment of corrosion inhibitors efficiency at oilfield pipelines of West Siberia region II. Tests in a U-cell

This paper is a continuation of a series of publications related to laboratory assessment of the performance of carbon dioxide corrosion inhibitors for oilfield pipelines in the West Siberian region. The test results obtained in U-shaped glass cells are considered. The effects of temperature, carbon dioxide content, test duration, specimen surface condition, presence and volume of a hydrocarbon phase, and inhibitor concentration on the corrosion kinetics and protective properties of a wide range of industrial inhibitors are analyzed. Recommendations are given on specific inhibitor test conditions to be used for assessment of inhibitor suitability for the protection of water pipelines and oil pipelines with low watercut.

Alteration of Wettability of Corroding Carbon Steel Surface by Carbon Dioxide Corrosion Inhibitors—Effect on Carbon Dioxide Corrosion Rate and Contact Angle

Abstract The wettability of the steel surface is an important factor co-determining the risk of corrosion in multiphase pipelines for transportation of oil and gas. The effect of carbon dioxide (CO2) corrosion inhibitors on the wettability of carbon steel was investigated in the present paper. Also investigated was the effect of oil on the performance of these inhibitors. Three inhibitors were investigated. Two of them were commercial inhibitor-based chemicals: an oleic imidazoline salt (OI) and a phosphate ester (PE). The third was cetyltrimethylammonium bromide (CTAB), a well-characterized quaternary ammonium compound. A refined, low-aromatic oil product was used in the tests. The wettability of the corroding carbon steel surface was studied by contact angle measurements (25°C, 1 bar CO2, 3 wt% sodium chloride [NaCl]). Both oil-in-water and water-in-oil experiments were performed. The effect of the inhibitor/oil interactions were also studied in CO2 corrosion tests where the steel specimens were alterna...

Testing of Carbon Dioxide Corrosion Inhibitor Performance at High Flow Velocities in Jet Impingement Geometry. Effects of Mass Transfer and Flow Forces

Abstract The performance of three continuous treatment carbon dioxide (CO2) corrosion inhibitor products was tested in an impinging jet apparatus (40°C, CO2 partial pressure 1 bar, pH 5, 3 wt% sodium chloride [NaCl] brine). The objective was to test the performance of the inhibitors at very high flow velocities; the jet flow velocity was varied in the range from 0.5 m/s to 20 m/s. Methods for characterization of mass transfer and calculation of wall shear stress are described. To assess how dissolved oxygen (O2) biased the test results, the dissolved oxygen (O2) concentration was intentionally held within two different ranges: 2 ppb to 4 ppb and 8 ppb to 30 ppb. Since flow velocity and O2 concentration were varied independently, a flow-dependent inhibited corrosion rate observed in the higher O2 concentration range could be attributed to flow-dependent O2 corrosion; the corrosion current was close to the O2 diffusion-limited current. The inhibited corrosion rate was not affected by the flow as long as O2 ...

Effect of Oil-in-Water Emulsions on the Performance of Carbon Dioxide Corrosion Inhibitors

Abstract The effect of oil-in-water emulsions on the performance of four carbon dioxide (CO2) corrosion inhibitors was studied in an impinging jet apparatus. Experimental conditions were 60°C to 90°C, pH 4.5 to 5, 1 bar CO2, 100% to 90% water-cut, and 0.1 wt% to 1 wt% sodium chloride (NaCl). A refined, low-aromatic, white spirit product was used as the oil phase. The jet flow velocities were varied in the range from 0 to 12 m/s. Corresponding wall shear stresses were 0 to 350 Pa. Oil-in-water emulsions were formed by injecting small amounts of oil in the impinging jet stream. This created small amounts of emulsion (on the order of 1 vol% to 2 vol% oil) that broke down in a few hours. Surface active, amphiphilic inhibitor molecules have a high affinity for accumulation at the oil-water interface. The dispersed droplets may constitute a large surface area. When the surface area exceeds 1 m2/L (order of magnitude) the droplets may deplete a significant amount of corrosion inhibitor from the corrosive aqueous...

Eurocorr 2004 – Part 2

(2005). Eurocorr 2004 – Part 2. Corrosion Engineering, Science and Technology: Vol. 40, No. 1, pp. 5-15.

Evaluation of the Effect of Carbon Dioxide Corrosion Inhibitors on Cavitation Damage Caused during the Ultrasound Test

Abstract A test for evaluating oilfield corrosion inhibitors using ultrasound has been developed recently. This paper describes experiments that have been undertaken to try and determine some of th...

A study of the adsorption properties of commercial carbon dioxide corrosion inhibitor formulations

Corrosion rate data for several commercial carbon dioxide corrosion inhibitors have been fitted to the Temkin adsorption isotherm and van't Hoff equation, enabling a determination of the enthalpy of adsorption (ΔHad∘). It has been found that experimentally determined ΔHad∘ values for commercial inhibitor formulations can provide valuable insights into the behaviour of the inherent active components. The temperature sensitivities along with the mechanism of adsorption (physi- or chemisorption) and the minimum concentration required for activity of inhibitors is determinable by this approach. Additionally, FTIR has been used to identify those inhibitors that are tenaciously adsorbed to steel, and suitable for use in batch treatment applications.