scholarly journals Corrosion Rate of Carbon Steel A106 Gr B in Amine-CO2 Contained Solutions

2021 ◽  
Vol 3 (1) ◽  
pp. 1-8
Author(s):  
Yuli Asmara ◽  
Tedi Kurniawan ◽  
Kushendarsyah Saptaji
Keyword(s):  
Carbon Steel ◽  
Corrosion Rate ◽  
Oil And Gas ◽  
Caustic Solution ◽  
Co2 Corrosion ◽  
Co2 Gas ◽  
Linear Polarization Resistance ◽  
Reduce Risk ◽  
Carbon Dioxide Co2 ◽  
Static Conditions

Carbon dioxide (CO2) is one of the corrosive element which exists in oil and gas industries. To prevent CO2 corrosion on carbon steel pipelines, amine-base solvent and caustic solutions are commonly applied. Accordingly, effectiveness of amine base solvent and caustic solutions to reduce risk of corrosion becomes key parameters in determining service lifetime of pipelines made of carbon steel. In this research, the corrosion rate of carbon steel A106 Gr B in amine solutions combined with saturated CO2 gas and caustic solution was studied. The experiments were carried out in static conditions and the Linear Polarization Resistance (LPR) technique was used to measure the corrosion rate (as per ASTM G 5-94). It was found that the corrosion rate in the amine-based solution had shown remarkable results. Somehow, the corrosion rate in an amine-based solvent containing saturated CO2 gas has increased to 200%. The temperature increment to 50°C from room temperature has also increased the corrosion rate. Meanwhile, the caustic addition in amine solution has reduced the corrosion rate of carbon steel.

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 Corrosion Investigation of Commercially Available Linepipe Steel in CO2 Environment

2018 ◽  
Vol 7 (3.32) ◽  
pp. 15
Author(s):  
Muhammad Haris ◽  
Saeid Kakooei ◽  
Mokhtar Che Ismail
Keyword(s):  
Carbon Steel ◽  
Corrosion Rate ◽  
Oil And Gas ◽  
Corrosion Behaviour ◽  
Complex Problem ◽  
Gas Production ◽  
Co2 Corrosion ◽  
Oil And Gas Production ◽  
The Difference ◽  
Co2 Environment

CO2 corrosion has been the most prevalent form of corrosion and is considered as a complex problem in oil and gas production industries. The CO2 in presence of water causes sweet corrosion that is responsible for failure of pipeline during transportation of Oil and Gas. This work studies the corrosion behaviour of carbon steel specimens in CO2 environment at different temperatures but at constant pressure. The effect of CO2 on Carbon Steel specimens (X65, A106) were studied in simulated solution of 3 wt.% NaCl. The specimens were immersed into the CO2 containing solution for 48 hours and corrosion behaviour was investigated by using electrochemical test like Linear Polarization Resistance and Tafel plot. The results indicate that the temperature has an important effect of corrosion rate of carbon Steel in CO2 environment. Corrosion rate of 1.5-2 mm/yr was reported for both steels at lower temperature while at higher temperature the difference can be observed due to difference in protective nature of steels. Similar Corrosion rate around 1.5 -2 mm/yr was observed at 25°C for both A106 and X65 while at 50°C and 75°C the corrosion rate varies significantly 1.5-3 mm/yr and 3.5-6 mm/yr.  

scholarly journals The Roles of H2S Gas in Behavior of Carbon Steel Corrosion in Oil and Gas Environment: A Review

2018 ◽  
Vol 7 (1) ◽  
pp. 37 ◽  
Author(s):  
Yuli Panca Asmara
Keyword(s):  
Carbon Steel ◽  
Oil And Gas ◽  
Chemical Properties ◽  
Steel Corrosion ◽  
Carbon Steels ◽  
Corrosion Mechanism ◽  
Gas Reservoir ◽  
H2s Corrosion ◽  
Carbon Dioxide Co2 ◽  
Oil And Gas Reservoir

Hydrogen sulfide (H2S) is the most dangerous element which exists in oil and gas reservoir. H2S acidifies water which causes pitting corrosion to carbon steel pipelines. Corrosion reaction will increase fast when it combines with oxygen and carbon dioxide (CO2). Thus, they can significantly reduce service life of transportation pipelines and processing facilities in oil and gas industries. Understanding corrosion mechanism of H2S is crucial to study since many severe deterioration of carbon steels pipelines found in oil and gas industries facilities. To investigate H2S corrosion accurately, it requires studying physical, electrical and chemical properties of the environment. This paper concentrates, especially, on carbon steel corrosion caused by H2S gas. How this gas reacts with carbon steel in oil and gas reservoir is also discussed. This paper also reviews the developments of corrosion prediction software of H2S corrosion. The corrosion mechanism of H2S combined with CO2 gas is also in focused. 

A Highly Effective Corrosion Inhibitor by Use of Gemini Imidazoline

SPE Journal ◽  
2016 ◽  
Vol 21 (05) ◽  
pp. 1743-1746 ◽  
Author(s):  
Jiang Yang ◽  
Liyang Gao ◽  
Xuan Liu ◽  
Wenlong Qin ◽  
Chengxian Yin ◽  
...  
Keyword(s):  
Corrosion Inhibitor ◽  
Corrosion Inhibition ◽  
Corrosion Inhibitors ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Molar Ratio ◽  
Co2 Corrosion ◽  
Highly Effective ◽  
Carbon Dioxide Co2 ◽  
Triethylene Tetramine

Summary Corrosion inhibitors are widely used to control corrosion under the sweet and sour environments in the oil and gas industry. More effective and environmentally friendly corrosion inhibitors need to be developed. This paper studies a new gemini imidazoline (GIM) corrosion inhibitor, in which two hydrocarbon chains and two head groups are linked by a rigid spacer. The GIM was synthesized through the reaction of oleic acid with triethylene tetramine at 2:1 molar ratio. The performance of the GIM on inhibition of carbon dioxide (CO2) corrosion was evaluated by linear polarization resistance in sparged-beaker testing. Rotating-wheel testing was performed to evaluate the film persistency of the test inhibitors. The results showed that corrosion inhibition of the GIM was more effective at lower concentration than that of conventional imidazoline. The mixture of GIM and fatty acid also showed better film persistency than conventional imidazoline. The emulsion tendency of the GIM was less than that of conventional imidazoline. The mechanism of the highly effective GIM was studied. It showed that GIM has much-higher surface activity than conventional imidazoline. The critical micelle concentration (CMC) of GIM is several times lower than that of conventional imidazoline. Hence, the new GIM corrosion inhibitor and its mixture give more-effective corrosion inhibition at low concentration; there is also a lesser environmental effect.

Role of Asphaltenes in Inhibiting Corrosion and Altering the Wettability of the Steel Surface

CORROSION ◽  
2011 ◽  
Vol 67 (10) ◽  
pp. 105006-105006-11 ◽  
Author(s):  
P. Ajmera ◽  
W. Robbins ◽  
S. Richter ◽  
S. Nešić
Keyword(s):  
Carbon Steel ◽  
Steel Surface ◽  
Protective Layer ◽  
Contact Angles ◽  
Co2 Corrosion ◽  
Water Contact ◽  
Internal Corrosion ◽  
Corrosion Rates ◽  
Mechanism Of Inhibition ◽  
Carbon Dioxide Co2

Abstract Asphaltenes (heptane insolubles) from a variety of crude oils have been identified previously as contributors to inhibition of internal corrosion of mild steel pipelines. However, the mechanism of inhibition is unknown. To explore the mechanism, carbon dioxide (CO2) corrosion rates and wettability (oil/water contact angles) have been measured using Arab Heavy crude oil and its asphaltenes. Inhibition of CO2 corrosion rates for carbon steel was measured using electrochemical methods in a glass cell; wettability was assessed using contact angle measurements in a multiphase goniometer. The phase behavior of asphaltenes in corrosion and wetting was evaluated in the crude, toluene (C7H8), or heptol (70:30 mixture of heptane [C7H16] and toluene). Inhibition on steel exposed to a hydrocarbon phase increased with the concentration of asphaltenes in toluene. Inhibition by asphaltenes dissolved in toluene appears to be more effective than in the whole crude, at equivalent concentrations of asphaltenes. At 5 wt% in toluene, asphaltenes form a strong protective layer on the carbon steel surface, which reduces the corrosion rate and makes the surface hydrophobic. When the solubility of the oil is altered to the point where asphaltenes start to flocculate, it enhances the corrosion inhibition greatly. However, the inhibition is not as persistent as for the fully dissolved asphaltenes, and the surface needs to be periodically wetted with the oil phase to maintain the protection.

scholarly journals Effect of pH in SRB (ATCC 7757) Growth for Oil and Gas API X 70 Steel Pipes

2019 ◽  
Vol 3 (1) ◽  
pp. 30-36
Author(s):  
Zuraini Din ◽  
Keyword(s):  
Carbon Steel ◽  
Corrosion Rate ◽  
Oil And Gas ◽  
Desulfovibrio Desulfuricans ◽  
Oil And Gas Industry ◽  
Gas Industry ◽  
Corrosion Failure ◽  
Bacteria Growth ◽  
Steel Pipes ◽  
Metal Pipes

In the oil and gas industry, pipeline is the major transportation medium to deliver the products. According to [1] containment of pipeline loss to indicate that corrosion has been found to be the most predominant cause for failures of buried metal pipes. MIC has been identified as one of the major causes of underground pipeline corrosion failure and Sulphate Reducing Bacteria (SRB) are the main reason causing MIC, by accelerating corrosion rate. The objectives of this study is to study the SRB growth, Desulfovibrio desulfuricans ATCC 7757 due to pH and determine the optimum value controlling the bacteria growth on the internal pipe of carbon steel grade API X70. The result shows that the optimum SRB growth is at range pH 5-5 to 6.5 and the exposure time of 7 to 14 days. At pH 6.5 the maximum corrosion rate is 1.056 mm/year. Corrosion phenomena on carbon steel in the study proven had influence by pH and time. From this result pitting corrosion strongly attack at carbon steel pipe. In the future project, it is recommended to study the effect of different pipe location for example the pipeline under seawater.

Velocity Guidelines for Avoiding Erosion-Corrosion Damage in Sweet Production With Sand

1998 ◽  
Vol 120 (1) ◽  
pp. 78-83 ◽  
Author(s):  
J. R. Shadley ◽  
E. F. Rybicki ◽  
S. A. Shirazi ◽  
E. Dayalan
Keyword(s):  
Carbon Steel ◽  
Oil And Gas ◽  
Corrosion Damage ◽  
Gas Production ◽  
Metal Loss ◽  
Co2 Corrosion ◽  
Oil And Gas Production ◽  
Erosion Corrosion ◽  
Steel Piping ◽  
Loss Rates

CO2 corrosion in carbon steel piping systems can be severe depending on a number of factors including CO2 content, water chemistry, temperature, and percent water cut. For many oil and gas production conditions, corrosion products can form a protective scale on interior surfaces of the piping. In these situations, metal loss rates can reduce to below design allowances. But, if sand is entrained in the flow, sand particles impinging on pipe surfaces can remove the scale or prevent it from forming at localized areas of particle impingement. This process is referred to as “erosion-corrosion” and can lead to high metal loss rates. In some cases, penetration rates can be extremely high due to pitting. This paper combines laboratory test data on erosion-corrosion with an erosion prediction computational model to compute flow velocity limits (“threshold velocities”) for avoiding erosion-corrosion in carbon steel piping. Also discussed is how threshold velocities can be shifted upward by using a corrosion inhibitor.

scholarly journals Comparison of Corrosion Rate in the Environment of 10% Acetic Acid solution with different Deflection.

2019 ◽  
Vol 20 (2) ◽  
pp. 84-93
Author(s):  
Nendi Suhendi Syafei ◽  
S S Rizki ◽  
Suryaningsih Suryaningsih ◽  
Darmawan Hidayat
Keyword(s):  
Acetic Acid ◽  
Carbon Steel ◽  
Corrosion Rate ◽  
Oil And Gas ◽  
Acetic Acid Solution ◽  
Oil And Gas Industry ◽  
Steel Pipe ◽  
Gas Industry ◽  
Stress Cracking ◽  
Acid Environment

The oil and gas industry exploration that will generally be followed by corrosive substances including sweet gas (eg H2S and CO2), it will result in corrosion event. The corrosion stress cracking will cause the carbon steel pipe to break so that production oil and gas can be stopped. The research aims in this paper is to analyze the corrosion event of carbon steel pipe in laboratory scale on acid environment with the existence of sweet gas H2O and CO2 by using three points loading method. This research uses carbon steel pipe API 5L-X65 which stay in condensation environment of 1350 ml aquades, 150 ml acetic acid. Based on the figure (5.a) and figure (5.b) that the corrosion rate will increase with increasing exposure time, and the greater the stress that is given, the corrosion rate increases according to the image (6.a) and image (6.b). Whereas based on the results of microstructural tests using optical microscopes, pitting corrosion occurs, and corrosion events  occur are the stress corrosion cracking transgranular and intergranular based on figure 8.  

scholarly journals Analisis Korosi Retak Tegangan pada Pipa Baja Karbon dalam Larutan Asam dan Sweet Gas

2018 ◽  
Vol 3 (1) ◽  
pp. 137
Author(s):  
Nendi Suhendi Syafei ◽  
Darmawan Hidayat ◽  
Bernard Y. Tumbelaka ◽  
Liu Kin Men
Keyword(s):  
Acetic Acid ◽  
Carbon Steel ◽  
Corrosion Rate ◽  
Oil And Gas ◽  
Test Sample ◽  
Ammonia Solution ◽  
Test Results ◽  
Stress Cracking ◽  
Sample Test ◽  
Acid Environment

Pada eksplorasi di industri migas bahwa umumnya akan diikuti dengan zat korosif termasuk sweet gas (misalnya H2S dan CO2), maka akan mengakibatkan terjadinya peristiwa korosi. Bila terjadi peristiwa korosi retak tegangan akan mengakibatkan pipa baja karbon pecah sehingga berdampak produksi migas bisa terhenti. Penelitian ini bertujuan untuk menganalisis peristiwa korosi pipa baja karbon skala laboratorium dalam lingkungan asam dengan adanya sweet gas H2O dan CO2 dengan menggunakan metoda tiga titik pembebanan. Penelitian ini menggunakan bahan pipa baja karbon API 5L-X65 yang berada dalam lingkungan larutan asam asetat dan amoniak, kemudian diisikan sweet gas CO2 dan H2S dalam keadaan jenuh. Berdasarkan hasil uji mikrostruktur dan mikroskop terpolarisasi, terjadi peristiwa korosi retak tegangan, yaitu korosi retak tegangan transgranular dan korosi retak tegangan intergranular. Laju korosi yang terjadi pada sampel uji akan semakin besar, apabila defleksi yang diberikan semakin besar. Dalamnya retakan pada sampel uji akan semakin dalam apabila defleksi yang diberikan semakin besar. Laju korosi pada sampel uji akan semakin besar untuk defleksi yang sama tetapi variasi waktu paparan berbeda.Kata kunci: korosi, retak tegangan, pembebanan tiga titik, sweet gas, pipa baja karbon In industry exploration oil and gas that will generally be followed by corrosive substances including sweet gas (e.g H2S and CO2), then will result in corrosion event. If there is event a corrosion stress cracking will cause the pipe carbon steel to break so that production oil and gas can be stopped. This research aims to analyze the corrosion event of pipe carbon steel in laboratory scale on acid environment with the existence of sweet gas H2O and CO2 by using method three points loading. This research uses pipe carbon steel API 5L-X65 which is in the environment of acetic acid and ammonia solution, then filled with sweet gas CO2 and H2S in saturated state. Based on microstructure and microscope polarized test results, there is a phenomenon corrosion stress cracking, i.e corrosion stress cracking transgranular stress and corrosion stress cracking intergranular. The corrosion rate occurs in test sample test will be greater if deflection to given is greater. Inside crack in test sample test will deeper if deflection to given is greater. The corrosion rate in test sample test will be greater for the same deflection but variation of exposure time is different.Keywords: corrosion, stress cracking, three-point loading, sweet gas, pipe carbon steel

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