scholarly journals COMPARATIVE STUDY AND ANALYSIS OF CARBON STEEL CORROSION IN CO2 SATURATED ENVIRONMENT.

2020 ◽  
Vol 2 (1) ◽  
Keyword(s):  
Weight Loss ◽  
Acetic Acid ◽  
Carbon Steel ◽  
Corrosion Rate ◽  
Comparative Study ◽  
Oil And Gas ◽  
Steel Corrosion ◽  
Gas Production ◽  
High Concentration ◽  
Co2 Environment

Carbon steel is arguably one of the most efficient, reliable and safer kind of steel used in petroleum and gas industry for production, distribution and transmission of products. Acetic acid (HAc), is also one of the impurities in oil and gas during transportation from the well sites to the refineries. It is formed in the formation water, which also present in oil and gas production and transportation processes. Acetic acid aids corrosion in pipelines and as a result causes environmental degradation. It has been observed that high concentration of HAc increases the rate of corrosion of carbon steel in CO2 environment. Corrosion slows down production of oil and gas and thereby reduces revenue. In this work, a comparative study and analysis of carbon steel corrosion in the presence of HAc was carried out at 25oC and 80oC in CO2 saturated environment. Weight loss and surface analysis methods (XRD, EDX and SEM) were used to characterize the corrosion layers of the carbon steel samples at different conditions. The weight loss results show that the corrosion rate increased initially with the increase in the concentration of HAc and attained a maximum, and then gradually decreased. At 25oC with 500ppm of HAc, the corrosion rate is 1.35 mm/yr, and 1.80 mm/yr when 1000ppm of HAc was added to the solution. At 80oC and 500ppm HAc, the corrosion rate was 1.80 mm/yr and 2.70 mm/yr with 1000ppm of HAc. A further increase was observed at 3.45 mm/yr when 2500ppm of HAc was added to the system. This increase in corrosion rate is attributed to increase in temperature as increased temperature increases the rate of all reactions. The XRD analysis confirmed that the iron is formed in the absence of HAc while siderite (FeCO3), which is an ore of iron is observed on the materials with HAc. The SEM and EDX results confirmed that a fairly dense material of FeCO3 was formed in the absence of HAc and the layers became porous on addition of HAc to the solution. Key Words: Corrosion, Acetic acid, Carbon steel, CO2, Environment

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 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

scholarly journals The effect of volatile organic acids and CO2 on the corrosion rate of carbon steel from a Top-of-Line-Corrosion (TLC) perspective

2021 ◽  
Vol 1201 (1) ◽  
pp. 012079
Author(s):  
S B Gjertsen ◽  
A Palencsar ◽  
M Seiersten ◽  
T H Hemmingsen
Keyword(s):  
Carbon Steel ◽  
Corrosion Rate ◽  
Organic Acid ◽  
Carbonic Acid ◽  
Acid Corrosion ◽  
Iron Concentration ◽  
Critical Factor ◽  
Steel Corrosion ◽  
Carbon Steels ◽  
Corrosion Rates

Abstract Models for predicting top-of-line corrosion (TLC) rates on carbon steels are important tools for cost-effectively designing and operating natural gas transportation pipelines. The work presented in this paper is aimed to investigate how the corrosion rates on carbon steel is affected by acids typically present in the transported pipeline fluids. This investigation may contribute to the development of improved models. In a series of experiments, the corrosion rate differences for pure CO2 (carbonic acid) corrosion and pure organic acid corrosion (acetic acid and formic acid) on X65 carbon steel were investigated at starting pH values; 4.5, 5.3, or 6.3. The experiments were conducted in deaerated low-salinity aqueous solutions at atmospheric pressure and temperature of 65 °C. The corrosion rates were evaluated from linear polarization resistance data as well as mass loss and released iron concentration. A correlation between lower pH values and increased corrosion rates was found for the organic acid experiments. However, the pH was not the most critical factor for the rates of carbon steel corrosion in these experiments. The experimental results showed that the type of acid species involved and the concentration of the undissociated acid in the solution influenced the corrosion rates considerably.

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. 

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