Effect of Corrosion on Hydrocarbon Pipelines T (original) (raw)
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PIPELINE CORROSION CONTROL IN OIL AND GAS INDUSTRY: A CASE STUDY OF NNPC/PPMC SYSTEM 2A PIPELINE
Corrosion in pipelines is one of the major challenges faced by oil and gas industries all over the world. This has made corrosion control or management a major factor to consider before setting up any industry that will transport products via pipelines. In this study the types of corrosion found on system 2A pipeline were; pitting, microbial, sulfide-stress cracking, hydrogen-stress cracking and hydrogen-induced cracking and these were caused by poor maintenance of the pipeline system, severe mutilation of the pipeline coatings, substrates due to vandalization and coating failures. The data from cathodic protection control method from Nigeria National Petroleum Corporation (NNPC)/ Pipeline and Product Marketing Company (PPMC) for system 2A line was analyzed and it was deduced that about 10.3km of the pipeline was well protected and possibly fit for use and about 62.7km is experiencing under protection which means corrosion is predicted to take place in that segment in a short time and finally about 16km of the pipeline is experiencing corrosion. From the results obtained, it can be deduced that the use of cathodic protection technique as a method of controlling corrosion in oil and gas pipelines is effective and efficient when compared to other methods and thus constant monitoring is needed to achieve optimum efficiency.
Key issues related to modelling of internal corrosion of oil and gas pipelines – A review
The state-of-the-art in modelling of internal corrosion of oil and gas pipelines made from carbon steel is reviewed. The review covers the effects of: electrochemistry, water chemistry, formation of protective scales and scales, temperature, flow, steel, inhibition, water condensation, glycol/methanol and localized attack. Various mathematical modelling strategies are discussed.
An investigation on corrosion protection layers in pipelines transporting hydro.PDF
Chemical reactions between carbon steel, water and chemical species produce corrosion layers (scales) on the internal surface of pipelines transporting hydrocarbons. Scales act as a diffusion barrier and prevent the progress of corrosion, a dangerous failure initiator. The protective film (10-100 μm thickness) can be removed locally by the action of the internal flow, or by other mechanisms. Adhesion with the substrate and the failure modes of the corrosion layer can be tested by indentation. Some results are presented of experiments performed on specimens with scales grown in a controlled environment.
Journal of Natural Gas Science and Engineeringning , 2022
This paper presents an updated review of the external corrosion and failure mechanisms of buried natural gas and oil pipelines. Various forms of external corrosion and failure mechanisms such as hydrogen-induced cracking (HIC), hydrogen embrittlement (HE), corrosion fatigue (CF), stress corrosion cracking (SCC) and microbiologically influenced corrosion (MIC) for oil and gas pipelines are thoroughly reviewed. The factors influencing external corrosion and possible forms of environment-assisted cracking (EAC) of pipeline steels in the soil are also reviewed and analyzed in depth. In addition, the existing monitoring tools for the external corrosion assessment and the models for corrosion prevention and prediction, failure occurrence, and remaining life of oil and gas pipelines, are analyzed. Moreover, the articles on external corrosion management, reliability-based models, risk-based models, and integrity assessment including machine learning and fuzzy logic approaches, are also reviewed. The conclusions and recommendations for future research in the prevention and prediction of external corrosion are presented at the end.
Materials Sciences and Applications, 2015
In this paper, the corrosion of steel pipelines transporting hydrocarbon condensed products was studied. Different activities of sampling and analysis were carried out to diagnose the failure causes and to establish a control system for the corrosion problem. The combination of three types of corrosion, including erosion corrosion, galvanic corrosion and microbiologically induced corrosion, was synthetically considered. A serial of experiments were designed to research those types of corrosion. This type of failure was observed in characteristics sites of the pipeline, mainly in direction changes and welding joints. Additionally, localized corrosion was observed in the inner steel wall and distributed along the pipeline, although a tendency was not detected.
Investigation of Corrosion of the Pipeline Using TOEFLT in Iran Refinery
Corrosion, from long time before was a greatest problem in oil and gas industry and experts have always tried to combat this major problem. This has been given to the corrosion and inspection in oil and gas industry. Corrosion in oil and gas wells has the electrochemical mechanism, When the system reaches a temperature below the dew point, moisture is converted to liquid and many droplets occurs on the pipe's wall. In the electrochemical reaction, water plays role of the electrolyte. The water that creates was not corrosion by itself. When the acidic gases such as H 2 S and CO 2 are dissolved in water create an acidic environment which in the vicinity of the steel will cause severe corrosion. Sometimes in oil wells, oxygen is one of the corrosive gases too. In the oil and gas industries, corrosion may be localized or uniform. Localized corrosion, can be create under the insulators, sediment and bacteria, was 10 to 100 times faster than uniform corrosion lead to destruction and there are many costs and risks associated with it.
International Journal of Scientific and Technology Research, 2012
In order to control the corrosion in pipelines, it is important to understand the underlying corrosion mechanisms and prediction of it’s initiation and means of mitigation. This paper reviews the electrochemistry of corrosion, it’s kinetics and thermodynamic nature, with respect to CO2 and H2S effects in propagating corrosion in oil and gas pipeline system. The phenomenon of polarization and it’s importance in the mitigation of corrosion processes was highlighted in relation to it’s mechanisms. Several principles and models used in predicting and evaluating corrosion kinetics were reviewed emphasizing their applicability in the oil and gas pipeline system. Scale formation on metal surface plays a prominent role in the rate of corrosion propagation making the process more complex, hence the mathematical models to extract the parameters which determine the effect of scale formation were appraised
Corrosion of industrial gas pipelines under the action of formation waters
Scientific journal of the Ternopil national technical university, 2019
The state of pipeline after the long time of operation is studied. Major factors are determined, influencing nature and rate of the passage of the processes of the internal corrosion of pipelinespresence of perceptible mechanical stresses, chemical composition and the motion of corrosive environment. The results obtained allow a more accurate and accurate prediction of the life and residual life of industrial pipelines, taking into account the influence of mechanical and corrosion factors.
Investigation of Corrosion Induced Degradation in Oil Pipelines
https://www.ijrrjournal.com/IJRR\_Vol.6\_Issue.6\_June2019/Abstract\_IJRR0052.html, 2019
Corrosion has been identified as a major concern in the oil and gas industry. To this end, the study investigated the corrosion induced degradation in oil pipelines within the South-South geo-political region of Nigeria. To achieve this, Direct Field Assessment Method (DFAM) was used to obtain field data because it helps ascertain which corrosion type prevails in the selected regions, since pipelines are susceptible to various kinds of corrosion depending on the potential difference between the pipe and the ground surface within a corrosive environment. The reliability and the failure rate of these pipelines in the Niger Delta regions due to corrosion were determined. Results reveal that 70.83% of the pipeline corrosion that occurs in the South-South geo-political region of Nigeria from 1999-2015 is due to Stress Corrosion Cracking (SCC) and that there is a seemingly correlation between the 3 rd party activity (vandalism) and corrosion. This is because the areas with higher 3 rd party activity have corresponding higher failure rate and corrosion occurrence. However, despite the effect of 3 rd party activities and corrosion activities, the reliability result suggests that the oil pipelines are still within their useful life stage.
Effect of oil in multiphase flow on corrosion product film in large horizontal pipeline
Materials and Corrosion, 2000
The properties of corrosion product film formed on carbon steel pipelines under saltwater-oil-CO 2 multiphase flow are examined by AC impedance methods. Experiments are performed in a 101.6 cm I.D., 10 m long pipeline. Experimental results show that there are two reactions on the steel surface in saltwater-oil mixture. One is charge transfer, and the other is diffusion. By calculation of charge transfer resistance, R t , and Warburg impedance coefficient, r, it is found that, R t in saltwater-oil mixture is much higher than that in saltwater. In saltwater-oil mixture, R t and r increase with immersion time. It is suggested that the porous corrosion film occurs on the surface of the steel, and that the film becomes compact when the immersion time increases. The longer the exposure time, the more compact the film, resulting in that the corrosion rate becomes lower. Die Eigenschaften des Korrosionsproduktfilmes, der sich an Rohrleitungen aus unlegiertem Stahl in Salzwasser-O È l-CO 2-Mehrphasenstro Èmungen bildet, wurde mit Hilfe von AC Impedanz-Methoden untersucht. Die Versuche erfolgten in einer 10 m langen Rohrleitung mit einem Innendurchmesser von 101,6 mm. Die experimentellen Ergebnisse zeigen, daû es auf der Stahloberfla Èche in der Salzwasser-O È l-Mischung zwei Reaktionen gibt: den Ladungstransport und die Diffusion. Durch Berechnung des Ladungstransportwiderstandes, R t , und des Warburg-Impedanzkoeffizienten, r, wurde festgestellt, daû R t in der Salzwasser-O È l-Mischung wesentlich ho Èher ist als im Salzwasser. In der Salzwasser-O È l-Mischung steigen R t und r mit der Tauchdauer an. Es wird angenommen, daû sich der auf der Stahloberfla Èche bildende poro Èse Korrosionsfilm mit zunehmender Tauchdauer verdichtet. Je la Ènger die Auslagerungszeit umso kompakter wird der Film, was zu einer verminderten Korrosionsgeschwindigkeit fu Èhrt.