scholarly journals Coatings & linings for oil & gas pipelines – the most effective method of corrosion protection for aged pipelines

2020 ◽  
Vol 305 ◽  
pp. 00016
Author(s):  
Ion Antonio Tache ◽  
Carmen Tache
Keyword(s):  
Corrosion Protection ◽  
Oil And Gas ◽  
Control Program ◽  
Corrosion Control ◽  
Gas Pipelines ◽  
Internal Corrosion ◽  
Below Ground ◽  
Infrastructure Failure ◽  
Water Gas

Pipelines around the world are in danger due to ageing, deposits and corrosion. Leaky fittings and cracks are an environmental hazard and cause the loss of valuable resources such as drinking water, gas, or oil. The pipelines may get corroded internally due to the nature of the fluid flowing inside and due to various other factors. The environmental and societal impact of infrastructure failure is a primary consideration for today’s pipeline operators. Without implementing safety measures and having a corrosion control program, corrosion makes transporting hazardous material unsafe. There are many methods NACE (National Association of Corrosion Engineers) recommends as part of a successful corrosion control program to protect oil and gas pipelines. Coatings and linings applied to pipelines whether above or below ground and often used in combination with cathodic protection. Different linings may be used for internal corrosion protection, provided the lining material does not degrade following long-term exposure to the transported fluid, at the pipeline pressure and temperature conditions.

Hydrogen Assisted Cracking Failures of Girth Welds in Oil and Gas Pipelines

2012 ◽  
Author(s):  
W. E. Amend ◽  
G. T. Quickel ◽  
W. A. Bruce ◽  
J. A. Beavers
Keyword(s):  
Oil And Gas ◽  
The United States ◽  
Gas Pipelines ◽  
Hydrogen Cracking ◽  
Oil And Gas Pipelines ◽  
Hydrogen Assisted Cracking ◽  
Cause Of Failure ◽  
New Construction ◽  
Below Ground ◽  
Girth Welds

There are more than 2.5 million miles of oil and gas pipelines in the United States, totaling over 330 million girth welds below ground. During construction, girth welds are susceptible to the formation of various defects, one of which is hydrogen-assisted cracks. The synergistic impact of tensile stress, a susceptible microstructure, and atomic hydrogen can lead to hydrogen embrittlement and the formation of hydrogen cracks. This paper reviews hydrogen cracking of girth welds in carbon steel pipelines made during new construction and provides examples involving hydrogen cracking in which failure analysis techniques were used to establish the metallurgical cause of failure.

Flow Assurance of Wet Gas Pipelines From a Corrosion Viewpoint

2002 ◽  
Author(s):  
Rolf Nyborg ◽  
Arne Dugstad
Keyword(s):  
Carbon Steel ◽  
Oil And Gas ◽  
Prediction Models ◽  
Process Equipment ◽  
Corrosion Control ◽  
Internal Corrosion ◽  
Application Range ◽  
Wet Gas ◽  
Offshore Oil And Gas ◽  
Stabilization Technique

In many offshore oil and gas projects under development, the pipeline costs are a considerable part of the investment and can become prohibitively high if the corrosivity of the fluid necessitates the use of corrosion resistant alloys instead of carbon steel. Development of more robust and reliable methods for internal corrosion control can increase the application range of carbon steel and therefore have a large economic impact. Corrosion control of carbon steel pipelines has traditionally often been managed by the use of corrosion inhibitors. The pH stabilization technique has been successfully used for corrosion control of several large wet gas condensate pipelines in the last few years. Precipitation of scale and salts in the pipeline and process equipment creates further challenges when formation water is produced. Different corrosion prediction models are used in the industry to assess the corrosivity of the transported fluid. An overview of the present models is given together with a link to fluid flow modeling.

Effect of Hydrocarbons on the Internal Corrosion of Oil and Gas Pipelines

CORROSION ◽  
2007 ◽  
Vol 63 (7) ◽  
pp. 704-712 ◽  
Author(s):  
S. Papavinasam ◽  
A. Doiron ◽  
T. Panneerselvam ◽  
R. W. Revie
Keyword(s):  
Oil And Gas ◽  
Operating Conditions ◽  
Gas Pipelines ◽  
Internal Corrosion ◽  
Oil In Water ◽  
Oil And Gas Pipelines ◽  
Water Wettability

Abstract Under certain conditions, hydrocarbons may alter the internal corrosion conditions of oil and gas pipelines. In this paper, the effects of hydrocarbons on corrosion have been predicted based on the type of emulsion (i.e., water-in-oil or oil-in-water), wettability (oil-wet, water-wet, or mixed-wet), and corrosiveness of brine in the presence of hydrocarbons. Laboratory methodologies have been developed to determine wettability and to identify the type of emulsion under pipeline operating conditions. Using these methodologies, the wettability and the type of emulsion have been determined for 14 hydrocarbons obtained from operating pipelines. The corrosiveness of brine in the presence of hydrocarbons also has been determined using rotating cage experiments.

Reliability Analysis and Performance Predictions of Aged Pipelines Subjected to Internal Corrosion: A Markov Modelling Technique

2015 ◽  
Author(s):  
Chinedu I. Ossai ◽  
Brian Boswell ◽  
Ian J. Davies
Keyword(s):  
Oil And Gas ◽  
Integrated Management ◽  
Remaining Useful Life ◽  
Gas Pipelines ◽  
Markov Modelling ◽  
Internal Corrosion ◽  
Performance Predictions ◽  
Oil And Gas Pipelines ◽  
And Performance ◽  
Life Predictions

To maintain the integrity of corroded oil and gas pipelines, the reliability at times of exposure over the lifecycle duration need to be understood. This paper describes the procedures for predicting the performance of internally corroded oil and gas pipelines using a probabilistic-based Markovian process. The Pipeline Corrosivity Index (PCI), which is expressed as a function of the retained pipe-wall thickness was used to describe the condition of the corroded pipelines at exposure durations for low, moderate, high and severe corrosion rates. The time variation of the predicted Pipeline Corrosivity Index (PCI) was compared with field measured Pipeline Corrosivity Indexes (PCIs) of corroded API X52 grade pipelines and the results indicate that the model developed in this research is viable for integrated management of aged corroded pipelines and remaining useful life predictions.

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