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Corrosion Resistance Of Stainless Steel Pipelines In Seawater During Pre-Comissioning Phase

Picture for Corrosion Resistance Of Stainless Steel Pipelines In Seawater During Pre-Comissioning Phase
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In Oil & Gas industries, Cr-Ni-Mo stainless steels and Ni-Cr-Mo alloys with Pitting Resistance Equivalent Number (PREN) lower than 40 could be selected for Rigid Production subsea risers, pipeline, and associated structure’s piping, according to a CO2/H2S corrosion assessment that considers all steady and transient conditions foreseen to operate the reservoir.


However, there are frequently some localized corrosion concerns for these materials during the installation and pre-commissioning of the line, when the internal surface of the line could be in contact temporarily with untreated seawater. These concerns systematically lead to discard the selection of these materials and to select, for conservative purpose, UNS N06625 that is admitted immune to localized corrosion in ambient seawater in international standard and operator’s specification, whatever the outcomes of the CO2/H2 corrosion assessment.

Product Number: 51323-19137-SG
Author: Charles Leballeur, Tran Quang Tung, Nicolas Larché
Publication Date: 2023
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In-house operator specifications and international standards report some recommendations on the line fill water chemical treatment that should be implemented when installing and pre-commissioning subsea Corrosion Resistant Alloys pipelines. The main objective of this paper is to clarify some uncertainties in these recommendations and to better quantify actual corrosion risks.


UNS S31603, UNS N08904 and UNS N08825 type materials have been exposed in natural seawater from the bay of Brest (France) at 5 and 15°C and under the conditions representative of storage/pre-commissioning periods, i.e. in closed compartment conditions at 27°C. The pitting, crevice and under-deposit corrosion susceptibility of the different alloys have been assessed under these specific conditions.


The results of this study allow to complete the information from operator specifications and the standard recommendations used for the material selection of corrosion resistant alloys pipeline. According to the results obtained in this paper, some practices from these recommendations are susceptible to be over conservative and could thus be optimized. Indeed, tests performed have shown that the pitting and under- deposit corrosion risk seems to be very low in natural renewed seawater. This risk is expected to be even lower in close comparted media due to the fast decrease of dissolved oxygen concentration even at 27°C.

In-house operator specifications and international standards report some recommendations on the line fill water chemical treatment that should be implemented when installing and pre-commissioning subsea Corrosion Resistant Alloys pipelines. The main objective of this paper is to clarify some uncertainties in these recommendations and to better quantify actual corrosion risks.


UNS S31603, UNS N08904 and UNS N08825 type materials have been exposed in natural seawater from the bay of Brest (France) at 5 and 15°C and under the conditions representative of storage/pre-commissioning periods, i.e. in closed compartment conditions at 27°C. The pitting, crevice and under-deposit corrosion susceptibility of the different alloys have been assessed under these specific conditions.


The results of this study allow to complete the information from operator specifications and the standard recommendations used for the material selection of corrosion resistant alloys pipeline. According to the results obtained in this paper, some practices from these recommendations are susceptible to be over conservative and could thus be optimized. Indeed, tests performed have shown that the pitting and under- deposit corrosion risk seems to be very low in natural renewed seawater. This risk is expected to be even lower in close comparted media due to the fast decrease of dissolved oxygen concentration even at 27°C.

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Corrosion Resistance Of Stainless Steels And Nickel Alloys In Natural Seawater

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Author: Sandra Le Manchet/ Martin Monnot/ Emilie Robin
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Top of the Line Corrosion Mechanism for Multiphase Sour Gas Subsea Pipeline

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The hydrocarbon exploration in the ocean and deep sea was started as early as early as the 1850s, when the first drilling was carried out in California, USA. Other early oil explorations activities were later recorded in Pakistan (1886), Peru (1869), India (1890) and Dutch East Indies (1893). The development of an offshore industry is directly related to the development of subsea pipelines as well. As the industry expands towards deeper waters, the pipelines are required to have better materials, designs, operation practices and maintenance strategies to withstand the challenging environments. These pipelines are exposed to elevated temperatures, high pressures, and corrosive fluids.
Picture for Localized Corrosion of High-Grade Stainless Steels in Chlorinated Seawater
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Localized Corrosion of High-Grade Stainless Steels in Chlorinated Seawater

Product Number: 51323-18911-SG
Author: Nicolas Larché, Charles Leballeur, Sandra Le Manchet, Wenle He
Publication Date: 2023
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In natural seawater, microorganisms can fix, grow and develop on practically any surface, including stainless steels, which may cause industrial issues such as microbial induced corrosion, loss of heat transfer efficiency, or undesired colonization from macro-fouling. In particular, the presence of a biofilm on passive alloys such as stainless steels or nickel-based alloys can strongly enhance the cathodic reactions such as reduction of dissolved oxygen, and shift the open-circuit potential (OCP) to the noble direction.This results in an increase in OCP, also called cathodic depolarization or biofilm-induced ennoblement, and affects the risk of localized corrosion, since the critical pitting or crevice potential can be exceeded.
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