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Local Hard Zones On TMCP Large Diameter Line Pipes: What Do We Know?

Product Number: 51322-17565-SG

Author: Hervé Marchebois, Bruce Cowe, Thierry Cassagne

Publication Date: 2022

$20.00

The current paper deals with a thorough analysis of these newly recognized LHZ with Scanning Electron Microscope (SEM) and Electron Back Scattering Diffraction (EBSD) investigations through the wall thickness of pipes. Internal diameter (ID) surface, intermediate zone and bulk metal microstructures showed an increase of a strong misorientation while approaching the ID. Thus, LHZ is characterized by the presence of lath and especially lower bainite type microstructures associated to high local hardness above the NACE MR 0175 / ISO 15156 limits for sour service applications.

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Localized and Generalized Corrosion Evaluation of S13CR in Shale Oil & Gas Production Conditions

Product Number: 51324-21106-SG

Author: Merlin C. E. Bandeira; Felipe S. Assunção; Pedro Filgueiras; Kevin Schleiss; Rogaciano M. Moreira

Publication Date: 2024

$40.00

To understand the performance of S13CR on shale gas field, the ability of oxide layer to repassivate on erosion environment was investigated by means of electrochemical and rotating cage tests at 300 bar of total pressure with 10 bar of CO2, 1.2 mbar of H2S partial pressure with balance of nitrogen; sand particles concentration of 50g/L, 26% NaCl, stir velocity of 1,000 RPM and temperature of 115°C. Based on the results, it was observed stable potential (LPR) under erosion condition (with sand) when compared to reference test (without sand). Despite the huge amount of sand and the high rotation speed of the cage, the cyclic potentiodynamic polarization of S13CR on erosion test is quite similar to the reference test. Localized corrosion induced by erosional attack, investigated by RC tests, was not observed and the corrosion rate were similar in both conditions. Laboratory test results corroborate field caliper inspection after 12 months in service where the highest penetration was 9% of wall thickness, therefore below the API 5CRA recommendation of 12.5%. The penetration rates of laboratory test and field inspection were 0.2 and 0.5 mm/y, respectively.

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Localized Corrosion Limit of Use of S13%Cr (UNS S41427) Connector in Converted Injection Treated Seawater Well

Product Number: 51324-20714-SG

Author: Nicolas Larché; Marianne Kleive; Charles Leballeur; Eva Malmanger

Publication Date: 2024

$40.00

Many systems can be converted and used for different applications not initially planned. This is the case for production wells, sometimes converted into water injection wells and for which the production tubing material selection is clearly not adapted for prolonged contact with natural seawater. Oxygen removal treatment must be applied but precise control is not obvious and excursions above zero or close-to-zero oxygen can occur. The production tubing material S13%Cr are known to be sensitive to dissolved oxygen excursions in seawater, but data from the literature cannot precisely help in defining the allowed limits of use. Exploring the possibility to convert a production well into a treated seawater injection well then requires a careful assessment of the corrosion resistance limits of the involved alloys. A series of corrosion tests in treated seawater were designed to assess the limits of use of fast connector made of alloy UNS S41427. The corrosion tests were performed both at laboratory scale and on full-scale fast connectors in a treated seawater flow loops simulating service conditions. For all the performed tests, maintaining the dissolved oxygen content (DOC) at 15 ppb and below never led to localized corrosion and has been considered as a safe condition in terms of corrosion risk for alloy S41427 at ambient temperature. It was found that prolonged dissolved oxygen content (DOC) above 30±10 ppb may lead to initial crevice corrosion after only 4 h of exposure. Globally, a very good correlation between the laboratory and the full-scale test results was found. The critical crevice potential for alloy S41427 was significantly affected by the cleaning process of the tested coupons, while the stop of the corrosion was always measured for potentials reached at DOC < 10 ppb. The proposed methodology, involving both laboratory and full-scale tests, allowed to precisely quantify the limits of use of UNS S41427 in treated injection well. It could be used for any other material and applications to help at designing adapted and reliable engineering diagrams for material selections.

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Localized Corrosion Management For Thermally Insulated Systems Via Insulation Stand-Offs And Low Point Drains

Product Number: 51322-17585-SG

Author: Ahmad Raza Khan Rana, Graham Brigham, Omar Chaar, George Jarjoura

Publication Date: 2022

$20.00

Corrosion under thermal insulations namely CUI (Corrosion under insulation) is a key degradation process in hydrocarbon facilities which poses asset integrity risks. 1 CUI is reported as the reason behind 40-60% of failures of the process piping in a typical oil refining facility. Speaking smaller-sized process piping (i.e., NPS < 4”), up to 81% of reported failures are known to result from CUI. 2 Monetary spending to inspect and fix CUI-related failures cost 10% of overall maintenance budget in a typical medium-sized oil refinery. 2 CUI risk is influenced by numerous operational and environmental factors which impedes its management in a typical AIM (Asset integrity management) program. The

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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

$20.00

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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Localized Corrosion of UNS S31603 in Aqueous Ammonium Chloride Environments at Elevated Temperatures and Low Dissolved Oxygen

Product Number: 51323-19125-SG

Author: Guru Prasad Sundararajan, Nicholas J. Laycock, Nikhil Amin, Wouter Hamer, Sami Ahmed

Publication Date: 2023

$20.00

Ammonium Chloride (NH4Cl) corrosion is prevalent in the refinery and petrochemical industries and its prediction, monitoring and control has been well documented. In Chemical plants, when NH3 and HCl are present in a gas-mixture and the temperature drops, NH4Cl can desublime. In the presence of water-vapor, NH4Cl desublime within components like heat-exchanger tubes, creating saturated wet salt deposits, causing general and localized corrosion.

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Localized corrosion propagation of carbon steel in inhibited environment: a potentiostatic approach

Product Number: 51323-19071-SG

Author: Bernardo Santos, Marc Singer, Maria Serenario, Maalek Mohamed-Said, Xi Wang, Alysson Helton Santos Bueno, David Young

Publication Date: 2023

$20.00

Localized corrosion is known as the most dangerous and unpredictable corrosion mechanisms found in hydrocarbon production and transmission systems. This mode of corrosion has the potential to cause serious financial loss, environmental damage, production interruption, and even loss of life. Over the years, corrosion engineers have made significant improvements on prediction and mitigation techniques to extend the lifespan of carbon steel pipelines, such as using of corrosion inhibitors; injection of such chemicals has proven to be effective and economic, making them a first choice over other alternatives

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Localized Corrosion Studied Via Interferometry Using Modified Surfaces

Product Number: 51322-17747-SG

Author: Tracey Jackson, Haitao Fang, Jagrut Jani, Johnathon Brooks, Lei Huang

Publication Date: 2022

$20.00

Corrosion failures in the oil and gas industry are dominated by localized failures in carbon steel; however, the industry has yet to develop standards for localized corrosion specifically for low alloy carbon steels (CS) such as UNS K03014 (API) 5LX65 [X65]) or UNS G10180 (C1018). The reasons for the lack of standardization are understandable as they are not trivial. The challenges are as follows: 1) CS pitting is more complex than pitting on stainless steels (SS) and can be impacted by corrosion byproducts and other forms of scales, and 2) surface finish of a test coupon or electrode has a significant impact on the three phases of pitting: initiation, propagation, and termination.

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Long- And Short Term Laboratory Testing Of UNS N06985 For OCTG In Extreme Sour Environments

Product Number: 51322-17966-SG

Author: Wenle He, Charlotte Ulfvin, Per Olsson Artberger

Publication Date: 2022

$20.00

UNS N06985 is a nickel-based alloy with additions of Mo, Cu and W. Because of its high strength and high resistance to stress corrosion cracking (SCC), cold worked UNS N06985 has been extensively used for OCTG (Oil Country Tubular Goods). The SCC initiation has been studied in Cl-H₂S-CO₂ containing sour environments; and the SCC resistance was often evaluated using slow strain rate testing (SSRT) for screening by short-term testing and using tensile or C-ring for verification by long-term autoclave testing exposures¹. UNS N06985 showed high resistance to SCC at high temperatures in elemental sulfur containing environments with moderate chlorides².

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Long Distance, Long Duration Case Study of Successful Inhibitor Application on a Very Light Hydrocarbon Pipeline

Product Number: 51324-21214-SG

Author: Trevor Place; Tyler Markowski; Jennifer Sargent; Hitesh Bagaria

Publication Date: 2024

$40.00

The operating mileage of North American pipelines transporting low density, high API gravity hydrocarbon liquids has increased significantly over the past two decades. This trend began in the early 2000’s because of increasing oil sands production in Canada, where light hydrocarbons are used to reduce the viscosity of bitumen to achieve practical ‘heavy oil’ specifications suitable for pipeline transport. The light tight oil boom of the 2010’s continued this trend, as multistage fracking unlocked high API gravity liquids from previously low permeability shale and sandstone formations. While different in origin and composition, light tight oils (LTOs), diluents used for bitumen transportation, and some refined products are similar in terms of density (density 680-800 kg/m3, or API 35-70), viscosity (<1cSt), and steel surface wetting behavior (hydrophilic). In previous works, the use of the NACE TM0172 ‘spindle test’ was demonstrated as an effective screening tool to assess the performance of corrosion inhibitors1 and led to the recommendation of hydrocarbon soluble inhibitors. Digital coupon analysis was used to provide unbiased quantification of results allowing better discrimination of inhibitor performance.2 The authors also provided an exploration of parasitic inhibitor consumption by fluid borne particulate.3 This work completes a decade-long pipeline case history where effective corrosion inhibition was used to solve a myriad of particulate related issues in a long-distance diluent carrying pipeline. Significant learnings about the performance and longevity of inhibitor (successfully applied at only one location of a 2500 km pipeline), the measurement of dissolved and particulate adsorbed inhibitor, the effect of maintenance pigging on the inhibitor film, and unexpected learnings about the ability of the inhibitor to disperse accumulated particulate is presented.

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Long Life Chloride Affected Concrete Structures – Some Corrosion Mechanistic Considerations

Product Number: 51321-16919-SG

Author: W K Green; J B Katen; D B McDonald

Publication Date: 2021

$20.00

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Long Range Ordering In Thermally Treated And Cold-Worked Alloy 690

Product Number: ED22-17251-SG

Author: Daniel Brimbal, Pierre Joly, Claude Benhamou, Cécilie Duhamel, Michael A. Burke, Annie Pagès, Bénédicte Gueraud

Publication Date: 2022

$20.00

Nickel-chromium alloys may be susceptible to ordering under certain thermal aging conditions, resulting in the formation of an Ni2Cr phase. The Ni2Cr phase is a superlattice which can result in significant changes of the physical or mechanical properties compared to those of the disordered alloy. Alloy 690, which usually contains a bit less than two nickel atoms per chrom-ium atom, could potentially be susceptible to long-range ordering (LRO) or short-range ordering (SRO). SRO implies that a Cr atom has a high probability of having a Ni nearest neighbor and that small order domains containing at most a few atoms exist. LRO implies that small Ni2Cr clusters exist, and although they may not be visible by transmission electron microscopy (TEM) dark field imaging, they lead to the detection of
additional diffraction spots in selected area electron diffraction (SAED) patterns, contrary to SRO. Below the critical temperature for LRO, the formation of the long-range ordered structures is preceded by a period of short-range ordering.

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Association for Materials Protection and Performance