AMPP Store - Individual Conference Papers

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Influence of the H2 Impurity on the Fatigue Crack Growth and Fracture in a Dense Phase CO2 Pipeline

Product Number: 51324-20721-SG

Author: B Bezensek; S Hopkin; J Sonke; F Gui; C Taylor

Publication Date: 2024

$40.00

Transport of dense phase CO2 by pipelines needs to account for possible degradation mechanisms arising due to H2 impurity which can be present in (typically) the 0.75 ~ 1 mol% range depending on the specification used. H2 gas can affect fatigue and fracture properties even at low partial pressures and hence the integrity. In this study a complementary experimental and computational modeling program was undertaken. API 5L X65 grade material samples were used for comparable testing in pure H2 gas at low partial pressure H2 and in dense phase CO2 at 100 barg with H2 impurity added in a 2 mol% and 4 mol% increments (i.e. partial pressures of 2 barg and 4 barg). The test results show effect of the H2 impurity in the dense phase CO2 accelerated fatigue crack growth and reduced fracture toughness. These findings are supported by computational simulation using density functional theory and molecular dynamics. A scoping integrity assessment for a dense phase CO2 pipeline with H2 impurity at 2 mol% shows the measured accelerated fatigue crack growth only affects large pressure cycles (pressure range in excess of 70 bar for OD/WT pipelines of ~30). The fatigue life is significantly shortened compared to the pure CO2 pipeline and this is mainly driven by the reduced fracture toughness at low partial pressure H2. The fatigue damage is proportional to the maximum operating pressure (as it increases the pressure range). For a postulated 50-year design life a safe pipeline design window considering a range of conservative inputs (material properties, integrity operating window, geometry, postulated defect size etc.) a safe operating pressure of 2900 psig (200barg) was found for a new build pipeline using modern materials. For a repurposed vintage material pipeline the safe operating pressure was set at 2200 psig (150 barg). An ECA incorporating the deleterious effect of H2 should be conducted to confirm the above postulate unless the project falls within the limits of the conservative inputs (material properties, integrity operating window, geometry, postulated defect size etc.), from a fracture mechanics perspective, of the four case studies that form the basis of this overall study. Other impurities if exceeded their safe threshold may create water drop out and acid formation. It is imperative that the project specifications err on the side of caution and restrict the impurities to safe limits until further understanding of the complex interaction mechanisms is developed.

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Influence of the Hardening Phases on the Hydrogen Embrittlement Susceptibility of Ni-Alloys based on UNS N07718

Product Number: 51320-14667-SG

Author: Julia Botinha, Bodo Gehrmann, Helena Alves

Publication Date: 2020

$20.00

The Alloy UNS(1) N07718 is among the most used alloys in the oil and gas industry. Due to the presence of the alloying elements niobium, aluminum and titanium, this alloy is precipitation hardenable by the formation of the phases Gamma’ and Gamma’’. Although presenting excellent strength properties and good resistance in sour gas applications, this material is known to be susceptible to hydrogen embrittlement and most field failures are related to this limiting property.

The use of Alloy 718 (UNS N07718) for oil & gas applications is regulated by the API(2) 6ACRA1 standard and it is available in three different grades, the 120K, with minimum 120 ksi yield strength, the 140K, with minimum 140 ksi yield strength, and the 150K, with minimum 150 ksi yield strength. Previous studies showed that, due to the different hardening heat treatment parameters, each of the available grades presents a different precipitation behavior in terms of distribution and amount of precipitates, and the obtained microstructure is directly related to the resistance of the material to hydrogen embrittlement.

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Influence of the Soil Moisture Level and Differential Aeration Cell on the Corrosion Rate of Carbon Steel and Zinc Coated Steel

Product Number: 51324-20694-SG

Author: Erwan Diler; Philippe Verpoort; Souhail Amami; Ansbert De Cleene; Benoit Emo

Publication Date: 2024

$40.00

Soil is a complex media involving solid particles, gas and liquid phases. Among the many soil parameters influencing the corrosion rate, beyond the pH and resistivity, disregards the microbial activity, the moisture level and the related oxygen diffusion is usually pointed out as a key parameter. Depending on the soil texture and related ability to retain water, as well as the ground water level, differential aeration corrosion cells (DACC) might appear. Such phenomenon locally affects the corrosion rate and distribution by galvanic action. This phenomenon is particularly relevant for large metallic pieces such as buried pipes, tubular piles, and sheet piles. In this study, an experimental setup composed of 30 coupons in carbon steel or zinc coated steel was exposed in two different soils to a vertical gradient of moisture level. The setup allows measuring the corrosion potential and galvanic current of each coupon, before and after their interconnection. The obtained results highlight i) the influence of the moisture level and oxygen diffusion on the corrosion potential for both carbon steel and zinc, and ii) quantify the differential aeration corrosion cells. The results are compared to coupons exposed for 1 year in the same environment, with and without DACC.

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Influence Of The Surface Condition On The Pitting And SCC Resistance Of Alloy UNS N07718 Produced Via Selective Laser Melting

Product Number: 51321-16949-SG

Author: Madison Woolridge; Christoph Wangenheim; Helmuth Sarmiento Klapper

Publication Date: 2021

$20.00

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Influence of the UV Radiation on the Corrosion Resistance of the Carbon-Based Coatings for the Marine Industry

Product Number: 51319-12950-SG

Author: Anastasiia Artemova

Publication Date: 2019

$20.00

The composite protective coating is the most widespread technology among various methods used in corrosion protection for the marine industry. Carbon-based materials are the most promising as anticorrosion pigments due to its mechanical strength chemical inertness non-cytotoxicity and very strong absorption of UV and visible light. In present study graphene oxide (GO) and multiwalled carbon nanotubes (MWCNT) were investigated as addictive and also they were modified by nitrogen-doping. The samples of stainless steel (316L) coated by epoxy resin with carbon-based pigments were exposed to UV irradiation (340nm) for 1000h and corrosion behavior in 3.5 wt% sodium chloride (NaCl) solution was investigated before and after UV degradation. Experimental results showed that corrosion current significantly decreased in presence of carbon-based materials especially nitrogen-doped ones in the composite coating. The degradation of the epoxy coating after UV exposure was retarded by the presence of the GO MWCNT and the nitrogen-doped pigments suggested that carbon-based nanomaterials may enhance the lifetime of composite coating. Finally a protection mechanism was built to explain the carbon-based nanomaterials improved corrosion resistance and effect of nitrogen-doping on the corrosion behavior.KEY WORDS: UV radiation composite coating corrosion graphene oxide multiwalled carbon nanotubes nitrogen doping

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Influence Of Thermomechanical Processing On Mechanical Properties And Corrosion Resistance Of Super Duplex Stainless Steel UNS S32750.

Product Number: 51322-17613-SG

Author: Clara Herrera, Merlin Seifert

Publication Date: 2022

$20.00

Duplex stainless steels (DSSs) are based on the Fe-Cr-Ni system and are constituted of 30 to 70 % ferrite and austenite. They combine high tensile strength, good toughness, weldability, and excellent corrosion resistance including stress-corrosion cracking and resistance to localized corrosion.^1-3 DSSs can be classified according to the Pitting Resistance Equivalent Number (PREN = Cr + 3.3 Mo + 16 N) in lean duplex (PREN= 22-27), standard (PREN = 28-38), super duplex (PREN = 38-45) and hyperduplex (PREN > 45).

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Influence of Ultrasonic Nanocrystal Surface Modification on the Corrosion and Stress Corrosion Cracking Behavior of Welded Joint in District Heating Pipe

Product Number: 51317--8953-SG

ISBN: 8953 2017 CP

Author: Yong-Sang Kim

Publication Date: 2017

$20.00

Stress corrosion cracking behavior measured by slow-strain rate tests with accelerated anodic & cathodic reactions. Results indicated the UNSM treatment has a significant effect on the corrosion condition. No effect appeared in the hydrogen embrittlement.

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Infrastructure Corrosion Issues and Solutions on Military Bases

Product Number: 51317--9212-SG

ISBN: 9212 2017 CP

Author: Vinod Agarwala

Publication Date: 2017

$20.00

Many hangars, shelters and silos used for storage of military weapons systems are several decades old and have started to show signs of aging and corrosion assisted damage of support structures. Case study.

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Inhibited Erosion-Corrosion of Carbon Steel in Sweet Production with CaCO3 Versus Sand Particles

Product Number: 51319-13433-SG

Author: Anass Nassef

Publication Date: 2019

$20.00

In the oil and gas production industry carbon steel tubing and piping are susceptible to erosion-corrosion damage due to the erosive and corrosive nature of the flow. The combined effect of solid particle erosion and corrosion can increase the metal degradation rate while simultaneously decreasing the efficiency of corrosion protection systems including iron-carbonate scale formation and chemical inhibition. These combined effects can lead to higher corrosion rates surface pitting and material failure. Thus prediction of chemical inhibitor effectiveness when solid particles are being produced particularly important. Modeling this behavior is critical when the wells are deep or off-shore because coupon testing is impractical and replacement costs are high. Considerable research has been devoted to investigate the effect of sand erosion on the efficiency of corrosion inhibitors in sweet production/CO2 environments in presence of sand particles. However sand particles are not the only particles that occur during oil and gas production. Calcium carbonate (CaCO3) particles can also be produced during oil and gas production because the majority of oil and gas production in the world is from carbonate reservoirs where calcium carbonate (CaCO3) particles can enter into the flow of produced gas and oil. Currently little is known about the erosive effects of CaCO3 particles on the performance of corrosion inhibitors in CO2 environments. This paper describes experimental and modeling studies directed at understanding the influence of CaCO3 particles on the effectiveness of imidazoline-based inhibitor in reducing CO2 corrosion of carbon steel material. The performance of the inhibitor with CaCO3 particles is compared with the inhibitor performance for a flow containing sand particles. A phenomenological model based on Frumkin-type isotherm is presented as a technique for predicting inhibitor effectiveness for these flow conditions. Erosion-corrosion experiments were performed using flow loop set up with a direct impingement configuration in an iron carbonate forming environment. Electrochemical linear polarization resistance and weight loss methods were utilized to experimentally characterize erosion-corrosion rates for both types of solid particles.

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Inhibiting localized corrosion of carbon steel pipelines in sour service

Product Number: 51323-18833-SG

Author: Anupom Sabhapondit, Aboubakr M Abdullah, Nicholas Laycock, Manoj Gonuguntla, Shimjith Madayi, Tom Bos

Publication Date: 2023

$20.00

Use of corrosion inhibitors (CI) to protect metallic equipment, especially carbon steel pipelines from corrosion has long been an established, effective, economic, and hence globally accepted technique. The oil and gas industry has been using CIs to protect the pipelines under various exposure conditions including sour and sweet services . Complete understanding of corrosion mechanisms under sour conditions and protecting pipeline steel under such conditions has always been a challenging task due to the complexity of such systems.

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Inhibiting Nucleation Corrosion in Liquid Hydrocarbons

Product Number: 51324-21232-SG

Author: Moshood Adewale; Hitesh Bagaria; Nimeshkumar Patel; Tatiana Barbosa; Osvaldo Antonio Heredia Cancino

Publication Date: 2024

$40.00

Dewpoint corrosion is a well-known phenomenon in flue gas stacks and refinery overheads, where fine water droplets condense from the vapor upon cooling, and the acid gases in the vapors diffuse into water droplets to form a highly corrosive low pH liquid. We have identified a similar mechanism in hydrocarbon liquids, which we call as “nucleation corrosion” (C2023-19463). Liquid hydrocarbons often have dissolved water (DW), which does not promote corrosion even in the presence of corrosive species (e.g., organic acids, H2S). Upon cooling, the DW nucleates as nanometer-sized water droplets and acids present in the liquid partition into the water droplets decreasing pH to cause aggressive nucleation corrosion. In this study the methods to mitigate nucleation corrosion are investigated with an emphasis on studying the impact of different types of chemical inhibitors on this newly discovered mechanism. An interesting example of the impact of the test method on inhibitor selection is shown. Finally, a case study highlighting nucleation corrosion in a refinery distillation overhead reflux line is presented.

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Inhibition Of Calcium Carbonate Scale Formation In Water-Mono Ethylene Glycol Solutions By Water Soluble Polymers

Product Number: 51321-16607-SG

Author: P.D. Natsi/ P.G. Koutsoukos

Publication Date: 2021

$20.00

Individual Conference Papers

Association for Materials Protection and Performance