AMPP Store - Individual Conference Papers

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Over-the-line Potential Surveys for Indirect Condition Assessment of Water/Waste Water Pipelines: Case Studies

Product Number: 51319-13003-SG

Author: Mersedeh Akhoondan

Publication Date: 2019

$20.00

Failure of water/wastewater mains can result in high visibility repairs customer inconvenience and replacement costs. Preventive measures such as condition assessment for early recognition of corrosion in aging infrastructures is crucial for agencies from resiliency safety and economic standpoints but is not regulated as in the oil & gas industry. Internally deployed tools/technology or external excavations for direct assessment techniques provide valuable insight on the existing condition of buried structures but at a significant cost in terms of shutdown and technology expenses in addition to safety concerns for manned entries into confined spaces. Because of the cost and safety implications large diameter cement mortar lined (CML) pipe extensive and recurring direct assessments are less common in the water and wastewater industries. Indirect assessment techniques particularly the over-the-line potential surveys for condition assessment of water/wastewater lines can be conducted to determine active external corrosion areas. Traditionally over-the-line potential surveys were applied to electrically continuous pipelines. Most water/wastewater pipeline designs utilize rubber gasket bell-and-spigot joints. Unless electrical continuity is intentionally designed for the pipeline such joints result in a pipeline with no electrical continuity. This paper presents multiple case studies where over-the-line potential surveys were successfully applied on electrically discontinuous water pipelines. The results of over-the-line surveys correlated well with direct assessment techniques. The paper presents the methodology and results of such assessments and findings for various pipe materials.

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Overview of latest advances in measuring and understanding cathodic protection current permeability by organic coatings

Product Number: 51320-14685-SG

Author: Facundo Varela, Mauricio Latino, Yongjun Tan, Maria Forsyth

Publication Date: 2020

$20.00

Shielding of cathodic protection (CP) by disbonded coatings is considered a “worst case scenario” for external corrosion in the pipeline industry. It has been hypothesized that if coatings were partially permeable to CP, the imbalance between cathodic and anodic reactions would induce a high pH environment under disbonded coatings and that would impede corrosion. However, direct experimental evidence of this process has been limited. Moreover, this line of reasoning is often inversed incorrectly assuming that the only reason for the presence of a high pH environment under disbonded coatings is their partial permeability to CP current.

The recent development of an electrochemical self-validating technique to measure the relatively small ionic currents that could permeate through defect free coatings has shed a new light on the topic. It has been found that most of the commercial pipeline coatings tested in unaged conditions present a CP shielding behavior. Accelerated hydrothermal ageing of fusion-bonded epoxy (FBE) coatings was performed to study the effect of water absorption. Ageing resulted in major plasticization, which increased the conduction of CP current through FBE coatings. However, FBE seems to be partially permeable to H+ and/or OH-, which reduces its ability to form and retain a high pH environment under disbonded coatings. In conjunction, these results thus indicate the extremely limited capability of commercial pipeline coatings to prevent corrosion in case of disbondment.

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Overview Of Latest Advances In Understanding The Limited Ability Of Fusion Bonded Epoxy To Stop Corrosion Within Disbondments

Product Number: 51321-16808-SG

Author: Facundo Varela; Mauricio Latino; Yongjun Tan; Maria Forsyth

Publication Date: 2021

$20.00

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Overview Of Scale Issues And Treatment For Sour Water Strippers

Product Number: 51322-17549-SG

Author: Haiping Lu, Swamy Margan, Bill Watson, William Mansfield, Jim Kiolbassa

Publication Date: 2022

$20.00

Sour water stripping is used to remove ammonia (NH₃) and hydrogen sulfide (H₂S) from sour water streams coming from many operation units to condition it for discharge or reuse.^1-3 In a complex refinery, most of the sour water comes from distillation, fluid catalytic cracking, catalytic reforming, coker and acid gas removal units, with many other operations contributing to the balance. The different streams are usually collected in a surge tank for centralized processing via a heat exchanger and a single stripper column, or two in series.

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Oxidation and Hydrogen Embrittlement Behavior of Several Additively Manufactured Ni-Based Superalloys

Product Number: 51324-21117-SG

Author: Lucas Teeter; Martin Detrois; Kyle Rozman; Chantal K. Sudbrack

Publication Date: 2024

$40.00

The environmental degradation of additively manufactured Ni-based superalloys (INCONEL® 625 (IN625), Haynes® 282® (H282), and INCONEL® 718 (IN718)), fabricated by laser powder-bed fusion (L-PBF) and fully heat-treated, is being screened for hydrogen service in industrial gas turbines. Oxidation experiments in air, on printed and machined surface conditions at 750 °C for 164, 500, and 2,010 hours revealed thicker oxides for printed conditions for IN625 and H282 and thicker oxides for machined conditions for IN718. The chromium oxide that developed was thickest for H282 and showed higher incorporation of Ni/Fe-based oxides for the as-printed surfaces. Ex-situ hydrogen embrittlement was evaluated by electrochemically charging flat test bars for 72hours in 0.1 M H2SO4 + 1 g/L CH4N2S then slow strain rate tensile testing (0.0039 mm/min) at room temperature. All experienced reduction in strain failure of that lead to a hydrogen embrittlement index of 16%, 18%, and 30% for IN625, H282, and IN718, respectively. Oxidation kinetics showed the highest to smallest oxidation rate: H282, IN625, and IN718. The oxidation rates were higher on the as-printed surfaces for H282 and IN625 but lower for IN718. Topographical imaging of the fracture surfaces showed a 30-100 µm deep embrittlement zone at the surface developed during hydrogen charging, but no significant differences between charged and as-received specimens in the center where ductile dimpling behavior is dominate.

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Oxidation Assessment and Impact of Pre-oxidation on Hot Corrosion Behavior of Fe- and Ni-based Alloys

Product Number: 51324-20991-SG

Author: Haofei Sun; Chentao He; Jing Liu

Publication Date: 2024

$40.00

In this study, we first validated the oxidation performance of Alloy 800 (Fe-based alloy) and 625 (Ni-based alloy) within the temperature range of 700-1000 °C. After 24 hours of oxidation at 1000°C in air, the mass gain is measured as 2.53 and 1.86 mg/cm2 for Alloy 800 and 625, respectively, with their increase rates approximately reaching 6 times compared with those at 900 °C. The main oxidation scale in both two alloys is identified as a Cr2O3 layer with minor NiCr2O4 from 800-1000 °C. A crucial facet of this investigation involved subjecting the alloys to pre-oxidation treatment at 1000 °C for 24 hours, resulting in reduced mass gain during subsequent hot corrosion evaluations with NaCl/Na2SO4 salts at 900°C, particularly noticeable in Alloy 800, where a dense oxidation layer formed. However, cross-sections of both two alloys show a deep penetration by Na and O. These findings reveal the limited protective role of the Cr2O3 layer in augmenting resistance to hot corrosion while offering valuable insights into materials' performance in high-temperature environments and industrial applications.

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Oxidation Behavior of an Austenitic Stainless Steel Used in the UK Advanced Gas Cooled Reactors

Product Number: 51315-5965-SG

ISBN: 5965 2015 CP

Author: Bo Chen

Publication Date: 2015

$20.00

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Oxidation Of Welded Materials In High Temperature Supercritical Carbon Dioxide

Product Number: 51321-16961-SG

Author: Florent Bocher

Publication Date: 2021

$20.00

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Oxidation Reactivity of Heat-Resistant Alloys Exposed in Wet Air at 900°C

Product Number: 51321-16288-SG

Author: Mirnaly Saenz de Miera/Joseph Kish/Peter Poruks/Michael Györffy/Harvey Fraser/Matthew Webb

Publication Date: 2021

$20.00

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Oxidation Resistant Behaviors of Commercial High Temperature Alloys in the Atmospheres Containing Water Vapor

Product Number: 51324-20729-SG

Author: Bingtao Li; Vinay Deodeshmukh; Lee M. Pike

Publication Date: 2024

$40.00

Water vapor has significant effects on high temperature oxidation behaviors of high temperature alloys, especially on chromia-forming alloys due to oxidative evaporation of chromia scale. The objectives of this work are to study high temperature oxidation behaviors of commercial high temperature alloys, including seven chromia-formers, such as N06230, R30188, N08120, N06002, N06625, N06617, S34700, and three alumina-formers, such as N07214, NiCoCrMoAl, NiFeCrAl, at the temperatures from 760 to 1093°C (1400 to 2000°F) for up to one year exposure in the air atmospheres containing (5-30)% water vapor. The effects of water vapor content, temperature, heating/cooling condition, and alloy composition were analyzed from the results of metal loss and internal oxidation penetration, along with comparison with their oxidation behaviors tested in air without water vapor addition. The study shows, in general, water vapor could accelerate oxidation attack, and higher water vapor contents could cause more oxidation attack. However, high temperature oxidation behaviors of high temperature alloys will depend on multiple factors that need to be considered, especially when comparing oxidation results generated under different testing conditions.

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Oxygen Consumption As Sensitive Measure Of Polymer Electrical Cable Insulation Aging

Product Number: ED22-17274-SG

Author: Yelin Ni, Katarzyna Grubel, Jonathan D. Egbert, Leonard S. Fifield

Publication Date: 2022

$20.00

It is of sustained interest to estimate the remaining useful lifetime of polymers used as cable insulation in nuclear power plants for cable aging management and license extension purposes. Studies have been focused on a range of topics from mechanism of degradation process, kinetic modeling, effects on chemical signatures and mechanical properties, and accelerated aging techniques for lifetime prediction.

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Oxygen Corrosion Control for Multiphase and Gas Phase Pipelines

Product Number: MECC23-20154-SG

Author: Geeta Rana, Henry Garlick, Caleb Clark, Jeremy Moloney

Publication Date: 2023

$20.00

Produced fluids in O&G sector in general do not contain oxygen, but oxygen ingress can occur at locations. Examples of such spaces can include but not limited to vapor space in tanks, custody transfers, injection pumps, vapor recovery systems, operating pumps with faulty seals, pipelines that are not properly purged of oxygen during commissioning operations, gas lift operations, methanol use or pigging operations.
This contamination of O2 in sweet/sour systems can lead to oxygen induced corrosion and may cause high general and pitting corrosion rates and failures.

Individual Conference Papers

Association for Materials Protection and Performance