AMPP Store - Products tagged with 'high temperature corrosion'

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09153 Control of Metal Dusting Using Alloy Selection, Coatings and Inhibitors

Product Number: 51300-09153-SG

ISBN: 09153 2009 CP

Author: Brian Chambers, Rafael J. Rengifo and Dale McIntyre

Publication Date: 2009

$20.00

This study reports the results of laboratory investigations in pressurized high-temperature carbon-rich environments simulating operations in syngas production and root cause failure analysis and laboratory analysis simulations in refinery platformer operations. The results rank a variety of stainless steels and Ni alloys.

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51317--9784-High Temperature Coking Resistance of an Alumina Forming Alloy

Product Number: 51317--9784-SG

ISBN: 9784 2017 CP

Author: Benjamin Church

Publication Date: 2017

$20.00

Coking is carbon deposition from a gas phase that is encountered in many reforming, cracking and other high temperature processes. An experimental high temperature coking atmosphere was constructed and used to evaluate the effects of temperature, time and metal surface roughness on the carbon deposition of an alumina forming alloy.

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51318-11372-Selection of Superheater Materials for Biomass-fired Boilers

Product Number: 51318-11372-SG

Author: V. Padilla

Publication Date: 2018

$20.00

This work presents the results of a field-based study designed to evaluate the corrosion performance of five alloys exposed in a Canadian biomass-fired boiler attached to a gasifier for 3,552 hours.

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A Case Study-Caustic Gouging Of Boiler Tubes

Product Number: 51322-17780-SG

Author: Suresh Divi, Sri Krishna Chimbli

Publication Date: 2022

$20.00

Caustic corrosion is sometimes referred to as “caustic attack or “caustic gouging.” Corrosion of this type may result from internally fouled heat transfer surfaces and the presence of sodium hydroxide in the boiler water; and concentrated solutions of alkali where the normal washing of the tube metal ID is restricted after Departure from Nucleate Boiling (DNB), i.e., when the steam bubble release exceeds the rinsing rate.

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Corrosion and Corrosion Products in a Sour Environment from 80°C to 200°C

Product Number: 51317--9084-SG

ISBN: 9084 2017 CP

Author: Shujun Gao

Publication Date: 2017

$20.00

Corrosion rate of mild steel and character of corrosion products in sour environments at temperatures from 20 to 200°C. H2S-H2O water chemistry model was developed. Then, H2S corrosion tests were done at 80, 120, 160 & 200°C - exposure time of 4 days.

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Corrosion Studies of Novel Nickel-Base Alloys in Molten Chloride Salts

Product Number: 51324-21199-SG

Author: Harjot Singh; Diego Ochoa; Michael Kloesel; Vilupanur Ravi; Boateng Twum Donkor

Publication Date: 2024

$40.00

Molten salts are being considered for use in a new generation of nuclear reactors. Therefore, any materials selection process necessarily involves corrosion studies to understand the compatibility between the salts of interest and the materials of construction. This project investigated the corrosion behavior of novel Ni-base superalloys in molten chloride salt mixtures at 750°C for 200 hours in an inert atmosphere. Alloy response to the molten salt was examined through mass loss per unit area, analysis of surface phases and microstructural examination of the alloy cross-section along with elemental analysis. The role of critical alloying elements in alloy corrosion behavior was related to the material response to the molten salt. Alloy 6, an aluminum-containing alloy was the most corrosion resistant while Alloy 7, containing titanium additions, also did well. In the absence of these critical alloying elements, Alloy 4, proved to be the least corrosion resistant.

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Corrosion Testing Of Graphene-Oxide-Polymer Coatings For Geothermal Drilling Applications

Product Number: 51322-17732-SG

Author: Erlend Oddvin Straume, Gifty Oppong Boakye, Baldur Geir Gunnarsson, Arna María Ormsdóttir, Beatriz Alonso Rodriguez, Sigrun Nanna Karlsdottir

Publication Date: 2022

$20.00

The high temperature and chemical composition of the geothermal fluid results in corrosion damage of drilling equipment, well casing and other components made of steel and iron alloys used in geothermal power production. This corrosive nature of the geothermal environment decreases the service life and increases the need for maintenance of geothermal power plants and geothermal wells. The main reasons for the corrosion of components are hydrogen sulfide (H2S) and carbon dioxide (CO2) present in geothermal system.

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Effect Of Varying H2S Content On High Temperature Corrosion Of Austenitic Alloys In A Pyrolysis Process Of Post-Consumer Plastics

Product Number: 51322-17552-SG

Author: Manuela Nimmervoll, Roland Haubner, Gregor Mori, Stefan Hönig

Publication Date: 2022

$20.00

Pyrolysis processes of post-consumer plastics are a promising chemical recycling route and a good alternative to disposal. Nevertheless, these processes are challenging for metallic materials since chlorine containing materials or biological components inside the feedstock can yield HCl and H2S, respectively, during cracking. In combination with high temperatures of the reactor zone metallic construction materials can be attacked by high-temperature corrosion.

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Evaluation Of Reactive Sulfur For Improved Corrosion Predictions In Oil Refineries

Product Number: 51322-18039-SG

Author: Ishan Patel, Gheorghe Bota, David Young

Publication Date: 2022

$20.00

Naphthenic acids and sulfur species in crude oil cause severe corrosion of the steel equipment of crude distillation units in oil refineries.^1–3 Because of rapidly changing oil economics, the refineries have inclined towards cheaper “opportunity crudes”, but the high levels of corrosive species, mainly naphthenic acids and organosulfur compounds, in these crudes would reduce the life of the equipment, and also increase the risk of catastrophic failure.³ So the opportunity crudes are often blended with the crudes containing lower levels of corrosive species; this decreases overall concentration of corrosive species and the corrosion rates.^4,5 However, corrosion rates are not simply proportional to the concentrations of naphthenic acids and sulfur species that are present in the crude oil.^4,5 Without accurate estimation of corrosion rates by crude oils or their “blends”, carbon steel equipment needs to be constructed with higher wall thickness for safety; if still insufficient, high alloy steels are required.

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Fe3O4, FeCO3 or FeS - Which Corrosion Product Will Prevail at High Temperature in CO2/H2S Environments?

Product Number: 51320-14413-SG

Author: Shujun Gao, Bruce Brown, David Young, Srdjan Nesic, Marc Singer

Publication Date: 2020

$20.00

Sweet (CO2) and sour (H2S) corrosion have continuously been a challenge in oil and gas production and transportation. Yet, some key issues are still not well understood, especially at high temperature production conditions. A CO2/H2S ratio of 500, which has been used (often inaccurately) to determine which corrosion mechanism is dominant, is probably even less valid at high temperature. The nature of the corrosion products forming at high temperature in CO2/H2S environments and their effects on the corrosion rate are not known. Finally, the impact on pipeline integrity of environmental changes between sweet and sour production conditions (simulating reservoir souring) has not been well documented. CO2, H2S, and CO2/H2S corrosion experiments were conducted at 120oC to investigate corrosion mechanisms and corrosion product layer formation at high temperature. The results show that the corrosion products were still clearly dominated by H2S under the pCO2/pH2S ratio of 550. Formation of Fe3O4, FeCO3, and FeS corrosion product layers had a direct impact on the measured corrosion rates and was dependent on the gas composition and on the sequence of exposure (CO2 then H2S and vice versa). Compared with H2S corrosion alone, the presence of CO2 could retard Fe3O4 formation in CO2/H2S mixture environment. No obvious change in steady state corrosion rate was observed when the corrosion environment was switched from CO2 to H2S and vice versa.

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Field Application of Corrosion Resistant Weld Overlay in Ultra-Supercritical Coal-Fired Boiler Waterwalls

Product Number: 51320-14660-SG

Author: Jun Jiang, Bingtao Li

Publication Date: 2020

$20.00

Weld overlay has been successfully used to mitigate high temperature corrosion issues in coal-fired boilers since the1990s, such as in waterwall and superheater/reheater area. Weld overlay is typically applied in shop or field by using Gas Metal Arc Welding (GMAW) process for boiler waterwall application, and the overlay welding is performed in vertical down welding mode (3G welding position) in subcritical and supercritical boiler waterwall applications. With the rapid development of coal-fired boiler market in China, ultra-supercritical boilers are becoming the dominated boiler type which often has spiral waterwall design. Most of ultra-supercritical coal-fired boiler waterwall consists of CrMo steel tubes, which could suffer severe high temperature corrosion attack after the installation of low NOx burners. It is expected that weld overlay could provide a long-term high temperature corrosion protection for ultra-supercritical boiler waterwall based on previous weld overlay study and application experience. However, for the spiral waterwall with inclined tube design, its field overlay welding is highly challenging and significantly different from typical vertical boiler waterwall overlay welding. The challenge and difference include welding position, welding sequence, welding parameters, and overlay properties, etc. This paper presents a successful field application of 309L stainless steel and 622 Ni-based alloy weld overlay on the spiral waterwall of an ultra-supercritical coal-fired boiler, including the welding development, simulation, and experience of overlay welding on the inclined tubes, along with the characterization of the weld overlay applied.

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High Temperature Corrosion Resistance Of Alloy N07740 In Solar And Low Emission Ultrasupercritical Power Generation

Product Number: 51322-17945-SG

Author: Stephen McCoy, John deBarbadillo, Brian Baker, Mark Anderson

Publication Date: 2022

$20.00

In recent years, solar energy technology has received particular emphasis in the interest of reducing CO₂ emissions. Concentrated solar power (CSP) technology received an initial boost from the installation of nine parabolic trough-based electricity-generating systems totaling 354 megawatts of capacity in the 1980’s. Solar One, operational in 1982 and supported by the DOE and an industrial consortium, illustrate utilization of a circulating heat transfer fluid to produce steam to drive a turbine generating electricity. Solar Two in 1996 demonstrated energy storage so that solar power could be generated during the night.¹ In the ensuing decades, additional capacity has increasingly been installed worldwide, comprised primarily of both parabolic trough and central tower CSP technologies, As of 2019, global installed capacity totaled 6.2 GW, with an additional 21 GWh planned of installed thermal energy storage (TES) comprised primarily of molten salts.

Products tagged with 'high temperature corrosion'

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