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Picture for Corrosion Susceptibility Assessment of Tank 241-AN-106 in Supporting Double-Shell Tank Corrosion Control at Hanford Site
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Corrosion Susceptibility Assessment of Tank 241-AN-106 in Supporting Double-Shell Tank Corrosion Control at Hanford Site

Product Number: 51323-18786-SG
Author: Sheewa X. Feng, Jason S. Page
Publication Date: 2023
$20.00

The chemical and radioactive waste at the Hanford Site is currently stored in 131 single-shell tanks and 27 double-shell tanks (DSTs). The DSTs were built between 1968 and 1986, and each has a capacity of about 1 million gallons. Figure 1 is one typical design of the DSTs. Double shell means that each tank consists of a primary tank within a secondary tank. The primary and secondary tanks are also known as liners, and both are made from carbon steel.
Picture for Corrosion Susceptibility Prediction and Lifetime Extension of Nuclear Dry Storage Canister using Weather Data
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Corrosion Susceptibility Prediction and Lifetime Extension of Nuclear Dry Storage Canister using Weather Data

Product Number: 51323-19441-SG
Author: Vinod Upadhyay, Julio Mendez, Siva Palani, Alan Rose, Keith Legg
Publication Date: 2023
$20.00

With growing concern for global warming resulting from fossil fuel usage, the use of nuclear energy has provided a cleaner alternative to power generation. Radioactive fuel such as Uranium Oxide has gained significant usage today. Almost 20% of the electricity generated in the US comes from nuclear energy.
Picture for Corrosion Testing of Additive Manufactured Materials
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Corrosion Testing of Additive Manufactured Materials

Product Number: 51323-19317-SG
Author: Robert P. Badrak
Publication Date: 2023
$20.00

Additive manufacturing (AM) is a term that is used to describe a family of processes that adds material in a controlled way to produce a structure or product. It has been used for many years for polymeric materials and its origin can be traced to Japan in the early 1980’s. The industrial use of AM polymeric products, then commonly introduced as stereolithography, got its start from an invention using a computer-controlled laser beam to harden a liquid polymer by Charles Hull in 1983.
Picture for Corrosion Testing of Carbon Steel and 13Cr Casing Materials in Simulated Superhot Deep Geothermal Well Environment
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Corrosion Testing of Carbon Steel and 13Cr Casing Materials in Simulated Superhot Deep Geothermal Well Environment

Product Number: 51324-20903-SG
Author: Sigrun Nanna Karlsdottir; Gifty Oppong Boakye; María Ýr Þráinsdóttir; Erlend Straume; Andri Ísak Þórhallsson
Publication Date: 2024
$40.00
Major challenges are encountered in the design and construction of deep superhot (>300°C) geothermal wells due to higher temperatures and pressure, and increased corrosiveness of the geothermal fluid. The corrosiveness of the geothermal fluid is due to the chemical composition which includes corrosive gases such as HCl, H2S and CO2. In this study L80-type 1 carbon steel and L80-13Cr stainless steel API casing materials were tested in a simulated superhot geothermal well environment at 350°C in water with Cl, H2S and CO2 for 168 hrs. in both vapor and liquid phases in high temperature and high pressure (HTHP) autoclave to investigate their corrosion behavior. The results showed that both API casing materials, L80-type 1 and L80-13Cr, were prone to corrosion attack in the simulated superhot deep geothermal well environment. The L80 grade Type 1 carbon steel tested in the liquid phase exhibited the highest corrosion rate and demonstrated vulnerability to localized corrosion or cracking in both liquid and vapor phases. Similarly, the L80 grade 13Cr stainless steel is not considered a suitable choice for harsh environments rich in H2S, CO2, and Cl at superheated temperatures. While it was prone to localized corrosion, it exhibited a low uniform corrosion rate (<0.1 mm/year).
Picture for Corrosion Testing of Coating Materials for Geothermal Turbine Application
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Corrosion Testing of Coating Materials for Geothermal Turbine Application

Product Number: 51317--9185-SG
ISBN: 9185 2017 CP
Author: Kolbrun Ragnarsdottir
Publication Date: 2017
$20.00

Development is needed for new materials to extend the life/reliability of surfaces used in geothermal turbines. Results of Tests and inspection of coatings on low carbon steel including; visual inspection, microstructural and chemical composition analysis with scannoing electro microscopy and energy dispersive x-ray spectroscopy.
Picture for Corrosion Testing of Coatings in Simulated ORC Geothermal Heat Exchanger Environment
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Corrosion Testing of Coatings in Simulated ORC Geothermal Heat Exchanger Environment

Product Number: 51323-19444-SG
Author: Sigrun Nanna Karlsdottir, Adolph Jr. Manadao Bravo, Gifty Oppong Boakye, Halldór Pálsson, Andri Stefánsson
Publication Date: 2023
$20.00

Organic Rankin Cycle (ORC) geothermal power plants are commonly used in low-to-medium temperature fields with temperatures below 200 °C . The utilization of geothermal fluids to generate geothermal power or heating for district systems can be difficult due to dissolved species and gasses in the fluid. The problems often encountered are due to scaling and corrosion which are dependent on the pH, salinity, and composition of the geothermal fluid (e.g., CO2 and H2S) .
Picture for Corrosion testing of CRA in simulated CO2 injection well environments
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Corrosion testing of CRA in simulated CO2 injection well environments

Product Number: 51323-18993-SG
Author: Gaute Svenningsen, Bjørn Helge Morland
Publication Date: 2023
$20.00

The number of CCS projects (planned and in operation) is increasing, and project developers need to provide firm evidence that the proposed material is suitable for these applications.
The petroleum industry has long experience with materials selection for wells, but the conditions for CO2 injection wells are somewhat different from “conventional” oil and gas wells. This is due to the high CO2 content and pressure (up to several hundred bar) which results in low pH condensed water (exact value depends on pressure and temperature, but approximately pH 3.0).
Picture for Corrosion Testing Of Graphene-Oxide-Polymer Coatings For Geothermal Drilling Applications
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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.
Picture for Corrosion Testing of PM HIPed UNS N06625 and PM HIPed UNS R56400 in Geothermal Environment at Hellisheidi Site
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Corrosion Testing of PM HIPed UNS N06625 and PM HIPed UNS R56400 in Geothermal Environment at Hellisheidi Site

Product Number: 51321-16708-SG
Author: Andri Isak Thorhallsson; Raja Khan; Malallah Al Lawati; Dagur Ingi Olafsson; Sandeep Irukuvarghula; Alessandro Sergi; Saemundur Gudlaugsson; Svava Davidsdottir; Helen Osk Haraldsdottir
Publication Date: 2021
$20.00
Picture for Corrosion under Hot Dilute Acidic Pre-Hydrolysis Biorefining Process
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Corrosion under Hot Dilute Acidic Pre-Hydrolysis Biorefining Process

Product Number: 51320-15438-SG
Author: Minkang Liu, Yimin Zeng, Xue Han , Jing-Li Luo
Publication Date: 2020
$20.00

Hot dilute acidic pre-hydrolysis biorefining is a pre-treatment technology recently developed for converting raw biomass materials into sugar streams and other valuable intermediate chemicals at elevated temperatures. However, corrosion database of steels and alloys in hot dilute acidic solutions are very limited, resulting in the cost-effective selection of materials of construction difficult. Corrosion studies were thus performed to identify suitable alloys of construction and advance the understanding of how alloying elements (e.g., Cr and Mo) present in steels and alloys affect the formation and properties of surface oxides. In this paper, the corrosion performance of three alloys (UNS S31603, UNS S32101 and UNS N06625) in hot dilute sulfuric acids are introduced. The alloys exhibited active general corrosion and even pitting in the hot acidic solutions. Alloy 625 has better resistance to the hot dilute acid compared to SS 316L and duplex 2101. This may be attributed to the higher contents of Mo in the alloy. Long-term tests indicate that their corrosion rates are gradually increased with time. The introduction of 100 ppm Cl- from raw biomass feedstocks into the acid solution only has marginal effect on corrosion. 
Picture for Corrosion under Hydrothermal Liquefaction Biorefining Process
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Corrosion under Hydrothermal Liquefaction Biorefining Process

Product Number: 51320-15439-SG
Author: Minkang Liu, Yimin Zeng, Xue Han, Jing-Li Luo
Publication Date: 2020
$20.00

The corrosion modes and extents of three candidate alloys (UNS S31603, UNS S31000 and UNS N06625) was investigated under simulated hydrothermal liquefaction (HTL) conditions. The effect of alkaline catalysts (K2CO3), operating pressure and flow rate on corrosion was also examined. Results indicated that the three alloys underwent general oxidation in hot pressurized water, of which SS 316 exhibited worse corrosion resistance compared to SS 310 and Alloy 625. The addition of K2CO3 resulted in a significant increase in the corrosion rates of the alloys, likely due to the formation of soluble metal hydroxides in basic environment. Environmental loop tests showed that higher operating pressure led to a marginal increase in the corrosion rates of SS 310 and Alloy 625. Increasing flow rate from 9 to 15 had no noticeable effect on the corrosion rates of the alloys in hot pressurized water at 310 C and 10 MPa.  
Corrosion Under Insulation (CUI) Management – A Case History
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Corrosion Under Insulation (CUI) Management – A Case History

Product Number: 51219-196-SG
Author: David A. Hunter
Publication Date: 2019
$20.00

Pond investigated pressure vessel tank failures which are causing recurring maintenance of $250,000 per year. This challenging project had limitations of space, operational time pressures/vessel availability requirements, cost and replacement variables. This presentation will chronical problems and discuss best practices of specifications, material selection, surface preparation, and application inspection that would have prevented the aforementioned outcome. This paper discusses the fundamentals of composite coatings, industry accepted design standards for their use, and examples of typical uses for these materials that solve problems in varied industries.
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