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3228 total products found.
Picture for Metal Dusting Resistance Of Nicrmocu Alloy And Its Weld Overlay Under High Pressure Condition
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Metal Dusting Resistance Of Nicrmocu Alloy And Its Weld Overlay Under High Pressure Condition

Product Number: 51322-17570-SG
Author: Bingtao Li, Vinay Deodeshmukh, Clara Schlereth, Anke S. Ulrich, Mathias C. Galetz
Publication Date: 2022
$20.00

Many industrial processes contain H2, CO, CO2, and H2O gas mixtures, such as syngas production and processing in hydrogen, ammonia, and methanol plants. These process environments have high carbon activity, i.e. ac > 1, and low oxygen partial pressure at their elevated operating temperatures, such as in the temperature range of 400-800 °C (752-1472 °F). The high carbon activity could result in a catastrophic material degradation, i.e. metal dusting. The resulting corrosion products consist of carbon or graphite and metal particles, along with possible carbides and oxides, and cause material disintegration.
NoP Commerce Standards image
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SSPC-AB 1-2019, Mineral and Slag Abrasives

Product Number: SSPC-AB 1-2019
Publication Date: 2019
$109.00
Picture for Characterization and Control of the Intergranular Corrosion Defects in a 2024 T351 Aluminium Alloy
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Characterization and Control of the Intergranular Corrosion Defects in a 2024 T351 Aluminium Alloy

Product Number: 51317--9427-SG
ISBN: 9427 2017 CP
Author: Marie-Laetitia de BONFILS-LAHOVARY
Publication Date: 2017
$20.00

This work aims to understand and characterize intergranular corrosion phenomena in order to develop and optimize an engineering test to determine the propagation kinetics of intergranular corrosion defects in a 2024-T351 aluminium alloy.
Picture for Dissimilar Tube-to-Tube Sheet Welding Challenges - A Case Study
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Dissimilar Tube-to-Tube Sheet Welding Challenges - A Case Study

Product Number: 51324-21022-SG
Author: Prabhu Bala; Krishnan Sivaraman
Publication Date: 2024
$40.00
A heat exchanger is a device used to transfer heat between two or more fluids and it is an integral part of any oil and gas refinery. Tube-to-tube sheet welding is the most critical activity in fabricating this equipment [1]. There are many factors which needs to be considered to produce a highly reliable weld joint. These factors include the type of the joint, weld joint design, selection of suitable filler wire, and robust inspection plan deployed during fabrication [1]. The task of selecting a suitable filler wire becomes much more challenging when the heat exchanger consists of dissimilar tube to tube sheet weld joints. This paper discusses a case study on the filler metal selection methodology followed for the dissimilar tube-to-tube sheet welding of SB163 UNS N08935 (With 35% of Ni) tube to Alloy 400 clad tube sheet for one of the heat exchangers
Picture for Effect of Oxygen in Back Purging Gas on Corrosion Resistance of Super Duplex Welded Joints
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Effect of Oxygen in Back Purging Gas on Corrosion Resistance of Super Duplex Welded Joints

Product Number: 51324-21111-SG
Author: Tatiana C. Almeida; Rogaciano M. Moreira; Merlin C. E. Bandeira; Oscar R. Mattos; Flávia M. F. Guedes
Publication Date: 2024
$40.00
Several offshore pipelines in Pre-salt fields, Brazil, are made of Super Duplex stainless steel. When welded, in general, these materials present a decrease in its corrosion resistance. Welding procedures, materials properties, surface conditions and post-weld treatment have influence on the resistance to local corrosion Although there is a strict control regarding the contamination of back purging gas with oxygen, sometimes, this control may fail and the oxygen content may exceed this limit. Understanding if the pitting corrosion resistance is affected by a higher oxygen level and how a post-weld surface treatment by pickling and passivation can improve the corrosion resistance is important in situations where the control of oxygen content is limited. In the present study, specimens welded with back purging gas containing 100 ppm and 200 ppm of oxygen and without back purging gas were investigated through ASTM (1) G48- A, and through ASTM G48 method E6. The pitting resistance was improved after post-weld surface treatment for super duplex stainless steel.
Picture for On the Sea Water Corrosion Resistance of Alloy 825 CTP (UNS N08827), an Improved Version of Alloy 825 (UNS N08825)
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On the Sea Water Corrosion Resistance of Alloy 825 CTP (UNS N08827), an Improved Version of Alloy 825 (UNS N08825)

Product Number: 51324-20983-SG
Author: Julia Botinha; Katharina Utens; Philipp Huebner; Daniela Zander; Helena Alves
Publication Date: 2024
$40.00
UNS(1) N08827, commercially called Alloy 825 CTP(2), represents a significant advancement of UNS N08825 (Alloy 825)(2) by virtue of its tailored chemical composition, resulting in enhanced localized corrosion resistance. The key modification in UNS N08827 involves a notable augmentation in molybdenum content, which has been raised to approximately 6%, twice the amount found in the conventional UNS N08825, which contains 3% molybdenum. Consequently, this alloy surpasses a critical threshold for the pitting resistance equivalent number (PREN) by exceeding 40, a prerequisite for specific applications within the oil and gas sector. Prior investigations have already demonstrated the heightened resistance of UNS N08827 to pitting and crevice corrosion when exposed to ferric chloride solutions, as evidenced by ASTM(3) G48 C and D tests. Building upon this foundation, the subsequent objective was to assess the corrosion performance of this alloy in an artificial seawater environment. This research paper presents the outcomes obtained from subjecting Alloy 825 CTP UNS N08827 to ASTM G61 and ASTM G150 tests, focusing on its corrosion behavior.
Picture for Evaluation of Corrosion Inhibitor Gel Filler Retention in Shorted Casings: A Pressure Test Study
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Evaluation of Corrosion Inhibitor Gel Filler Retention in Shorted Casings: A Pressure Test Study

Product Number: 51324-21135-SG
Author: Juan Dominguez Olivo; Alexander Roytman; Mikhail Ivanov; Terry Natale; Yefim Vaks
Publication Date: 2024
$40.00
Pipelines casings regulated by PHMSA require the mitigation of shorted casings. One method that aligns with the PHMSA guidelines is the utilization of NACE SP0200. This standard recommends using a corrosion-inhibiting gel filler that transforms from the viscosity of water to a high-viscosity gel, providing effective sealing and corrosion protection. However, concerns exist regarding the potential loss of the inhibitor filler during its application. While some operators opt for pneumatic pressure tests instead of hydrotests to minimize contamination and reduce costs, the rapid loss of pressure in a pneumatic test does not equate to a rapid loss of corrosion inhibitor gel. To address this concern, a custom-designed pressure chamber was employed to simulate casing defects ranging from 5 to 13 mm in the worst-case scenario (6 o'clock position). Corrosion inhibitor gel filler was injected into the chamber and then pressurized to a maximum of 20 psia (~1.4 bar). The pressure was released through the different simulated defects and the corrosion inhibitor filler loss was recorded. The study revealed that inhibitor retention remained satisfactory. In the worst-case scenario, the maximum loss of corrosion inhibitor gel filler recorded was approximately 1 to 5% of the injected solution.
Picture for Developing Vapor Phase Corrosion Inhibitors for Aluminum Alloys in Ethylene Glycol Coolant Solutions
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Developing Vapor Phase Corrosion Inhibitors for Aluminum Alloys in Ethylene Glycol Coolant Solutions

Product Number: 51324-20382-SG
Author: Behzad Bavarian; Lisa Reiner
Publication Date: 2024
$40.00
Different vapor phase corrosion inhibitors were evaluated to determine their corrosion inhibition for aluminum alloys in Ethylene glycol (C2H6O2) coolant mixture. When the temperature exceeds 80°C, ethylene glycol can decompose into organic acids. The resulting acidic environments cause severe localized corrosion of aluminum alloys. The corrosion behavior was studied at multiple temperatures in different corrosion inhibitors using different concentrations. Corrosion inhibitor VCI-A, VCI-B, VCI-C, and VCI-D at 2.5-3.0% dosage showed excellent corrosion protection. VCI-A, VCI-C and VCI-D maintained a steady, low corrosion rate during long term exposure by neutralizing pH and forming a hydrophobic film. They increase the polarization resistance by a significant factor, therefore, lowered corrosion rate. VCI-B inhibitor, also showed the ability to reduce the corrosion rate of aluminum in ethylene glycol solutions. However, due to its high pH chemistry, the effective dosage should be maintained at <2.5% to avoid any potential increase in pH that can promote localized corrosion or under-deposit corrosion attacks of aluminum alloys. The results of this investigation demonstrated that these inhibitors can lower the corrosion rate in water-ethylene glycol solutions by neutralizing pH and forming stable films.
Picture for Concrete Structures in Wastewater Environments: Key Considerations for Substrate Repair and Surface Preparation for Protective Coatings/Linings Applications
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Concrete Structures in Wastewater Environments: Key Considerations for Substrate Repair and Surface Preparation for Protective Coatings/Linings Applications

Product Number: 51324-20364-SG
Author: Brian Cheshire; Vaughn O'Dea
Publication Date: 2024
$40.00
Concrete is the most predominately used construction material for wastewater collection and treatment facilities. Nevertheless, there are still many questions and misconceptions on how to properly evaluate this substrate prior to commencing a coating or lining project. Knowing how to address any defects or necessary repairs is imperative for all projects, but in many cases, some of these repairs or details are omitted. In turn, questions still arise from the field on how to properly prepare these surfaces. Answering these questions is a vital task, as surface preparation is a major component in the successful installation of protective linings or polymer concretes. The main goal for any concrete coating project is the long-term protection of the substrate from corrosive and physical forces, which cannot be achieved without all these key steps taking place prior to placing the asset into immersion or chemical containment service. In summary, this paper will review the common forms of concrete attack mechanisms that occur in wastewater environments and will also review current industry best practices to repair (and prepare) concrete prior to the application of polymer concretes or high-performance protective linings. Some select case histories will be discussed in order to illustrate some of the concepts covered throughout the paper.
Picture for An Environmental Performance Comparison of Premium Vs. Standard Grades Used in Non-Magnetic Drill Collars
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An Environmental Performance Comparison of Premium Vs. Standard Grades Used in Non-Magnetic Drill Collars

Product Number: 51324-20685-SG
Author: Flavia Kudla; Manuel Marya
Publication Date: 2024
$40.00
Non-magnetic drill collar (NMDC) alloys are (Cr-Mn/Cr-Mn-Ni)-Mo-N proprietary austenitic stainless steels that meet minimum API Specification 7-1 requirements. Among NMDC alloys, a wide range of chemical compositions and environmental performance exist with similar mechanical requirements. NMDC alloy proprietary compositions may be grouped into premium and standard grades and, depending on the product and operation requirements, the drilling conditions may lean more towards one group versus the other. This paper evaluates and compares the corrosion performance of representative alloys from these two groups in terms of weight-loss corrosion, localized corrosion, and environmentally assisted cracking in two simulated drilling muds. The test program accounts for different levels of chlorides, dissolved oxygen, brine pH, and temperature, in order to reproduce corrosion in the environment(s) and temperature(s) representative of field jobs. This investigation aims to understand and identify corrosion and cracking limits of the alloys from the premium and standard groups; and consequently, provide guidance to improve operational reliability and increase NMDCs life in the field.
Failure Analyses On A Super Duplex Stainless Steel Tube Material Before And After Slow Strain Rate Testing In Sour Conditions – Part 2: A Case Study On Local Corrosion
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Failure Analyses On A Super Duplex Stainless Steel Tube Material Before And After Slow Strain Rate Testing In Sour Conditions – Part 2: A Case Study On Local Corrosion

Product Number: 51322-18320-SG
Author: Wenle He, Raveendra Siriki, Jerry Lindkvist
Publication Date: 2022
$20.00

The investigation on the specimens in the SCC susceptible conditions is included in Part 1, AMPP conference paper C2022-179982. In this Part 2, a case study is presented on the local corrosion on specimen surface or shoulder area although high ductility ratios in two testing conditions.    
Picture for Field Experience of Various Coating Systems in Oil & Gas Industry
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Field Experience of Various Coating Systems in Oil & Gas Industry

Product Number: 51324-20360-SG
Author: Amjad Kharusi; Janardhan Rao Saithala; Mohammed Al Ghafri; Mohammed Ossama; Talal Nabhani
Publication Date: 2024
$40.00
Internal and external coatings have been used extensively for the corrosion protection of a wide range of process components such as flowlines, pipelines, piping, vessels, tanks etc. that are used in oil and gas industry. Coatings are a critical barrier as part of a corrosion management strategy and shall be capable of providing long term corrosion protection in corrosive environment. Coatings are exposed to wide range of temperatures, high pressure environments, and acid gases (H2S and CO2), and are subjected to mechanical damage, etc. during operating service life. The authors’ company has extensive experience of using various coating systems for over 40 years. Fusion bonded epoxy (FBE) coatings and glass reinforced epoxy (GRE) linings are primarily used as internal coatings, and three-layer polypropylene (3LPP), three-layer polyethylene (3LPE), thermal spray aluminum (TSA), and epoxy coatings are used as external coatings in hydrocarbon and water injection service. During design, it is anticipated that coatings will meet expected design life, however, premature coating failures are reoccurring for various reasons, which result in significant oil & gas deferment and unplanned shutdowns. This paper will present two case studies on field experience of different coating systems and contributing factors that led to premature failures. The three main contributing factors to premature failure are quality QA/QC during coating application, incorrect coating selection, and coating damage during installation.

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