AMPP Store - Individual Conference Papers

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Handling Extreme Environments With Supoxy Platform Technology

Product Number: 51322-17643-SG

Author: Justin Manuel, Chad Remy

Publication Date: 2022

$20.00

One can find some of the most aggressive and corrosive environments for coatings in the process work and equipment functions for Oil and Gas Upstream facilities. These conditions have typically been handled using traditional coating options such as vinyl esters, epoxies, or baked phenolic linings. While these products are often tailored to environments with elevated temperatures and pressures found within upstream and “downhole” oil and gas production, the inception of new drilling techniques and the discovery of new shale basins has morphed the landscape of corrosive environments in this market.

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Hard Truths about Concrete Polishing

Product Number: 41212-702-SG

Author: Joe Reardon

Publication Date: 2012

$20.00

The benefits of concrete floor polishing include creation of a durable finish with modest maintenance requirements and compliance with principals of green construction. At the same time, however, there must be rigorous adherence to proper procedures in the creation of a concrete polished finish. The presentation describes the benefits of polished concrete and explains what can go wrong and why it sometimes happens.

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Hardness And Nickel-Based Alloys

Product Number: 51323-18806-SG

Author: Robert Badrak, Julia Botinha, John Groth, Helena Alves

Publication Date: 2023

$20.00

This paper addresses the relationship between hardness and environmental cracking resistance in nickel base alloys. The work here builds on the presentation made to AMPP’s SC08 Fall 2021 meeting on October 19th.

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Heat buildup for Thermally Insulative Coatings due to Solar Exposure: Efforts in Modeling and Prediction

Product Number: 51323-19496-SG

Author: Nathan R. McCormick, Victoria J. Gelling

Publication Date: 2023

$20.00

Human safety is at the forefront of industrial concerns, with manufacturers needing to comply with multiple standards globally and regionally. One such concern is ensuring that those working in close contact with surfaces of elevated temperature are protected against injury and burns. You will find that many will reference the fact that the U.S. Occupational Safety and Health Administration (OSHA) has set a limit of safe temperature for skin contact at 140°F (60°C) and state that these limits were set since no damage would occur during five seconds of exposure.

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Heat Treatment of Heat Exchanger U-bends - Practices on Different Materials and Case Histories of Failures

Product Number: 51324-20815-SG

Author: Shahab Soltaninia; Zesan Ardaniel; Cathleen Shargay; Sarah Radovcich

Publication Date: 2024

$40.00

There is currently confusion and differing practices being specified by purchasers, Shell-and-Tube Heat Exchanger (S&T HX) fabricators and/or U-bend suppliers regarding when and how to heat treat tubing U-bends. The need for Heat Treatment (HT) varies based on the material, service, and tightness of the bend (i.e., the degree of strain). The methods used for heat treating are typically furnace or Electric-Resistance (ER). This paper first summarizes the international codes and standards requirements for S&T HX U-bend heat treatment. Next it provides the highlight of some industry studies and compiles case histories of U-bend failures from literature and conference minutes. The overall goal for this paper is to propose possible initial changes to the relevant standards with future changes being added after the additional testing.

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Hexacyanoferrate-Intercalated Layered Double Hydroxides As Nano-Additives For Detection Of Early-Stage Corrosion Of Steel

Product Number: 51321-16740-SG

Author: M. Wilhelm; M. Reyes; A. Sushkova; J. Yang; B. Wabende; M. Pilz; R. Martins; S. Loureiro; C. Simon; J. Tedim

Publication Date: 2021

$20.00

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HFW Pipe Seam Screening Test For Susceptibility To Hydrogen Embrittlement

Product Number: MECC23-20105-SG

Author: Saad M. Al-Muaili; Mohammed Al-Anezi; Khalid A. Babakri

Publication Date: 2023

$20.00

HFW pipes is considered a cost-effective pipe option for oil and gas pipeline projects. The HFW seam performance is always a concern, especially in challenging environments such as low temperature applications and wet sour services. One of the challenges include the seam properties to resist sulfide stress cracking (SSC) or hydrogen embrittlement (HE) when exposed to hydrogen charging environment such as a wet sour service.

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Hibernation of Ducts with CRA Alloys: Standardization of Methods for the Chemical and Microbiological Composition of Operation Seawater

Product Number: 51324-20678-SG

Author: Walter Cravo; Flávia Maciel Fernandes Guedes; Maíra Paula de Sousa; Vinicius de Abreu Waldow; Luiz André Lucas Teixeira Pinto

Publication Date: 2024

$40.00

The work aimed to standardize the initial chemical and microbiological composition of seawater used in hibernation studies, due to the seasonality to which these waters are subject throughout the year. Bioaugmentation vs. biostimulation techniques were tested to increase microbial growth and test seawater with greater biocorrosive potential, obtaining more conservative results. Different seawater samples off the coast of Rio de Janeiro/Brazil were tested to validate the experimental model. Cultivation and molecular biology techniques were used for microbial monitoring. At the same time, the concentration of dissolved oxygen in the standardized fluid was monitored. The biostimulation technique was the most appropriate, maintaining a high bacterial concentration throughout the experiment. Population analysis by metagenomics revealed the presence of bacterial groups that promote biocorrosion in all waters and a change in the population profile over time, revealing the adaptability of certain groups. The oxygen concentration decreased over time reaching ppb levels.

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HIC Resistance Testing of Flexible Pipes Pressure Armor in H2S-Containing Environments

Product Number: 51319-13368-SG

Author: Jonas Sá

Publication Date: 2019

$20.00

Flexible pipes may be exposed to high pressures during deep-water operation. Pressure armor layer is designed to withstand the hoop stress that is caused by the inner fluid pressure. It is wound around an internal polymer sheath to isolate it from production gases and fluids. However wear and tear damage or even diffusion may cause gas or fluid buildup in the annulus exposing the pressure armor to environments that may contain H2S. Depending on the mechanical properties and microstructure of the steel the absorption of hydrogen generated by corrosion in a H2S-containing environment can lead to the failure of these layers. Hydrogen induced cracking (HIC) tests will be carried out in H2S-containing environments in order to assess the resistance to HIC of two pressure armor wires (with distinct microstructures). The tests will be carried out for different durations in order to investigate crack growth. After each test the specimens will be examined by visual and ultrasonic inspection followed by sectioning of the specimens at any suspicious regions with subsequent metallographic examination of the cut faces.

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High Accuracy Ultrasonic Corrosion Monitoring

Product Number: 51317--8990-SG

ISBN: 8990 2017 CP

Author: Fangxin Zou

Publication Date: 2017

$20.00

Permanently installed transducers have improved the precision of ultrasonic inspection by orders of magnitude and provide an accurate non-invasive alternative to other corrosion monitoring methods.

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High Density Polyethylene (HDPE) Installation Challenges and Recommendations

Product Number: MECC23-20096-SG

Author: Abdulrahman F. Alghannam, Abdulrahman A. Alzarah, Loai M. Alowa

Publication Date: 2023

$20.00

High-density polyethylene (HDPE) is a thermoplastic polymer that with the application of heat and pressure can form desirable shapes. HDPE is defined as a polyethylene containing very few short-chain branches (< 4 per 1,000 carbon atoms), having a density greater than 0.940 g/cm3 [1]. HDPE pipes have been used around the world in different fields, such as fire water, potable water, seawater, waste water, oil, and gas services.

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High Level Corrosion Risk Assessment Methodology For Refined Hydrocarbon Products

Product Number: 51319-13047-SG

Author: Mushaid Nauman

Publication Date: 2019

$20.00

Assessing corrosion risks and developing inspection and mitigation measures forms a vital part of any Asset Integrity Management (AIM) system. Improving asset reliability is crucial as the risks attached with the asset failure can be catastrophic in terms of human life environment and monetary loss. Knowledge about the asset degradation mechanisms affects critical decisions regarding maintenance inspection regimes and investment plans. Typically less than 10% of assets carry 95% of the risk thus making higher knowledge of individual “asset” integrity key to minimizing risk across any one business system. Achieving this highest possible performance of an asset against the lowest possible costs whilst ensuring safe operation is a challenge faced by many operators. Most of the emphasis from operators is given to upstream and processing facilities that hold a valid high in service deterioration risk because they face harsh and corrosive conditions. However the facilities installed downstream in particular the storage and transport of refined hydrocarbon products are often considered in the same “fit and forget” philosophy. Operators often apply makeshift solutions in case of any failure but problems can recur which besides denting the operational excellence can affect the environment and safety.Refined hydrocarbon products such as Jet A1 LPG and ULG 91/95 etc. are not generally corrosive to the metals and alloys that are used for their storage and transport; however they do contain dissolved water organic sulphides and oxygen containing compounds that can cause corrosion over the time. Conventional corrosion prediction models are not relevant since the acid gases are not present. In order to overcome this limitation and to allow corrosion risk assessment of both existing and aging facilities an alternative in-house corrosion risk assessment methodology has been developed. This methodology helps in order to dilute the corrosion risks associated with these facilities in a well-structured process as practiced for one of the major operators in the Middle East. This paper discusses the methodology used to model the corrosion rates and risk assessment involving both probability and consequences within these product streams.Key Words: jet A1 unleaded gasoline (ULG) liquefied petroleum gas (LPG) oxygen flowrate carbon dioxide (CO2) hydrogen sulphide (H2S)

Individual Conference Papers

Association for Materials Protection and Performance