AMPP Store - Individual Conference Papers

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External Chloride Stress Corrosion Cracking (Cl-SCC) of Valve Bonnet 304 Austenitic Stainless Steel Stud Bolts

Product Number: 51324-21176-SG

Author: Iyad Al-Buraiki; Mohammed Abu Alsaud; Yousif AlRabie

Publication Date: 2024

$40.00

Chloride stress corrosion cracking (Cl-SCC) is known to occur in austenitic stainless steels operating at temperatures above 60 °C (150 °F). This paper, however, will discuss external Cl-SCC failures that occurred at ambient conditions. These failures occurred in stainless steel grade 304 bolts used as valve bonnet stud bolts. The failure caused total disengagement of the valve bonnet. These valves were located approximately 1 km from the seashore. In addition, the valves were located underneath a seawater deluge system used for fire protection which was periodically tested resulting in the valves being wetted by seawater. This paper provides details related to the materials, environmental conditions and mechanical properties of these bolts and provides recommendations to avoid such failures in the future.

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External Corrosion Behavior of Oil Pipelines With Polyethylene Coating Under Pressure Fluctuations

Product Number: 51319-13199-SG

Author: Yanping Li

Publication Date: 2019

$20.00

External corrosion on buried pipe steels has been demonstrated to be a major threat to pipeline integrity. Although it has been extensively investigated and well understood electrochemically there is no particular model that is widely accepted by industry due to the complex nature of external corrosion. This paper demonstrates that the severity of external corrosion on polyethylene (PE) tape coated oil pipe is exacerbated by proximity downstream of pump stations and suggests mechanistic explanations related to pressure fluctuations. There are very limited studies available on this topic for buried liquid pipelines.External corrosion features reported by the most recent In-Line Inspection (ILI) ultrasonic wall measurement (UTWM) tools for two oil pipelines were correlated with the distance to upstream (U/S) pump stations. ILI data with UTWM is used because the data includes features that are under sleeve. These two oil pipelines with PE coating were investigated for a total length of about 2500 km. The pipelines have been in service for more than 40 years.Analysis of the results shows that external corrosion features with a depth <20% wall thickness (WT) reported by UTWM tools are distributed uniformly along the pipelines. However a clear increase in the frequency of corrosion features with depth >=20%WT is seen within 10 km from the U/S pump station. There is a much more pronounced increase in the density of deeper feature classes in the same region. This trend is further validated by the distribution of field nondestructive examination (NDE) excavations driven by external corrosion. Based on these data it is undeniable that the frequency and severity of external corrosion on these tape coated pipelines is positively correlated to U/S pump station proximity.Possible mechanisms may include mechano-electrochemistry and pressure fluctuations that facilitate electrochemical processes and/or PE tape coating damage: 1) Pressure fluctuations increase dislocation density and thus electrochemical potential ahead of corrosion tip due to stress concentration. 2) Pressure fluctuations may refresh the electrochemical environments inside corrosion and thus accelerating corrosion. 3) The PE coating damage accelerated by pressure fluctuations could contribute to the external corrosion distribution. One of the benefits of the findings in this paper is to help External Corrosion Direct Assessment (ECDA) to locate severe corrosion features especially for the lines that are non-piggable. Also the discoveries can provide guidance for future research and pipeline integrity management with external corrosion.

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External Stress Corrosion Cracking Of In-Situ Carbon Steel Pipelines

Product Number: 51322-17682-SG

Author: Duane Serate, Matthew Krantz, Yashar Behnamian, Haixia Guo, Simon Yuen, Victor Itulua

Publication Date: 2022

$20.00

There are hundreds of kilometers of above-ground carbon steel pipelines located in 32 in-situ oilsands facilities operated by 18 producers in Alberta Canada, with a total thermal oilsands capacity (operating) of 1.8 million barrels per day. A typical in-situ oilsands operation is for recovering bitumen located 75 meters or more below the surface, by the injection of steam.

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Extreme high-speed laser application of coating to prevent hydrogen embrittlement in metals

Product Number: 51323-19546-SG

Author: Yingwei Wu, Josh Barras, Jhonattan Gutjahr, Carl Hauser, Yuanbo T. Tang, Roger C. Reed, W. Mark Rainforth

Publication Date: 2023

$20.00

Hydrogen as a promising alternative energy source that is forecasted to potentially transform future power generation toward new-zero. However, its widespread adoption has proven challenging owing to difficulties around storage, transportation, and usage due to catastrophic failures i.e. hydrogen embrittlement (HE). This is particularly severe for high-strength structural steel that must be designed against fatal fractures; it is also relevant to parts that are not designed for hydrogen exposure due to the prevention of accidental spill or leakage.

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Facilitating the Use of Leak Detection Sensors Using Web-Based Remote Monitoring

Product Number: MECC23-20309-SG

Author: Jamey Hilleary

Publication Date: 2023

$20.00

Pipeline leak detection is emerging as a prime focus of Pipeline and Hazardous Materials Safety Administration (PHMSA) and other regulatory agencies in the United States as well as jurisdictions all over the world. The immense volume of buried pipelines and the fact that much of this buried infrastructure is over forty years old1 combine to present increasing risk of leaks with potentially catastrophic results. During the twenty-year timespan from 2002 through 2021, in the United States alone, the Pipeline and Hazardous Materials Safety Administration (PHMSA) recorded 42 hazardous liquids incidents resulting in 35 fatalities, 80 injuries, and over 147,000 barrels spilled (Figure 1).

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Facilitating the Use of Leak Detection Sensors Using Web-Based Remote Monitoring

Product Number: 51323-18884-SG

Author: Jamey Hilleary

Publication Date: 2023

$20.00

Pipeline leak detection is emerging as a prime focus of PHMSA and other regulatory agencies in the United States as well as jurisdictions all over the world. The immense volume of buried pipelines and the fact that much of this buried infrastructure is over forty years old1 combine to present increasing risk of leaks with potentially catastrophic results. During the twenty-year timespan from 2002 through 2021, in the United States alone, the Pipeline and Hazardous Materials Safety Administration (PHMSA) recorded 42 hazardous liquids incidents resulting in 35 fatalities, 80 injuries, and over 147,000 barrels spilled. In many cases the environmental and human health and safety costs could have been reduced if the leaks were detected much earlier.

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Factors Affecting the Performance of Epoxy Coatings in Cathodic Disbondment Testing

Product Number: 51218-107-SG

Author: Matt Fajt

Publication Date: 2018

$20.00

This paper will cover cathodic disbondment, dry film thickness, peak height and coating evaluation for failures.

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Factors Affecting Impact Toughness in Carbon Steels

Product Number: 51319-13361-SG

Author: Sangeetha Cathapuram

Publication Date: 2019

$20.00

Over the last five years there have been numerous reports of failures of carbon steel A105 flanges A234 fittings and some A106 seamless pipe. The failure primarily occurred in newly constructed material and the nature of the failures was Brittle Fracture with very low Charpy V-notch values (3 ft-lbs) at room temperatures when the expected notch toughness was higher than 40 ft-lbs. Typically these steels are exempted from impact testing for upto temperatures -20°F (-29°C) per ASME B31.3. It has been found that the cause of low toughness was a gradual change in the chemical composition of the steel during the steel making process primarily low Mn to C ratios (even though within specification limits) addition of alloying elements like boron vanadium kind of heat treatment applied grain size etc.This paper will identify and document how the different factors like low Mn high C addition of boron and resultant grain size affects the impact toughness of steels based on a review of currently available literature. A comparison with impact properties of other product forms of carbon steel like plates etc. will be presented. A review of the current industry best practices and recommendations to avoid brittle fracture due to metallurgical factors without affecting other mechanical properties during hydrostatic testing cold startups and other low temperature in service conditions will be documented and presented.

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Factors Affecting Vapor Phase H2S Concentrations in Asphalt and Mitigation via Scavengers

Product Number: 51317--9449-SG

ISBN: 9449 2017 CP

Author: Kyle Cattanach

Publication Date: 2017

$20.00

This work will examine and document the conditions that influence the phenomena of H2S generation, and generate quantitative data on the H2S removal performance of the oil soluble fully dispersible transition metal chemistry based H2S scavenger product line.

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Factors Determining the Size of Projects

Product Number: 41207-304-SG

Author: Ralph Baliunas, Louis G. Lyras

Publication Date: 2007

$20.00

This paper identifies the problems with large multi-year painting projects and discusses the benefit to Facility Owners and Contractors for breaking a large bridge project into smaller phases. It will also discuss factors that determine the optimum size, large or small, of a painting project and their impacts. The size of a project will be analyzed from the standpoint of money, time, insurance, bonding, manpower, inspection, management, bridge inventory and job quality.

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Factors for Selecting Thermal Insulation Materials to Prevent Corrosion Under Insulation

Product Number: 51319-12952-SG

Author: Kentaro Mizushima

Publication Date: 2019

$20.00

Many types of thermal insulation materials are used in oil and gas plant facilities. Recently new materials have been developed to prevent corrosion under insulation (CUI) and even the conventional materials have been improved their properties to provide better protection.When designing a plant measures to prevent CUI are studied when verifying the materials of construction determining the protective coatings systems and selecting thermal insulation and jacketing materials. Measures to prevent CUI should not be considered separately for these but rather together as a total system. Recently though while protective coatings have been studied by users coating manufacturers and independent organizations such as testing laboratories engineering firms and consultants there has been little investigation of the ability of thermal insulation materials themselves to prevent CUI.In this study the ability of various thermal insulation materials to prevent CUI in a simulated severely corrosive environment were examined. The factors influencing CUI prevention or aggravation were identified based on which it was recommended that these factors be considered when selecting thermal insulation materials during the design of a plant. As a summary of this study experiences of design of plants and related other CUI studies effective ideas relating to protective coatings thermal insulation and jacketing materials for preventing CUI will be shared.

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Factors In Galvanic Corrosion Between Steel And Iron Sulfides In Acidic Solutions

Product Number: 51322-17827-SG

Author: Payman Sharifi Abdar, Bruce Brown, Srdjan Nesic

Publication Date: 2022

$20.00

H2S corrosion, also known as sour corrosion, is one of the most researched types of metal degradation in oil and gas transmission pipelines requiring a wide range of environmental conditions and detailed surface analysis techniques. This is because localized or pitting corrosion is known to be the main type of corrosion failure in sour environments which caused 12% of all oilfield corrosion incidents according to a report from 1996. Therefore, control and reduction of this type of corrosion could prevent such failures in oil and gas industries, and significantly enhance asset integrity while reducing maintenance costs as well as eliminating environmental damage.

Individual Conference Papers

Association for Materials Protection and Performance