AMPP Store - Conference Papers

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Detection of H2S in Oilfield Chemicals

Product Number: 51324-21181-SG

Author: Tracey Jackson; Kung-Po Chao; Ya Liu

Publication Date: 2024

$40.00

For several years chemical vendors and oilfield operators have measured H2S presumably generated in situ in oilfield products, specifically corrosion inhibitors and combination scale and corrosion inhibitors. Sometimes when handling oilfield chemicals, a personal H2S monitor will be triggered with the assumption that this response is from H2S. Since the alert is triggered in close proximity to some oilfield chemicals or even while opening the chemical container, the logical conclusion is that the product contains H2S; however, these monitors are likely detecting vapor phase water-soluble, small chain sulfur species like 2-mercapoethanol (2ME) or thioglycolic acid (TGA). Analytical methods used to measure H2S to investigate these phenomena typically use gas chromatography (GC) with high inlet temperatures to evaluate the composition of the product headspace. These high temperatures cause thermal decomposition of water-soluble organosulfur intermediates (OSIs) which can result in a H2S response. The authors have studied several such phenomena associated with oilfield products and have developed methods to investigate these phenomena to determine the cause of H2S alerts. The goal is to allow operators and chemical vendors to make informed health and safety decisions about detection devices as well as chemical products selected for oilfield service. This paper describes the methods needed to determine the true H2S content of an oilfield chemical product as well as the impact of product composition changes on personal monitor false alarms.

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Detection of Surface Contamination During a Scheduled Inspection and Repair Investigation

Product Number: 41209-488-SG

Author: Lyn Kearns, Martin Janssen, Jean-Luc Coté

Publication Date: 2009

$20.00

The Department of National Defence (DND) in Canada has implemented a revised maintenance program for aircraft weapon systems whose goal is to ensure that essential maintenance is accomplished and to assure the continued airworthiness of aeronautical products during in-service operation. The program especially affects legacy aircraft. A case study is being presented where an adhesion failure was detected during a scheduled inspection.

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Deterioration of Wastewater Treatment and Collection System Assets: Knowing Where and How to Look

Product Number: 41206-271-SG

Author: R. A. Nixon

Publication Date: 2006

$20.00

After 35 years or longer in service, the concrete infrastructure in wastewater collection systems and treatment plants has deteriorated due to various corrosion and physical degradation mechanisms. This paper reviews the major mechanisms that cause deterioration of concrete and protective coatings. Also, examples of infrastructure degradation are presented along with a discussion of the best diagnostic methods for condition assessment of concrete for the various mechanisms.

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Determination of Activation Energies for Nuclear Electrical Cable Insulation Using Density and Total Color Difference

Product Number: ED22-17336-SG

Author: D.Li, Y.Ni, A.Zwoster, M.R. Pallaka, M.Spencer, L.S. Fifield

Publication Date: 2022

$20.00

Electrical cables are critical components of nuclear power plants (NPPs) that ensure their safe operation. In use they are exposed to a wide range of environmental stresses, such as elevated temperature, gamma radiation, moisture, and electrical stress. Among the different environmental stresses, elevated temperature leads to the thermo-oxidative degradation of electrical cable insulation, which may cause early failure of electrical cables and subsequently lead to unplanned plant shutdowns, electrical transients, and/or a loss of safety redundancy.

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Determination of Corrosion Inhibitor Residuals in Dry Crude Oil

Product Number: 51323-18769-SG

Author: Talal M. Alghamdi

Publication Date: 2023

$20.00

Sample preparation is the fundamental step of any analytical procedure, which involves cleaning the sample matrix and transporting the target analytes to a more suitable matrix for instrumental analyses. This is a very critical step because it leads to achieving a better detection limits as compared of not having this step.

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Determination Of Oxygen Limits For Corrosion Resistant Alloys (Cras) In Oil & Gas Produced Water Based On Electrochemical Test Methods – Part 1

Product Number: 51322-17939-SG

Author: Roy Johnsen, Marie E. Edvardsen, Martin O. Hestvik, Cristian Torres, Jan Ivar Skar, Marion Duparc, Sven Morten Hesjevik

Publication Date: 2022

$20.00

Corrosion Resistant Alloys (CRAs) have been widely used in oil & gas process systems since the 1980s due to their excellent resistance towards uniform corrosion in aggressive environments such as seawater and produced water containing CO₂, organic acids and/or production chemicals. However, cases of localized corrosion in the form of pitting and crevice corrosion have regularly been observed. As an example, ISO⁽²⁾ 21457 limits the max. operating temperature to 20⁰C for 25 Cr super duplex stainless steel (UNS S32750/760) and 6-Mo austenittic stainless steels (UNS S31254) in chlorinated seawater systems, to avoid crevice corrosion.¹

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Determination Of Oxygen Limits For Corrosion Resistant Alloys (Cras) In Oil & Gas Produced Water Based On Electrochemical Test Methods – Part 2.

Product Number: 51322-17947-SG

Author: Marion Duparc, Roy Johnsen, Jan Ivar Skar, Tov Eivind Saxegaard

Publication Date: 2022

$20.00

Crevice corrosion is a geometrical-dependent type of localized attack that occurs in occluded regions where a stagnant and corrosive electrolyte is in contact with the surface of a passive metal^1,2. Crevices are present in all industrial designs and can lead to major failure since their detection is often challenging^3,4. Main strategies for the prevention and mitigation of crevice corrosion include design awareness and adequate materials selection⁵.

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Determination of the Acceptability Conditions for a Safe Use of Alloys UNS S32750 Through SSRT Screening

Product Number: 51321-16322-SG

Author: Vincent Duquesnes/Christophe Mendibide/Wenle He/Raveendra Siriki

Publication Date: 2021

$20.00

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Determination of the Corrosion Rate of Thermally Spayed Aluminum (TSA) in Simulated Marine Service

Product Number: 51320-14650-SG

Author: Shiladitya Paul, Dave Harvey

Publication Date: 2020

$20.00

Operators desire extended life of offshore facilities, structures and components to improve affordability, and to increase their availability in later years of operation. Whilst maintenance and replacement of topside facilities is possible, critical to this objective is the design and construction of supporting infrastructure and facilities capable of withstanding splash and tidal zone corrosion for the lifetime of the structure with minimum maintenance.

Thermally sprayed aluminum (TSA) is increasingly applied in marine environments as a corrosion mitigation solution but few studies provide quantitative corrosion rate data, from which a lifetime of little or no maintenance can be predicted. A technology review was undertaken to establish current working practice and experience related to the mitigation of splash and tidal zone corrosion. A number of coating systems (thermally sprayed, organic paints and duplex combined thermal spray and paint), currently used in the splash and tidal zone of offshore structures, were identified. Thermal spray coatings with and without aluminum-silicone sealant were prepared and tested in alternate immersion using linear polarisation resistance (LPR) methods. The data were analysed and corrosion rates values were obtained.

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Determining Distribution Rate Of Vapor Corrosion Inhibitors Using Corrosion Potential Data

Product Number: 51322-17970-SG

Author: Pavan K. Shukla, Roderick E. Fuentes, Bruce J. Wiersma, Crystal Girardot, Jason Page, Shawn Campbell

Publication Date: 2022

$20.00

High-level radioactive waste generated during reprocessing of spent nuclear fuel at Hanford has been stored in several single- and 27 double shell tanks (DSTs). Each DST consists of a primary shell (inner) surrounded by secondary (outer) liner. The secondary liner rests on a concrete foundation. Rainwater may seep in and accumulate in the drain slots and may corrode the exterior of the secondary liner. Evidence of wall thinning has been detected via ultrasonic inspections of the annulus floor between the primary and secondary tank shells. Since the inspection is confined to this region, there is a concern that corrosion is widespread on the underside of the bottom plate.

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Determining Migration of Vapor Corrosion Inhibitions Within Sandpad

Product Number: 51323-19365-SG

Author: Pavan K. Shukla, Roderick E. Fuentes, Andrew Nordquist, Bruce J. Wiersma, Laurie Perry

Publication Date: 2023

$20.00

Soil-side corrosion of the bottom plates of aboveground storage tanks is one of the main reasons for the tank bottom failures. Literature data and experimental work have shown that soil-side corrosion rates could reach as high as 50-100 mpy, indicating that soil-side corrosion could cause the tank-bottom failure in relative short periods, i.e., less than five years after initial installation or repairs. In addition, a recent study has shown that cathodic protection (CP) systems’ effectiveness could be questionable in up to 40 percent of the tanks.

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Determining Repair and Replacement of Legacy Pipeline Systems

Product Number: 51319-13427-SG

Author: Jason Land

Publication Date: 2019

$20.00

Legacy pipeline operators face increased regulatory challenges. Legacy systems have decades of metal loss and coating damage from forces pressure cycling thermal stresses and other physical phenomena that weaken the pipeline; years of damage make the pipeline more susceptible to leaks or rupture related to integrity threats. Management of a legacy system requires corrosion control. Mechanical integrity can be maintained by coupling an appropriate inspection schedule with relevant remedial responses. Legacy pipelines can then be operated under acceptable risk levels to the public the environment and the business.Engineering economic analysis demonstrates that well planned corrosion management can provide a cost-effective safe operation over the life cycle of pipelines and valuable information to decide whether to extend the operational life of the asset. This financial analysis incorporates the cost of the necessary mitigative actions comparing the cost of the continuing mitigative actions to the cost of replacement while folding in the key components of risk.

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Individual Conference Papers

Detection of H2S in Oilfield Chemicals

Detection of Surface Contamination During a Scheduled Inspection and Repair Investigation

Deterioration of Wastewater Treatment and Collection System Assets: Knowing Where and How to Look

Determination of Activation Energies for Nuclear Electrical Cable Insulation Using Density and Total Color Difference

Determination of Corrosion Inhibitor Residuals in Dry Crude Oil

Determination Of Oxygen Limits For Corrosion Resistant Alloys (Cras) In Oil & Gas Produced Water Based On Electrochemical Test Methods – Part 1

Determination Of Oxygen Limits For Corrosion Resistant Alloys (Cras) In Oil & Gas Produced Water Based On Electrochemical Test Methods – Part 2.

Determination of the Acceptability Conditions for a Safe Use of Alloys UNS S32750 Through SSRT Screening

Determination of the Corrosion Rate of Thermally Spayed Aluminum (TSA) in Simulated Marine Service

Determining Distribution Rate Of Vapor Corrosion Inhibitors Using Corrosion Potential Data

Determining Migration of Vapor Corrosion Inhibitions Within Sandpad

Determining Repair and Replacement of Legacy Pipeline Systems

Association for Materials Protection and Performance