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Design Of Cathodic Protection System For Duplex Stainless-Steel Pipeline: Protection Criteria And Hydrogen Embrittlement Management

Product Number: 51322-18124-SG

Author: Ashraf Al Aasmi, Kathy Buckingham, Ziru Zhang, Timothy Bieri

Publication Date: 2022

$20.00

A life cycle cost assessment led to the selection of DSS for field gas gathering network composing of more than 200 miles of pipelines. Buried portions are provided with external coating. Furthermore, due to high chloride content in the soils, the external corrosion threat was mitigated through the use of an external coating supplemented with CP.

As there was no industrial reference covering onshore DSS pipeline CP criteria, lab testing was conducted to establish the criteria and confirm if the risk of hydrogen embrittlement is managed appropriately. This is further evaluated with field data to confirm pipelines integrity.

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Design Of Sour Service Material: Combining Metallurgical Design, Laboratory And Full Scale Testing Towards A Novel High Strength Sour Service Material

Product Number: 51322-17615-SG

Author: Michel PIETTE, Florian THEBAULT, John FORTAILLIER, Livia-Raquel CUPERTINO-MALHEIROS

Publication Date: 2022

$20.00

During the last decades, low alloyed steels with improved resistance to Sulfide Stress Cracking (SSC) have been developed for covering specific applications as heavy wall casings¹ or expandable tubings² or for reaching higher mechanical properties, such as 125 ksi Specified Minimum Yield Strength (SMYS) materials.^3-6 For the latter, relevant sour environments for developed grades are mild, meaning that all sour applications cannot be covered while a strong interest exists for O&G operators to use high strength materials when designing wells. Consequently, there is an incentive to push the limits of use of high strength sour service steels by enhancing their resistance to SSC. Several recommendations were already published when designing high strength sour service grades: hardness level shall be limited as much as possible and be preferentially below 22 HRC⁷, microstructure shall present a minimum required amount of martensite8 which is well known to be ideal for combining high mechanical properties and high resistance to hydrogen. Besides, many authors highlighted some other influencing parameters related to the material or the process.

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Destructive Examination Protocol for 3013-Container-Package Storing Plutonium-Bearing Materials

Product Number: 51324-20811-SG

Author: Roderick E. Fuentes; Michael J. Martínez-Rodríguez; Elizabeth J. Kelly

Publication Date: 2024

$40.00

The 3013-container-package consists of a convenience, inner and outer container and is used for long-term storage of plutonium-bearing materials. A destructive examination (DE) protocol has been developed to examine the container package visually and with microscopic aid to find any corrosion conditions that could result in the loss of the integrity of the container package over its lifetime. The DE protocol contains three main steps: initial container examination, helium (He) leak testing, and detailed imaging and analysis of the inner container closure weld region (ICCWR). The ICCWR has been determined to be bounding, defined as exhibiting worst case conditions for stress corrosion cracking (SCC) of the inner container. To assess SCC in the ICCWR, the inner container lid is cut into quarters and the weld and He-leak testing gasket are removed. Then a citric acid wash is performed to remove adherent chlorides from the ICCWR. The wash is then sent for analysis to determine the concentration of chlorides in the ICCWR. While the analysis for chloride concentration is being performed, the quarter sections are further sectioned into 1/8th subsections by cutting each section in half. These subsections are washed using nitric acid to remove corrosion products. Then each subsection is imaged using a Wide Angle 3-D Measurement System (WAMS). After analysis of microscope images for potential SCC, additional imaging can be performed, including subsurface imaging. After review, a determination is made of whether the container integrity may potentially affect the safe storage of the material.

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Detection And Location Of Coating Defects And Disbondments On Buried Pipelines With Differential Reflectometry Mapping

Product Number: 51322-18065-SG

Author: Tristan Petit de Servins d’Héricourt, Homero Castaneda

Publication Date: 2022

$20.00

Corrosion control of buried assets usually involves a double shield: a coating system as a physical insulation barrier, and a cathodic protection system as an additional ad hoc defense. Detection of a corrosion spot at the coating defect stage is the only way to identify the threat before significant metal loss occurs. Furthermore, detection of defects in the coatings of such assets is especially important, since large defects, if left unrepaired, will not only leave the asset locally prone to corrosion, but also drain and weaken the cathodic protection effectiveness for the entire structure. Therefore, identification and characterization of coating anomalies is critical for the integrity of buried assets.

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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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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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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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Developing Additively Manufactured Alloy UNS N07718 for Critical Oilfield Applications

Product Number: 51323-19220-SG

Author: Wei Chen, Thomas Dobrowolski, Paul Agosta, Nicholas Barta, Lakshmi Vendra, Juan Carlos Flores

Publication Date: 2023

$20.00

Additively Manufactured Alloy UNS N07718 (AM 718) has been increasingly adopted for components in oilfield applications. AM 718 fabricated using laser powder bed fusion (LPBF) has demonstrated not only excellent mechanical performance, but also promising capabilities in critical services such as sour or hydrogen-generating conditions. In oilfield applications, it is generally felt that AM 718 should comply with API standard 20S4, and align with the requirements for wrought 718 in API 6ACRA.

AMPP Conference Papers

Association for Materials Protection and Performance