AMPP Store - Products tagged with 'subsea'

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51318-10982-Analyzing Pig Returns from a Subsea Pipeline for MIC: Sampling and Testing Challenges

Product Number: 51318-10982-SG

Author: John J. Kilbane II Ph.D.

Publication Date: 2018

$20.00

This manuscript provides case study data from subsea crude oil pipelines that addresses the questions of how to obtain the best quality samples from pig returns for microbiological testing, and what are the relative merits of different test methodologies.

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51318-11049-CORROSION RISK ASSESSMENT MODEL OF SUBSEA PIPELINES NETWORK

Product Number: 51318-11049-SG

Author: Faisal M. Al-Abbas / Gusai H. Al-Aithan / Saad Muaili / Qasim Saleem / Balasubramani Bakthavatchalu / Ebadul Haque / Mohammed Barout

Publication Date: 2018

$20.00

A risk assessment model developed as part of a holistic study conducted to evaluate the condition of subsea pipelines. A systematic semi-quantitative risk-based model was developed to identify, analyze and evaluate risk associated with each subsea pipeline.

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51318-11152-Risk Based Subsea Inspection Planning and Corrosion Management.

Product Number: 51318-11152-SG

Author: S. Haarberg / G. Ø. Lauvstad / J. C. Werenskiold

Publication Date: 2018

$20.00

A new field gradient (FG) measurement tool has been developed for cathodic protection (CP) inspection of subsea facilities. The paper presents a case where FG data and CP modelling have been used to optimize CP retrofit design, cutting costs by 50%.

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Cathodic Protection Of Mooring Chain In Offshore Environment

Product Number: 51322-17722-SG

Author: Faisal Shahzad, Nils Olav Digre, Kristian Varne

Publication Date: 2022

$20.00

Corrosion in Mooring systems for permanently moored floating production units has been identified as a problem area by authorities as well as industry. A Joint Industry Project (JIP) initiated by the Bureau of Safety and Environmental Enforcement (BSEE) with participation from major global oil and gas operators as well as equipment suppliers was established in 2014 to review the problem area. ¹ Studies performed as a part of this program have shown that especially mooring chains located in tropical waters have shown signs of rapid corrosion, both general and localized with corrosion rates significantly larger than those specified in design standards. Increased corrosion allowance, as well as increased inspection requirements, have been recommended and corrosion has been reported as the leading cause for pre-emptive replacement of mooring.

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Comments On Standards Development For Selection And Specification Of Subsea Materials

Product Number: 51322-17491-SG

Author: Russell D. Kane

Publication Date: 2022

$20.00

In the oil and gas industry, the major standard for material selection today is ANSI¹/NACE² MR0175/ISO 15156 Parts 1-3. [1] While this standard deals extensively with environment cracking and its prevention for materials under exposure to production environments containing H₂S, CO2, chlorides, and sulfur, it does not include any guidance or material requirements for resistance to environmental cracking (such as hydrogen stress cracking – HSC, or otherwise) under variable subsea conditions that involve exposure to seawater with varying levels of cathodic protection (CP). ISO 21457 [2] provides further guidance for materials selection and corrosion control for oil and gas production systems but does not provide adequate coverage of the issue of environmental cracking in subsea applications with CP.

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Corrosion Mitigation Of Deepwater, 143-Km Long Multiphase Pipelines

Product Number: 51321-16520-SG

Author: Alyn Jenkins/ Marcus Rossiter/ William Cardwell/ Michael Reid/ Brian Messenger

Publication Date: 2021

$20.00

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Development of an F22 Metal Compatible Scale Inhibitor for Subsea Application

Product Number: 51323-19069-SG

Author: Chunfang Fan, Wei Zhang, Tiffany Nguyen, Jason Moses, Alexander Nelson, David Orta

Publication Date: 2023

$20.00

Mineral scale deposition is one of the major flow assurance issues for the oil and gas industry. When an oil or gas well produces water, there is the possibility that scale could form either by the mixing of incompatible waters forming oversaturated brine or by direct precipitation of the water that occurs naturally in reservoirs due to the changes in pressure, temperature, or pH. Scale inhibitors are commonly used to prevent mineral scale formation during oil and gas production and mitigate this flow assurance issue.

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Effect of Heat Treatment and Manufacturing Method on the Susceptibility to Hydrogen Induced Stress Cracking of UNS N06625

Product Number: 51324-20899-SG

Author: Eivind Bruun Thorstensen; Atle Helge Qvale; Vebjørn Andresen ; Roy Johnsen; Paal Bratland

Publication Date: 2024

$40.00

This paper presents results obtained from examining the effect of heat treatment and production method on the hydrogen induced stress cracking (HISC) susceptibility of UNS N06625 (Alloy 625). Five different versions of Alloy 625 were examined: Hot forged material heat treated at 920 °C, 1010 °C and 1100 °C respectively, material produced by hot isostatic pressing (HIP) and material that has been solution annealed and strain hardened (cold worked) at a temperature below secondary phase formation. The different versions of Alloy 625 were initially characterized by identifying the critical pitting temperature (CPT) by use of a modified ASTM G48 Method C test. Resistance to Hydrogen Embrittlement (HE) has been examined by use of stepwise loading of tensile specimens in a hydrogen charging environment in CortestTM proof rings, followed by fractography characterization and microstructural examination by use of Optical Light Microscope (OLM) and Scanning Electron Microscope (SEM). The hot forged and the HIP’ed versions of Alloy 625 that subsequently were heat treated, were found to be susceptible to HISC. The evaluation was based on a decrease in strength and ductility, as well as brittle fracture surfaces and secondary cracking on the samples’ outer surface. Among the hot forged and heat-treated versions, the samples heat treated at 1010°C were found to be the most susceptible to HISC, while (solution) heat treatment at 1100°C resulted in the lowest HISC susceptibility amongst the hot forged and heat-treated qualities. The solution annealed (1150 °C) and cold worked version showed a higher resistance to HISC, as no reduction in fracture strength, nor any secondary cracking were observed. The amount of grain boundary precipitations was found to be the main factor influencing the HISC susceptibility, where an increased amount of grain boundary precipitations led to higher susceptibility. The effect of grain size on the HISC susceptibility of samples charged with hydrogen were also considered, and the results indicate that larger grains have a beneficial effect on the ductility.

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Electrochemical Behavior Under Artificial Seawater and Intergranular Corrosion Performance of 6XXX Aluminum Alloys Series

Product Number: 51320-14620-SG

Author: Mariana Georges M. de Carvalho, Gustavo Brandolin, Daniela Figueiredo Cavalcante, Flavio Vieira Vasques de Sousa, Vanessa Dreilich, Fabio Pereira Alves

Publication Date: 2020

$20.00

Aluminum alloys have high strength to weight ratio, and during the years they have been used successfully in the maritime industry, due to their good corrosion resistance when correctly applied (e.g., properly selected). In the subsea environment, the oil and gas industry currently uses aluminum alloys for Remotely Operated Vehicle (ROV), but due to its limited information regarding long-term application in seawater, these alloys are not generally selected for subsea structural purposes. The aim of the current paper is to compare the performance of three different aluminum alloys through electrochemical tests in artificial seawater and under accelerated intergranular corrosion (IGC) tests. Samples were tested through potentiodynamic polarization (ASTM(1) G61), under aerated and de-aerated environments, and in order to compare their IGC resistance, they were tested following ISO(2) 11846 (method B). The polarization curves revealed that the open circuit potential (OCP) increased when the solution moved from de-aerated to aerated. Additionally, no improved performance was seen from any alloy tested concerning pitting and repassivation potential, even when subjected to different aeration conditions. Finally, the IGC testing was satisfactory to distinguish the alloys’ IGC resistance.

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Evaluation of the Hydrogen Diffusion and Transport Kinetics in ASTM A508 Grade 4N

Product Number: 51321-16404-SG

Author: Esteban Rodoni/Andreas Viereckl/Zakaria Quadir/Garry Leadbeater/Mariano Iannuzzi

Publication Date: 2021

$20.00

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Extending the Life of an Ageing Forty Two Years Old Offshore Wet Crude Pipeline

Product Number: 51322-17532-SG

Author: Faisal M. Al-Abbas, Qasim Saleem, Bander Al-Otaibi, Balasubramani Bakthavatchalu, Ebadul Haque

Publication Date: 2022

$20.00

The hydrocarbon exploration in the ocean and deep sea was started as early as early as the 1850s, when the first drilling was carried out in California, USA. Other early oil explorations activities were later recorded in Pakistan (1886), Peru (1869), India (1890) and Dutch East Indies (1893).1 In 1930s, the development of the Gulf of Mexico as an offshore area started with oil first being produced in 1938.1 The production from the North Sea brought more technical challenges to the offshore industry.

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Hydrogen Embrittlement Susceptibility in Corrosion Resistant Materials for Fasteners

Product Number: 51323-18763-SG

Author: Hans Husby, Inge Morten Kulbotten, Gisle Rørvik

Publication Date: 2023

$20.00

Products tagged with 'subsea'

Association for Materials Protection and Performance