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High pressure and high temperature processes are present in a wide variety of industries and are often pushing the limits of common materials. As a result, these applications have required advanced materials as well as an improved understanding of the in-situ conditions. Furthermore, those processes have become more and more present in a wide range of industries such as upstream oil and gas (O&G) and power generation (in supercritical CO2 or molten salt nuclear reactors). The corrosion performance of existing and emerging materials to the extreme environments present in next generation power must be well characterized to ensure material integrity and reduce the risk of catastrophic failures due to environmentally assisted cracking, homogeneous corrosion, thermal oxidation, or other mechanisms.
Wells in oil, gas and geothermal production experience a broad spectrum of operating conditions in terms of temperature, depth, pressure and production environments, which govern material selection. For severe environments, where high strength and toughness combined with excellent corrosion and cracking resistance are required, a new superaustenitic stainless steel has been recently developed. Aiming for a minimum yield strength of at least 120 ksi (827 MPa), strain hardening enables the desired mechanical properties, allowing users to avoid well known but HISC susceptible and less cost effective precipitation hardened (PH) nickel alloys.
This is Part I of a two-part series intended to provide background and a rational justification or supporting rationale for requirements leading to the development and publication of NACE(1) MR 0175 and ISO(2) 15156. Part I focuses on some of the metallurgical and processing requirements; specifically, Rockwell C 22 scale (HRC) limit, the various acceptable heat treatments and the 1wt% Ni limit for carbon and low alloy steels to minimize the threat of sulfide stress cracking (SSC) in H2S containing environments. Part II describes the testing and rationale behind the use of accelerated laboratory test procedures and their development to differentiate metallurgical behavior in sour environments.
This paper is Part II of a two-part series intended to narrate the history, some of which has been forgotten over time, leading up to the publication of the first Material Requirement (MR-01-75) standard prepared by NACE and its subsequent auxiliary standards. Previously, Part I1 described the field observations and discussed the metallurgical factors that were being investigated by the historical NACE T-1B and 1F committees to support the development a “harmonized” sour service materials standard. In Part II, we focus on the rationale behind the use of accelerated laboratory test procedures and their development to differentiate metallurgical behavior in sour environments.
PT Pertamina Hulu Energi (PHE) is a subsidiary of PT Pertamina (PERSERO) – Indonesia’s national oiland gas company, with coverage activities from exploration, development, operation, production anddistribution of oil and gas in Indonesia. PHE manages the portfolio and/or operations of 58 subsidiaries,6 joint ventures and 2 affiliated companies that manage oil and gas blocks at home and abroad, as wellas engaged in downstream oil and gas business activities and services with oil and gas production of540,000 BOPD and 2500 MMSCFD. Oil and gas operations handle hazardous material such as hydrocarbons that can easily form flammable mixture and some toxic.
Abrasive blasting operations used for paint and surface coatings removal are essential for the maintenance of the ships, aircraft, and land vehicles of the United States Armed Forces as well as use industries such as oil & gas, power generation, construction, mining, and infrastructure, among others. Abrasive blasting nozzle design is rudimentary and noise levels produced during abrasive blasting operations in shipyards, maintenance facilities, and factories for removing paint and surface coatings often exceed exposure limits put in place by Occupational Safety and Health Administration (OSHA). Reducing a worker's occupational noise exposure is imperative from a safety and economics perspective.
Formulators of these coatings need to address the legislations strongly pushing toward lower VOC content. All around the World, Governments, Paint Manufacturers and Applicators are still discussing viable options, though there is no doubt that challenges related to higher solids content in coating formulations will continue to increase.
This presentation outlines recent developments in a novel remote sensing technique developed to detect localised abnormal pipe wall stress by mapping variations in the earth’s magnetic field around pipelines. Corrosion metallurgical defects and ground movements result in areas of increased localised stress in pressurised pipelines and a direct relationship has been described mathematically which connects magnetic field characteristics to the magnitude of stress due to magnetostriction. The method is non invasive and reports localised stress as a percentage of material specified minimum yield strength its geometric centre and 3 dimensional mapping of the pipeline route including depth of cover all to cm accuracy.The presentation first explores magnetostriction in ferromagnetic materials and then how measurements of remote magnetic field can be applied to define the location of defects in operational pipelines quantify the associated abnormal stress and to concurrently report a 3 dimensional map of the pipeline route. The benefits of using this technique and a series of case studies are described to illustrate its use in practice in the field.
Testing cured coatings for flaws and defects is often a crucial part of the acceptance process for a coating assessed against its specification. This is particularly the case for pipeline and storage tank coatings and for coatings applied for corrosion protection, where discontinuities in the coating can lead to premature failure.