AMPP Store - Individual Conference Papers

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Material Selection for anthropogenic CO2 injection: mechanical and corrosion performances of steels under dense CO2 with impurities

Product Number: 51323-18886-SG

Author: Cécile Millet, Guillaume Néel, Luciana Lima, Diana Rodriguez Barrera

Publication Date: 2023

$20.00

Carbon capture and storage (CCS) are technologies aimed at capturing CO2, followed by transportation to a storage site and injection into one of several types of stable geological formations, to trap and prevent its subsequent emission. Though CO2 transport and injection for Enhanced Oil Recovery (EOR) are known for over 40 years, new challenges arise when the CO2 source is anthropogenic, meaning with a human-cause origin and not natural (as in EOR). EU Directive 2009/31/EC states that CO2 streams from power stations or industrial plants "shall consist overwhelmingly of CO2" but may contain associated incidental substances (e.g., SOx, NOx, O2, H2S).

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Material Selection for Carbon Capture and Storage (CCS) Wells

Product Number: 51323-18760-SG

Author: Willem Maarten van Haaften, Hisashi Amaya, Bostjan Bezensek, Yuji Arai, Brian Chambers, Hiroki Kamitani

Publication Date: 2023

$20.00

The goal of the Paris Agreement is to limit global warming to below 2°C, preferably 1.5°C, compared to pre-industrial levels.1 While the world is slowly transitioning to more sustainable energy sources to reach this target, one of the ways to reduce the CO2 in the atmosphere is to capture it and store it in depleted gas fields. According to the IOGP1, the total number of CCS projects in Europe is 65 in 2022.2 The aim of these projects is to store around 60 MtCO₂/yr by 2030.

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Material Selection for CCUS Injection Well: A Case Study in North Sea

Product Number: 51324-21062-SG

Author: Luciana Lima; Cecile Millet; Diana Rodrigues Barrera; Guillaume Néel; Robert Conder

Publication Date: 2024

$40.00

Carbon capture utilization and storage (CCUS) are technologies aimed at capturing CO2 and preventing its subsequent emission. Though CO2 transport and injection for enhanced oil recovery (EOR) has been a common practice for the Oil and Gas industry for over 40 years, new challenges arise when the CO2 source is anthropogenic. Industrial CO2 stream composition will carry impurities such as NO2 (nitrogen oxides), SO2 (sulfur oxides), O2 (oxygen), H2S (hydrogen sulfide) that could affect material corrosion behavior. A complete testing program was undertaken to assess the main corrosion risks associated to the application: Sulfide Stress Cracking (SSC), Stress Corrosion Cracking (SCC), crevice and mass loss resistance. The results confirm the effects of impurities such as SO2, NO2 and oxygen on corrosion behavior. Carbon low alloyed steel (N80Q) material presented a higher corrosion rate, and it is not suitable for injection tubing but may be acceptable for casing materials when not permanently exposed to the CO2 stream. UNS S41426 (S13Cr) material needs special considerations for CCS application due the presence of some localized corrosion when exposed to a high saline water phase. UNS S31803 (22Cr) could be suitable for a less severe environment including additional testing, whilst UNS S32760 (25CrS) presented good corrosion behavior and is suitable for the application.

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Material Selection For Storage Tanks – Life Cycle Cost Analyses

Product Number: 51322-17505-SG

Author: Sandra Le Manchet, John Grocki

Publication Date: 2022

$20.00

This paper will provide recent corrosion data for stored chemicals. Duplex stainless steel corrosion curves obtained in nitric, sulfuric, phosphoric acids as well as several kinds of waters will be provided. In addition, atmospheric corrosion data obtained after 15+ years of sample exposures in several geographic areas will be shown. These results will be compared to those obtained with other materials commonly used for the construction of storage tanks.

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Material Selection Methodology Using Halite Tendency Indicators for Gas Wells: A Case Study

Product Number: 51320-14586-SG

Author: Eugenia Marinou, Valdir De Souza, David Roberts, Qi Zhao

Publication Date: 2020

$20.00

In gas wells, where a low or unknown amount of the naturally occurring saline formation water is expected to be produced, tubing material selection relies on selecting a fixed dataset of input parameters and extrapolating to the entire well life. This is intended to represent the worst-case scenario; while this can be the case regarding pressure and temperature, the produced water composition as a function of time is less likely to be as reliable. This is because during production, gas can cause water evaporation, leading to a significant increase in the chloride ion concentration compared to the analyzed values – and hence, potentially an unsuitable material selected. To this end, it is important to: (a) ensure that the formation water composition analyzed is correct, (b) that this composition is reconciled to initial reservoir conditions and (c) calculate any evaporation/condensation effects in different sections of the well as a function of production forecasts. This makes it easier to establish operational envelopes that both prevent productivity impairment and provide appropriate thresholds of acceptability for the tubing material selected. This paper describes the methodology applied for tubing material selection for a high temperature-high pressure (HTHP) gas well in the North Sea.

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Material Testing and FFS Modelling for HTHA of Less-Common Alloys: C-0.3Mo

Product Number: 51324-21142-SG

Author: Jorge Penso; Nathaniel Sutton; Brandon Rollins

Publication Date: 2024

$40.00

Tremendous attention has been devoted to understanding the behavior of common engineering alloys in high temperature hydrogen service. Nelson curves from API RP 9411 are available for the alloys most widely used in HTHA service. However, the aging international fleet of equipment in hydrogen service, across the refining, petrochemical and fertilizer industries means that in-service equipment constructed from less-common alloys must sometimes be evaluated for HTHA. The authors are involved with an 10-year joint industry project studying HTHA. One major outcome of this project is a volumetric HTHA damage FFS model which incorporates stresses from methane pressure within the material into an MPC Omega Multiaxial damage formula. A crack growth model using the fracture mechanics parameter C* (commonly used in creep crack growth)12 is also under development. These two are related in that the C* crack growth law parameters can be calculated utilizing the MPC Omega material creep properties. With sufficient creep data for an uncommon alloy like C-0-.3Mo, lot centered MPC Omega creep properties can be regressed. Such data have been compiled by the authors and resulting Omega creep properties are reported. These creep properties, along with other material properties, are used in the HTHA damage progression and the C* crack growth models. Model predictions using this approach are compared to historically available ex-service HTHA data from API RP 9411 for alloys with Mo contents between that of carbon steel and C-0.5Mo. Selective testing (creep and crack growth testing in both air and hydrogen environments) is in-progress to verify the FFS approach.

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Material-Biodiesel Compatibility – Survey of Industry Experience

Product Number: 51317--9434-SG

ISBN: 9434 2017 CP

Author: Li Yan

Publication Date: 2017

$20.00

Two surveys were conducted in 2011 to understand the industry knowledge and experience with respect to the use of biodiesel. This paper summarizes the salient features from these surveys.

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Materials and Corrosion Challenges for the Development of Plastics Recycling Processes

Product Number: 51324-20733-SG

Author: François Ropital; Jean Kittel; Wilfried Weiss; Alexandra Chaumonnot; Frederic Favre

Publication Date: 2024

$40.00

To support the booming demand of plastics by the industry, and to reduce the environmental footprint, circularity is a collective imperative. Since plastics are divided into a large number of families, there is no universal recycling process. Depending on the type of polymer, recycling processes involve one or several steps such as conversion, depolymerization, dissolution, mechanical treatment, etc Highly corrosive environments can be found, including high temperature and aggressive fluids. Some of the elementary steps of plastics recycling resemble proven processes of the petrochemical or refining industries. The long-lasting experience of these industrial sectors can help for material selection. However, plastics recycling also opens unexplored conditions, e.g. due to the presence of contaminants such as chlorides and bromides. In this paper, we intend to describe several plastics recycling routes and develop on their potential corrosiveness. Guidelines for materials selection will be discussed, and need for further experimental work will be identified.

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Materials and Corrosion Risk Mitigation Associated with Flowback of Acid Stimulation Fluids

Product Number: 51317--8917-SG

ISBN: 8917 2017 CP

Author: Sandra Hernandez

Publication Date: 2017

$20.00

Acid stimulation is a growing practice in the deep water subsea environment. Two acids were tested, one of hydrofluoric and acetic acids and another of hydrofluoric, hydrochloric, and acetic acids. Results and outlines recommendations for different alloys are presented.

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Materials Compatibility Issues in Biofuels – A Review

Product Number: 51317-10039-SG

ISBN: 0039 2017 CP

Author: Narasi Sridhar

Publication Date: 2017

$20.00

The storage and transportation of biofuels continue to be of interest. Material compatibility issues arise. For alcohol fuels, stress corrosion cracking of steels, and swelling and leaching of various polymeric materials. This paper will provide an overview of research that has been conducted in alcohol fuels.

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Materials Performance and Challenges in Oil and Gas Production Wells

Product Number: 51319-13294-SG

Author: Janardhan Saithala

Publication Date: 2019

$20.00

Integrity of materials in Oil & Gas production wells is critical to meet the objectives of design and the lifecycle performance of wells. This is significant value both in economic terms and health safety and environment. Subsurface uncertainties Aging fields EOR activities and also the quality of procured equipment add to the difficulties in preventing equipment failures in wells. Failures that are especially unforeseen or unanticipated provide crucial feedback to operators and lessons to be learnt. It is imperative for operators to learn improve processes and avoid recurrence of failures.Petroleum Development Oman (PDO) as a large operator with more than 10000 wells has gained important experience and lessons from many such failures. This has contributed significantly to improve the company standards material selection reset the operating envelope and procedures enhance surveillance and improve upon quality assurance and control of new equipment.This paper is a compilation of some of the important lessons learnt from such incidents in the recent past. It discusses the operational experience and learning from different subsurface materials from CS to nickel alloys used in different components such as casing tubing packers and X-trees.

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Materials Performance in Oxidizing Acid and Corrosive Solution containing Oxidants

Product Number: 51319-12991-SG

Author: Ajit Mishra

Publication Date: 2019

$20.00

Nickel-based alloys containing optimum amounts of chromium (Cr) molybdenum (Mo) and tungsten (W) are widely used in the chemical process industries due to their tolerance of both oxidizing and reducing conditions. In the present study corrosion tests were performed using weight loss and electrochemical techniques for Ni-based CRAs in various corrosive solutions. The motivation of this study is to understand thematerials performance in oxidizing acid (such as nitric acid) and acidic solutions containingoxidants (like ferric ion cupric ion peroxide etc.). An attempt was further made to correlate the corrosion performance of the alloys in individual and mixed acids to their alloying elements and contents.The corrosion data suggest that in oxidizing acid reducing + oxidizing acid and in solutions containing oxidants HASTELLOY® G-35® (UNS N06035) (Ni-33Cr-8Mo) exhibits a remarkably high corrosion resistance than existing nickel and iron-based alloys.

Individual Conference Papers

Association for Materials Protection and Performance