AMPP Store - Individual Conference Papers

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Development of A Combined Corrosion and Scale Inhibitor for Subsea Multiphase Oil Field in Brazil

Product Number: 51323-18810-SG

Author: Larry Chen, Nihal Obeyesekere, Aline Kina, Lisa Greaney

Publication Date: 2023

$20.00

This production asset located in the deep-water offshore Brazil, producing heavy oil in the range of 16 to 24 oAPI. Mudline caisson separators with electrical submersible pumps (ESPs) are used to process fluids from multiple wells and boost them to the receiving floating production, storage, and offloading (FPSO) vessel(1). There are significant flow-assurance and corrosion challenges in operating the asset. One of the challenges is the production fields have limited subsea umbilical, necessitate the use of
multifunctional products to maintain the field’s integrity and mitigate any flow assurance and scale issues.

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Development of a concentrated corrosion inhibitor compatible with produced water brine and scale inhibitor

Product Number: 51320-14668-SG

Author: Sathees Kesavan, John Samuel Selvaraj, Suresh Seethalakshmi, Yure Queiros, Andrade Gessie, Nicolas Scanarotti

Publication Date: 2020

$20.00

Oil and gas production field requirements to maintain asset integrity and scale control are very diverse. In an operator’s field in Latin America, the conditions across several wells required the co-injection of corrosion and scale inhibitors. The brine composition of these wells is challenging due to relatively high concentration of calcium ions as well as the presence of iron. The selected scale and corrosion inhibitors need to be compatible with brine and with each other without negatively impacting the absolute performance of the individual products. An additional practical challenge for product selection was imposed by the extreme remote location of the field requiring the product to perform at an optimal dosage without increased transportation and logistics costs.

This paper describes the results from screening studies conducted with a series of corrosion inhibitor product formulations using different static and dynamic lab performance evaluation test methods. As the primary corrosion inhibitor actives are oil-soluble by nature, focus was given to formulating the product with an appropriate selection of solvents, such as methanol and isopropanol, and surfactants to achieve the desired compatibility with the brine and scale inhibitors. The final products were identified, and an optimal product dosage was arrived at based on tests conducted under typical and aggressive conditions representative of the field. However, due to the diversity of conditions and corrosion severity levels across multiple wells in this field, corrosion prediction simulations were run for unmonitored wells to estimate a baseline corrosion rate and build confidence in the recommended corrosion inhibitor product dosage. The validation of the prediction for monitored wells with ER probes will also be discussed in this study.

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Development of a Corrosion Control Program for Liquid Radioactive Wastes Stored in Carbon Steel Waste

Product Number: 51317--9688-SG

ISBN: 9688 2017 CP

Author: Bruce Wiersma

Publication Date: 2017

$20.00

Large underground, carbon steel tanks are used for interim storage of liquid radioactive waste. The current corrosion control program needs to be updated to account for the susceptibility to pitting corrosion of waste tanks due to the halide content of the secondary waste.

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Development of a Corrosion Inhibitor Formulation for Acid Cleaning of Geothermal Wells

Product Number: 51319-13376-SG

Author: Michael Todd

Publication Date: 2019

$20.00

Calcium carbonate and other mineral scales form in geothermal wells leading to reduced efficiency and sometimes well closure. Hydrochloric acid is used to dissolve carbonate scales and improve efficiency. This acid is very aggressive to the underlying metal which is typically steel. Corrosion inhibitors are typically added to the acid in order to reduce the corrosion rate. This paper describes the development of a corrosion inhibitor formulation which reduced the corrosion rate of steel in 15% hydrochloric acid. A number of inhibitors were screened to select the best performing compounds. Combinations of inhibitors were also tested to look for synergies. The results showed that a tertiary combination of inhibitors provided superior protection to any single inhibitor alone.

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Development Of A F22 Compatible Scale Inhibitor

Product Number: 51322-17610-SG

Author: Ya Liu, Benton Hutchinson, Rose Lehman, Jeffrey Russek, James Outlaw

Publication Date: 2022

$20.00

F22 is a low alloy steel that typically contains 12% Carbon, 2.25% Chromium, and 1.0% Molybdenum1. This steel has been widely used in oil production systems, especially in well head design and construction. As a low alloy steel, F22 can be corroded by oilfield chemicals under certain circumstances. For example, it was observed in the Gulf of Mexico that typical scale inhibitor chemistries caused severe corrosion on F22.

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Development of a Gas-Phase Corrosion Inhibitor for Wet-Gas Carbon Dioxide Corrosion at 200°C

Product Number: 51323-18829-SG

Author: Wei Zhang, Jason Moses, William Cardwell, Samar Agha Keshmiri, Khoa Ky, David Orta, Alyn Jenkins

Publication Date: 2023

$20.00

Although organic corrosion inhibitors have been widely applied in the energy industry, many details regarding their protection mechanism remain unknown. For example, a corrosion inhibitor adsorbs on the clean steel/aqueous solution interface, driven by electrostatic interaction. With the corrosion product
layer formed, how would the inhibitor adsorption interact with the corrosion product nucleation and precipitation? What is the effect of pre-corrosion in inhibitor testing?

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Development of a Low-Power Wireless Sensor Network of Conductivity Probes for the Detection of Corrosive Fluids in Pipelines

Product Number: 51320-14502-SG

Author: Matthew Cullin , Raghu Srinivasan , Todd Petersen, Christina Forbes

Publication Date: 2020

$20.00

One of the primary drawbacks of using electronic sensors for continuous corrosion monitoring in remote locations is the need to provide power and communications at the test location. The present work explores the use of a low-power wireless sensor network to overcome these challenges. Such a network allows sensors to be powered by locally installed energy harvesting elements (i.e., thermoelectric, solar). The communication protocol of the wireless sensor network permits each node to communicate with every other node and store (back-up) data for the entire network. The result is a robust and easily deployable network of sensors that spans large distances. The current effort focuses on the development of conductivity probes that are compatible with industry-standard internal corrosion monitoring infrastructure (i.e., access fittings, coupon holders) and amenable to integration into a low-power wireless sensor network.

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Development of a Master Curve to Characterize the Susceptibility of Fastener Materials to Hydrogen Embrittlement

Product Number: 51324-20813-SG

Author: Ted L Anderson; Behrang Fahmi; Herman E. Amaya

Publication Date: 2024

$40.00

This paper introduces an innovative approach for mitigating hydrogen embrittlement in materials used in underwater environments, a critical challenge in marine engineering. Our study focuses on developing a comprehensive 'master curve' that encapsulates the complex interplay among key factors: hydrogen concentration, applied potential, and material strength. This curve serves as a predictive tool for evaluating the susceptibility of materials to hydrogen embrittlement, a phenomenon that lacks a one-size-fits-all solution. Through fracture mechanics testing of carbon steel alloys and rigorous analysis, quantitative relationships between these factors are established. This research not only aids in optimizing material selection and designing effective cathodic protection systems but also ensures enhanced safety and integrity in operational contexts. The master curve, rooted in both empirical data and theoretical insights, offers a strategic framework for engineers and industry professionals, guiding decisions that enhance the durability and reliability of subsea equipment.

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Development of a New CRA Grade for High Pressure High Temperature Application

Product Number: 51319-12782-SG

Author: Cécile Millet

Publication Date: 2019

$20.00

In High Pressure High Temperature “HPHT” wells (pressure above 10000psi/690bar temperature above 300°F/150°C which contain CO2 (sweet corrosion) and H2S (sour service) the oil & gas operators need to select materials which are resistant in corrosive atmosphere during the well lifetime. At the same time high strength grades are usually required to meet collapse and burst properties. The aim of the end users is to get the specific grade which can resist to corrosion while minimizing the cost which involves qualification with corrosion tests.The API 5CRA standard defines corrosion resistant alloy (CRA) grades for casings and tubings from group 1 named “Super 13Cr 13-5-2” (suitable up to 356°F/180°C) to group 2 “Duplex” grades 22-5-3 (450°F/232°C) or “Super Duplex” 25-7-4 (482°F/250°C) and higher grades.Therefore when the well temperature is above 356°F/180°C duplex grades or higher are commonly selected as these materials have a larger application domain at higher temperature range.A new proprietary grade chemistry was developed to provide good corrosion performances up to 230°C 125ksi (862MPa) grade material and high impact toughness. From a metallurgical standpoint achieving targeted mechanical and corrosion performances has ended up in a multi-phases material (martensite delta ferrite and austenite). Most of the performances are mainly controlled by the phases balance which alloy optimization has enabled consistent control by heat treatment.Stress corrosion cracking performances were assessed and compared to Super 13Cr and Super Duplex materials showing significant benefice of chromium under high temperature. Potentiodynamic electrochemical measurements in H2S environment were performed at 24°C in order to evaluate pitting performance and assess risk of sulfide stress corrosion cracking confirming higher sulfide stress corrosion performance compared to S13Cr materials. X-ray Photoelectron Spectroscopy (XPS) characterizations provide deep knowledge about it passive film compositions underlining the beneficial effect of high chromium within the grade.This solution offers to Oil and Gas operators a cost effective designed seamless tubes for high temperature well reservoir condition as alternative to duplex materials.

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Development of a new high interstitial non-magnetic stainless steel for oil and gas applications

Product Number: 51320-14552-SG

Author: Clara Herrera, Philipp Niederhofer, Merlin Seifert

Publication Date: 2020

$20.00

High nitrogen FeCrMn -austenitic stainless steels are used in oil and gas applications such as non-magnetic drill collars, Measuring While Drilling (MWD), and Logging While Drilling (LWD) housings. These steels are characterized by a good combination of high strength and high corrosion resistance in aggressive environments. This paper presents some results of a newly developed non-magnetic high interstitial (FeCrMnMo(C+N)) austenitic stainless steel which shows high strength, toughness, and enhanced corrosion properties. Characterization of microstructure, mechanical and corrosion properties was performed. After solution annealing at 1125 °C, the new 18Cr-18Mn-2Mo-1(C+N) is fully austenitic without precipitates or δ-ferrite. The newly developed stainless steel is characterized by an elongation higher than 60 %, a yield and ultimate strength of 600 MPa and 980 MPa, respectively, combined with high impact energy (≥ 350 J). Pitting resistance equivalent number (PREN) is > 35. The high-interstitial (HI) steel shows no intergranular corrosion without sensitization treatment (ASTM A262) and no weight loss in ferric chloride solution testing at room temperature for 72 hours (ASTM G48 Method A). The critical pitting temperature tested in acidified ferric chloride is 35 °C (ASTM G48 Method E). The new high interstitial FeCrMn austenitic stainless steel is a very promising grade for applications in the oil and gas industry due to the high mechanical strength above 1000 MPa combined with good corrosion properties.

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Development Of A New Top-Of-Line Corrosion Model For Sweet Wet Gas Pipelines

Product Number: 51321-16812-SG

Author: Y. Zheng; J. Sonke; W. M. Bos

Publication Date: 2021

$20.00

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Development of a New Vapor Phase Corrosion Inhibitor for Steam Generating and Boilers

Product Number: 51319-12773-SG

Author: Behzad Bavarian

Publication Date: 2019

$20.00

The presence of dissolved oxygen in boiler feed water and steam generating systems can present serious problems in a steam generating plant by promoting corrosion and thick scale formation in the feed water system the boiler and the steam condensate system. Therefore it is important to remove oxygen from the feed water and also from the condensate where in-leakage can occur. The first step in the elimination of oxygen from the boiler feed water is mechanical deaeration. The second step involves chemical oxygen scavenging to remove the residual oxygen. Hydrazine is used as an oxygen scavenger to control corrosion in steam generating systems despite being a genotoxic carcinogen. Alternative chemicals nontoxic corrosion inhibitors or new oxygen scavenger-free water treatment technologies are preferred. A newly developed amine based vapor phase corrosion inhibitor was investigated. Electrochemical tests were conducted and showed a significantly lower corrosion rate in boiling water. Short term corrosion tests in boiling water showed a decreased corrosion rate from 5.3 mpy to 1.93 mpy for 50 ppm VCI and 1.32 mpy for 100 ppm VCI addition. Long term corrosion tests in the hot steam generating closed loop system showed a decreased corrosion rate from 8.2-8.9 mpy for the control sample to 0.72-0.74 mpy when washed with 500 ppm VCI solution and subsequently maintained at 100 ppm inhibitor for the test remainder. When inhibitor added at beginning of test resulted in corrosion rate of 1.09-1.24 mpy (with 100 ppm VCI). XPS analysis showed that the amine based inhibitor promoted and stabilized a protective (Fe3O4) magnetite oxide on the pipe internals.

Individual Conference Papers

Association for Materials Protection and Performance