AMPP Store - Products tagged with 'corrosion rate'

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51318-11630-Internal Corrosion Direct Assessment of a Wet Gas Pipeline

Product Number: 51318-11630-SG

Author: Xihua S. He / Debashis Basu / and Osvaldo Pensado / Jianyun Mei / Bibo Zhang / Hongbo Wu / Yongzhao Fan / Deqiang Cai / Yang Li

Publication Date: 2018

$20.00

This work applied the Wet Gas-Internal Corrosion Direct Assessment (WG-ICDA) standard to assess the severity of internal corrosion of 2 segments along a pipeline used to transport wet gas from a gas mine.

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A real-time matrix based corrosion monitoring system

Product Number: 51322-18130-SG

Author: Hanne Martinussen, Fredrik Sandquist

Publication Date: 2022

$20.00

Pipeline integrity management and practices have been systemized through standards(1), and one important aspect in integrity management is corrosion monitoring. Corrosion monitoring by using permanently installed equipment has increased in the past years⁽²⁾. By using permanently installed ultrasound transducer (UT) sensors and automating signal processing and communication, a more costefficient corrosion management program can be obtained. Ultrasound techniques have been developed to complement traditional inspection with monitoring to improve cost efficiency of pipeline integrity management.

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AC Corrosion of Cathodically Protected Pipelines – Summary

Product Number: 51321-16299-SG

Author: Dr. Andreas Junker Olesen

Publication Date: 2021

$20.00

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Acquiring and Analyzing Electrical Resistance Probe Data Using Web-Based Remote Monitoring Tools

Product Number: MECC23-19990-SG

Author: Jamey Hilleary

Publication Date: 2023

$20.00

Corrosion rate monitoring techniques, using coupons and probes of various designs and technologies, have been in use for decades in some form or another. Weight-loss coupons were an early type of direct measurement of metal loss to determine the rate of corrosion in many applications, internal and external. These coupons could be placed where corrosion is suspected to be occurring and the rate of corrosion determined by removing and weighing the coupon after a set period.

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Advancement of a Comprehensive Mechanistic CO2 Corrosion Model to Incorporate Simulated Hydrodynamics via a Turbulent Flow Model

Product Number: 51324-20657-SG

Author: Michael Jones; Gregory de Boer; Richard Woollam; Joshua Owen; Richard Barker

Publication Date: 2024

$40.00

In this work, two comprehensive mechanistic models of aqueous carbon dioxide (CO2) corrosion produced by Nordsveen et al.1 and Kahyarian et al.2 17 years apart are recreated and compared to highlight the evolution in understanding. The differences between the models include the role of carbonic acid at the surface, whether it is directly reduced or acts as a buffering agent, as well as different mechanisms for the anodic response, and varying temperature responses of multiple input variables. Through recreation and validation of these models using the same software, key comparisons are made to understand the effect of these changes on predicted corrosion rate, surface pH, and speciation through the boundary layers. These values are plotted across a range of input parameters to investigate how the change in scientific understanding influences predictive response of corrosion models.

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An Enhanced Prediction Model For Simultaneous Naphthenic Acid And Sulfidic Corrosion Quantification

Product Number: 51322-17901-SG

Author: Winston Robbins, Sridhar Srinivasan, Abbey Wing, Gerrit Buchheim

Publication Date: 2022

$20.00

Sulfur and acidic impurities in crude oils pose serious hot oil corrosion problems in crude distillation units (CDU) and associated vacuum distillation units (VDU), especially with the increase in processing of lowquality, opportunity crudes.^1-4 In the range of 200-400˚C, reactive sulfur compounds cause sulfidation corrosion of ferritic carbon and chrome steels in CDU, VDU, and front ends of downstream units operating at hot oil temperatures.^5-7 Over the same temperature range, naturally occurring carboxylic acids in crudes can be so aggressive that higher alloy, austenitic stainless steels containing >2.5% Mo are required for processing high acid oils.^8-11 Although sulfidation and acid corrosion occur over the same temperature range, they differ in two significant ways. Sulfidation forms an iron sulfide solid that is semiresistant to further corrosion and relatively insensitive to flow velocity. Acids form oil soluble organic salts that can be washed away especially in areas of high turbulence.^12-14

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ANSI/NACE TM0416-2016, “Test Method for Monitoring Atmospheric Corrosion Rate by Electrochemical Measurements”

Product Number: 21405-SG

Publication Date: 2016

$179.00

HISTORICAL DOCUMENT. Specification, selection & use of sensors for monitoring atmospheric corrosion. These sensors - based on electrochemical techniques - provide continuous records of contaminants, corrosion rates, or coating condition.

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ANSI/NACE TM0416-2023/ISO 22858:2020, Corrosion of metals and alloys — Electrochemical measurements — Test method for monitoring atmospheric corrosion

Product Number: ANSI-NACE TM0416-2023-ISO 22858-2020

$140.00

The purpose of this document is to provide instructions on the use of electrochemical sensors for monitoring atmospheric corrosion. These sensors are used to measure thin film electrolyte conductance, corrosion current or coating condition over long periods. This method permits the instantaneous evaluation of corrosion current that can be related to specific environmental conditions in real time. The instantaneous corrosion current measurements are not accessible using electrical resistance sensors or mass loss techniques. The technology described in this document complements other standard techniques for assessing atmospheric corrosion such as mass loss coupons, electrical resistance sensors or coated test panels (see ISO 8407 and ISO 4628-8). These continuous records of material condition can be useful for studying atmospheric corrosion, evaluating materials or managing assets.

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Assessing Comprehensive Mechanistic CO2 Corrosion Modeling Methods and Their Impact on Predicted Corrosion Behavior

Product Number: 51324-20656-SG

Author: Michael Jones; Gregory de Boer; Richard Woollam; Joshua Owen; Richard Barker

Publication Date: 2024

$40.00

In this work, two comprehensive mechanistic models of aqueous carbon dioxide (CO2) corrosion produced by Nordsveen et al.1 and Kahyarian et al.2 17 years apart are recreated and compared to highlight the evolution in understanding. The differences between the models include the role of carbonic acid at the surface, whether it is directly reduced or acts as a buffering agent, as well as different mechanisms for the anodic response, and varying temperature responses of multiple input variables. Through recreation and validation of these models using the same software, key comparisons are made to understand the effect of these changes on predicted corrosion rate, surface pH, and speciation through the boundary layers. These values are plotted across a range of input parameters to investigate how the change in scientific understanding influences predictive response of corrosion models.

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Combining CP System and Pressure Monitoring at Gas Storage Fields Using Wireless Networked Systems

Product Number: 51317--8983-SG

ISBN: 8983 2017 CP

Author: Jamey Hilleary

Publication Date: 2017

$20.00

The presentation discusses use of combined direct monitoring and wireless local networking technologies allowing multiple data types from several locations in a gas storage field to be accessed through a single field device.

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Corrosion Of 2Cr Steel In Supercritical CO2 Saturated Saline Water With Cl, S and Br Anions

Product Number: 51323-19014-SG

Author: Benjamin Taylor, Yimin Zeng, Haofei Sun, Jing Liu

Publication Date: 2023

$20.00

Before full decarburization can be achieved, the Intergovernmental Panel of Climate Change (IPCC) suggests an applicable way of combining CO2-producing processes with the carbon capture, utilization, and storage (CCUS) chain. Except for permanent CO2 storage, the economics and efficiency of CCUS processes can be further improved by utilizing the CO2 byproduct in other industry areas. One of the promising methods is to use the captured CO2 for enhanced oil recovery (EOR).

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Corrosion of Cr-Alloyed Steels in Supercritical CO2-Saturated Brine Water

Product Number: 51324-20809-SG

Author: Alexander Gross; Haofei Sun; Jing Liu

Publication Date: 2024

$40.00

In the context of urgent efforts to reduce global carbon emissions, carbon capture, utilization, and storage (CCUS) has gained prominence. Tubing and casing steels are vital materials of construction (MOC) in CCUS systems, especially in supercritical CO2 (s-CO2) environments. However, the understanding of the corrosion behavior of these steels under s-CO2 conditions is limited, which presents integrity challenges. Immersion experiments were conducted with steels containing varying chromium (Cr) levels (0.5 wt% to 16.5 wt%), including P110, P91, and SS 316. These steels were exposed to s-CO2-saturated brine water (3.5 wt% NaCl) at 50 °C and 10 MPa for durations of 10 and 100 hours. Corrosion rates were determined via weight loss measurements, and corrosion products were analyzed with SEM and XRD. P110 displayed the highest corrosion rates (15.7 mm/y at 10 hours, 2.9 mm/y at 100 hours) but developed a thick FeCO3 layer after 100 hours. In contrast, P91 and SS 316 exhibited lower corrosion rates after 100 hours (0.04 mm/y and < 0.01 mm/y, respectively). The influence of Cr content and exposure duration on the corrosion behavior of these steels were discussed. All steels exhibited decreasing corrosion rates over time, primarily due to oxide formation, enhancing the understanding of casing and tubing steel corrosion in s-CO2 environments.

Products tagged with 'corrosion rate'

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