AMPP Store - Products tagged with 'carbon dioxide'

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Calculation Of Surface Speciation On Mild Steel Under Applied Polarization

Product Number: 51321-16913-SG

Author: Zheng Ma; Bruce Brown; Srdjan Nesic; Marc Singer

Publication Date: 2021

$20.00

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Carbonate Stress Corrosion Cracking of Carbon Steel in Refinery FCC Main Fractionator Overhead Systems

Product Number: 51390-90206-SG

Author: J.H. Kmetz, D.J. Truax

Publication Date: 1990

$20.00

Intergranular cracking and faiulure of carbon steel piping and vessels of FCC Main Fraqctionator overhead systems in NH3-H2S-CO2- containing environments is attributed to carbonate stress corrosion cracking. From plant water sampling program, cracking is correlated with water chemistry, open circuit potential and pH.

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CO2 and the Partial Pressure Bandit

Product Number: 41216-984-SG

Author: James McDonald, Michael Harrison, Douglas Mittlesteadt

Publication Date: 2016

$20.00

Pressurized Atlas Cell Testing is commonly understood to be an aggressive accelerated test for lining systems due the combination of pressure, temperature and a thermal gradient across the coating film known as the Cold Wall Effect. This is especially true when Carbon Dioxide (CO2) is added to the gas phase, as CO2 is miscible with oil and soluble in water. A familiar gas mix of 5% CO2, 5% Hydrogen Sulfide (H2S), and 90% Methane (CH4) are used in test protocols to simulate head space conditions of tanks and pressure vessels in oil and gas production conditions.

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Corrosion Control of Acid Flare Lines at Gas Treatment Facility

Product Number: MPWT19-15242

Author: Ibrahim Albrahim, Ricardo Costa, Jehad Al-Aithan, Maher Al-Abdullatif, Abdulaziz Al- Tijani

Publication Date: 2019

$0.00

In any operating facility, the integrity of flare or relief lines should always be closely maintained, as it is one of the most important safeguards during plant upsets or emergency conditions. The most common damage mechanism in acid flare lines is acid gas dew point corrosion”. Corrosion in such systems is often dependent on fluid stagnation, especially in the presence of acidic water, during idle conditions.
The intent of this paper is to shed light on the efforts done in a gas treatment facility to identify different root causes that impacted or accelerated Acid Gas Dew Point Corrosion. These included design deficiencies, equipment integrity, and process challenges. Moreover, the paper provides findings and recommendations to avoid the occurrence of similar events in acid flare lines.

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Corrosion Management Improvements in Liquids-Rich Shale Play - Pipeline Internal Corrosion Mitigation Case Studies

Product Number: 51324-20990-SG

Author: Monica Fernandez; Chris Jeske; Robert Terry; Ruben Carrera

Publication Date: 2024

$40.00

This paper details the process followed to enhance the pipeline internal corrosion management during operational stage in a liquids-rich shale play, focusing on pipeline internal corrosion mitigation. The process involves several key steps, encompassing a thorough review of historical data (operational conditions, fluid chemistry, corrosion coupons, chemical treatments, pigging activities, inspection results, among others), meticulous data analysis, strategic scheduling, implementation of short-term, mid-term, and long-term actions, followed by periodic monitoring to evaluate barrier performance in conjunction with an inspection plan to confirm asset integrity and optimize resource utilization. The improvements have considered industry best practices, know-how, lessons learned, valuable insights gained from past failures, challenges encountered within upstream operations for corrosion and integrity activities execution, and the actions taken to overcome them.

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Corrosion resistance of 13Cr-5Ni-2Mo Martensitic Stainless Steel in CO2 Environment Containing a Small amount of H2S

Product Number: 92055-SG

Author: M.Ueda, T.Kushida, K.Kondoand T.Kudo

Publication Date: 1992

$20.00

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Corrosion Testing of PM HIPed UNS N06625 and PM HIPed UNS R56400 in Geothermal Environment at Hellisheidi Site

Product Number: 51321-16708-SG

Author: Andri Isak Thorhallsson; Raja Khan; Malallah Al Lawati; Dagur Ingi Olafsson; Sandeep Irukuvarghula; Alessandro Sergi; Saemundur Gudlaugsson; Svava Davidsdottir; Helen Osk Haraldsdottir

Publication Date: 2021

$20.00

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Effect of Carbon Dioxide and Hydrogen Sulfide on the Localized Corrosion Susceptibility of Corrosion

Product Number: 51317--8933-SG

ISBN: 8933 2017 CP

Author: Teresa Perez

Publication Date: 2017

$20.00

The purpose of this review is to discuss environmental effects, especially hydrogen sulfide and carbon dioxide on pitting susceptibility of low alloy steels and corrosion resistant alloys.

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Effect Of Inhibitor Component On Inhibitor Efficiency - Inhibitor Types And Intensifier-

Product Number: 51322-17791-SG

Author: Hirotaka Mizukami, Ayano Yasui, Tatsuya Sei, Takashi Ito, Susumu Hirano, Toshiyuki Sunaba, Akiyoshi Kimura, Reiko Ikeda, Mitsuru Uno

Publication Date: 2022

$20.00

A lot of oil and gas facilities face corrosion problems because the production fluid contains some corrosive components represented by CO₂. Generally, corrosion inhibitors are used in order to mitigate corrosion problems of tubing and pipeline. Imidazoline is known as one of the active ingredients of corrosion inhibitors and widely used in the oil and gas industries. However, imidazoline-type inhibitor is easily hydrolyzed to amide if water mixes into it.

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Effect of Trace Concentrations of H2S Introduced to Existing Sweet Corrosion Product Layers

Product Number: 51323-19261-SG

Author: Adam Cutright, Bruce Brown, David Young

Publication Date: 2023

$20.00

A 2002 study estimated the annual cost associated with corrosion of gas pipelines to be around $5 billion. Corrosion of oil and gas pipelines continues to pose a major issue in the oil and gas industry due to the combination of brine produced with the oil and the type of acid gas present which can lead to significant internal corrosion. Oil and gas reservoirs can be separated into two categories, sweet and sour.

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Enhanced Oil Recovery: Localization of corrosion during polymer flooding

Product Number: 51323-18888-SG

Author: Moritz Schwingenschlögl, Gunther Ball

Publication Date: 2023

$20.00

Traditionally, oil recovery operations are subdivided into primary, secondary and tertiary stages. EOR is commonly classified as tertiary recovery, where gases, liquid chemicals and thermal energy can be used to enhance the displacement of reservoir fluids. Different sources divide EOR into two to five categories, one particular method, polymer flooding, is based on increasing the fluid viscosity by adding a polymer to the injected water. Polymer EOR is a mobility-control process using a polymer-augmented waterflood, typically a solution of partially hydrolyzed polyacrylamide (HPAM) or polysaccharides, which is injected to displace oil towards production wells.

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Evaluation Of Dead Leg Piping with Internal Corrosion at A Salt Dome Natural Gas Storage Facility

Product Number: 51323-19041-SG

Author: Leslie A. Ward, Len J. Krissa, Garry Matocha, Thomas Pickthall

Publication Date: 2023

$20.00

The essence of this paper is to talk about internal corrosion found in deadleg piping at the Enbridge Gas Transmission, & Midstream (GTM) Egan Hub Partners Storage Facility and especially how the corrosion was evaluated after the deadlegs were removed. The salt dome cavern storage facility is in south central Louisiana. The internal corrosion was found in the piping that comes from the storage caverns and goes through pressure reduction stations and then through dehydrations systems.

Products tagged with 'carbon dioxide'

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