AMPP Store - Products tagged with 'co2'

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Current Industry Practice in Carbon Capture Corrosion, and the Knowledge Gap it Produces

Product Number: 51323-19539-SG

Author: Mark McLeod, Ivan Gutierrez, Brad Healey, Tundzhay Kurtulan

Publication Date: 2023

$20.00

Vital work is being carried out across engineering to ensure the net-zero commitments as laid out in the Paris agreement are met. Due to increased government investment, carbon capture, utilisation, and storage (CCUS) has become key to achieving these commitments, with some industries only able to decarbonise through CCUS, such as concrete or fertiliser production. Carbon capture has also moved away from vertically integrated systems, with single emitters having dedicated downstream transport and storage sites, to larger systems gathering CO2 with a shared transport and storage infrastructure.

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Development of Sucker Rods for Aggressive Environments

Product Number: 51317--8944-SG

ISBN: 8944 2017 CP

Author: Martin Buhler

Publication Date: 2017

$20.00

A Cr-Mo-B-Ti low alloyed steel, with a special quenched and tempered heat treatment, was designed. Corrosion fatigue resistance of the new material was evaluated at lab scale. Field tests are being carried out in 26 wells where sucker rods had failed for years.

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Effect of Aggressive Substance on the Nature of Corrosion Scales Formation on Super 13Cr Stainless Steel in Formate Completion Fluid

Product Number: 51321-16311-SG

Author: Xiaoqi Yue/ HangCao/ Lei Zhang/MinxuLu/LeiMa/Mifeng Zhao/Yong Hua

Publication Date: 2021

$20.00

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Fitness-for-Purpose Testing of UNS R30003, UNS R30035, UNS N07718 and UNS N09946 in Environment with H2S, CO2, and High-Chlorides

Product Number: 51324-20839-SG

Author: Noelle Easter C. Co; Ravi M. Krishnamurthy; Kenneth George; Bjørn-Andreas Hugaas; Ragnar Marcelius Fredriksen

Publication Date: 2024

$40.00

Critical equipment in high pressure high temperature (HPHT) oil and gas wells are commonly made of superalloys. Components in these wells require both high strength and corrosion resistance. In this study, four superalloys: Elgiloy (UNS R30003), MP35N (UNS R30035), Alloy 718 (UNS N07718) and 945X (UNS N09946) were tested in an environment with H2S, CO2, and high chlorides. Four-point bend tests were performed with N07718 and UNS N09946 materials while three-point bend tests were done on UNS R30003 and UNS R30035 in an autoclave with pH2S of 0.025 bar and pCO2 16.6 bar, and 308 g/L Cl- at 363°F for 30 days. Neither cracking nor pitting was observed on any of the four-point or three-point bend specimens. In addition to four-point bend testing, slow strain rate tests were performed on UNS N07718 and UNS N09946 materials. Results of the slow strain rate test showed no significant decrease in ductility in either UNS N09946 or UNS N07718. However, UNS N09946 performed better than UNS N07718 in a high chloride environment based solely on SSRT results.

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Guidelines for Corrosion Inhibitor Selection for Oil and Gas Production

Product Number: 51317--8842-SG

ISBN: 8842 2017 CP

Author: Johannes Sonke

Publication Date: 2017

$20.00

Recommended corrosion inhibitor (CI) testing methods and interpretation to assure proper execution of a test program. Associated guidance for CI test program definition testing and management to ensure and improve the integrity of carbon steels applications in our Industry.

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Guidelines for Using Water Analysis for Corrosion Prediction- Sampling Analysis and Data Interpretation

Product Number: 51323-19421-SG

Author: Y. Zheng, J. Sonke, B. Brown

Publication Date: 2023

$20.00

Various corrosion prediction tools for CO₂/H₂S corrosion have been developed in the past thirty years. For corrosion analysis in oil and gas production, the water chemistry largely determines the corrosion rate which is mainly driven by in-situ pH.

The in-situ water or brine is pressurized with acid gases (CO₂/H₂S) which results in a decrease in pH and typically an increase in the corrosion rate.

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H2S, CO2 and High Chloride Downhole Environment Modelling and Fitness for Purpose Testing of UNS S39274, UNS N08535 and UNS N06255 Corrosion Resistant Alloys

Product Number: 51324-20838-SG

Author: Noelle Easter C. Co; Ravi M. Krishnamurthy; Kenneth George; Bjørn-Andreas Hugaas; Ragnar Marcelius Fredriksen

Publication Date: 2024

$40.00

Aker BP is planning to drill four high-pressure, high-temperature wells in a gas field. The produced fluids are primarily composed of gas condensate with formation water. The operator anticipates a chloride environment greater than 120,000 mg/L in these four wells. ISO 15156 specifies a chloride limit of 120,000 mg/L for super duplex alloys for downhole applications. The objectives of this study are to determine the chemistry inside these four wells, to identify the test parameters representative of the downhole environment, and to assess if UNS S39274, UNS N08535 and UNS N06255 are suitable tubing materials. Thermodynamic modeling based on the anticipated production rate from each well was employed for the determination of downhole chemistry. Results show that chloride concentration can reach 308,000 mg/L. Scaling of halite, barite, calcite, and aragonite was also predicted to occur at certain depths inside the well. The parameters used for fitness-for-purpose testing were selected based on chloride conditions with and without halite scaling. The performance of UNS S39274, UNS N08535 and UNS N06255 was assessed using four-point bend tests, crevice corrosion tests, and slow strain rate tests in the simulated downhole environment with 0.025 bar pH2S, 16.6 bar pCO2 and high chloride concentration. No cracking was observed on UNS S39274 and UNS N06255 four-point bend specimens. However, one out of twelve UNS N08535 specimens tested exhibited a crack at a location outside the inner roller of the four-point bend jig. The corrosion rates of UNS S39274, UNS N08535, and UNS N06255 based on mass loss are 0.18 mpy, 0.23 mpy, and 0.09 mpy, respectively. Slow strain rate test results showed no significant loss in ductility, and no secondary cracking when specimens were tested in downhole high chloride conditions. The overall results of the study indicated that these corrosion resistant alloys are able to withstand chloride concentrations beyond the specified limits when H2S partial pressure is low.

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Impact of O2 Content on Corrosion Behavior of X65 Mild Steel in Gaseous, Liquid and Supercritical CO2 environments

Product Number: 51320-14433-SG

Author: Xiu Jiang, Dingrong Qu , Xiaoliang Song

Publication Date: 2020

$20.00

CO2 stream in CCS system usually contains impurities, such as water, O2, SO2, NO2, H2S, and other trace substances, which could pose a threat to internal corrosion and integrity of CO2 transportation pipelines. The general and localized corrosion behavior of API 5L X65 mild steel were evaluated using an autoclave both in water-saturated CO2 and CO2-saturated water environments in the presence of varying concentrations of O2. Experiments were performed at 25 °C and 35 °C, 8 MPa and 35 °C, 4 MPa to simulate the conditions encountered during dense, supercritical and gaseous CO2 transport. General corrosion rates were obtained by weight-loss method. The surface morphology of the coupons was examined by scanning electron microscopy (SEM). Results indicated that general corrosion rates at each O2 concentration in CO2-saturated water environment were much higher than those in water-saturated CO2 environment. The corrosion rates did not increase with increasing O2 concentration from 0 to 2000 ppm; instead the corrosion rate reached a maximum with 1000 ppm O2 at 25 °C, 8 MPa and 50 ppm O2 at 35 °C, 8 MPa in water-saturated CO2 environment and 50 ppm at 25 °C, 8 MPa and 100 ppm at 35 °C, 8 MPa in CO2-saturated water environment. However, the change trend of general corrosion rate with O2 content at 35 °C, 4 MPa was different from that in 25 °C and 35 °C, 8 MPa both in water-saturated CO2 and CO2-saturated water environments. Localized corrosion or general corrosion rate of over 0.1 mm/y was identified at each test condition both in a water-saturated CO2 and CO2-saturated water environments. When O2 was added, coupon surfaces were covered by a more porous corrosion product scale. A final series of tests conducted with the addition of 100 ppm and 2000 ppm O2 in CO2 environment with 60% relative humidity (RH) and 80% RH revealed that no localized corrosion was observed and the general corrosion rates were lower than 0.1 mm/y at 25 °C and 35 °C, 8

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Lab Performance Testing on Corrosion Inhibitors Under Supercritical Carbon Dioxide Conditions

Product Number: 51317--9474-SG

ISBN: 9474 2017 CP

Author: Larry Chen

Publication Date: 2017

$20.00

This paper discusses the design philosophy for corrosion inhibitors used for carbon capture, transportation, and storage and the performance testing using rotating cylinder autoclave (RCA) and electrochemical impedance spectroscopy (EIS) methods under CO2 supercritical conditions.

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Non-Abrasive Surface Preparation

Product Number: 51217-078-SG

Author: David Watson

Publication Date: 2017

$20.00

While traditional cleaning solutions can be time consuming, costly and ineffective, dry ice blast cleaning provides a completely dry solution that cleans faster and more efficiently, while reducing downtime and supporting environmental initiatives. This presentation will discuss the basic concepts of dry ice cleaning. Participants will learn the benefits of the process, as well as, how it can benefit their production, improve quality, and support an environmentally responsible production environment.

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On-Line Real-Time Corrosion Monitoring Techniques Under Co2 - Brine Environment – Comparative Study

Product Number: 51317--9040-SG

ISBN: 9040 2017 CP

Author: Hui Li

Publication Date: 2017

$20.00

Injection water/brine handling systems are important elements of the oil & gas field operations. This comparative study offers insights relevant to accuracy, sensitivity and responsiveness of different corrosion monitoring techniques in brine environment.

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Role Of Acetic Acid On The Kinetics And Mechanism Of Carbon Steel Dissolution Under CO2 Top Of Line Corrosion

Product Number: 51322-17818-SG

Author: Mariana Costa Folena, José Antônio da Cunha Ponciano Gomes, Frederick Pessu, Anne Neville, Richard Barker

Publication Date: 2022

$20.00

Top of line corrosion (TLC) is a specific corrosion mechanism observed in the oil and gas industry. This phenomena occurs under stratified or wet-gas flow regimes when the upper internal pipeline walls are sufficiently cooled (by heat transfer to the surrounding outer environment), promoting local condensation of water vapor. Carbon dioxide (CO₂) and organic acids dissolving into the condensed water generate a change in the solution chemistry, ultimately influencing the corrosion kinetics of the contacting carbon steel.

Products tagged with 'co2'

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