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51316-7681-Comparison of Corrosion Behavior of X65 1Cr and 5Cr Steels in Water-Containing Supercritical CO2 Environments with SO2/O2

Picture for Comparison of Corrosion Behavior of X65 1Cr and 5Cr Steels in Water-Containing Supercritical CO2 En
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Product Number: 51316-7681-SG
ISBN: 7681 2016 CP
Author: Yong Hua
Publication Date: 2016
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A systematic study is undertaken to study the corrosion behavior of three different steels (X65 carbon steel 1Cr steel and 5Cr steel) that could be considered as pipeline/tubular materials for the transport and/or injection of supercritical CO2 for carbon capture and storage (CCS) applications. The purpose of the research is to establish the influence of low Cr-bearing steels on the critical water content required to avoid substantial levels of internal corrosion in an impure supercritical CO2 system containing sulphur dioxide (SO2). Experiments were performed in autoclaves containing supercritical CO2 at 80 bar and 35°C in the presence of 100 ppm (mole) SO2 under various levels of humidity from 0 to 100%. General and localized corrosion rates for all three materials were determined over a period of 48 hours through the implementation of gravimetric analysis and surface profilometry respectively. Scanning electron microscopy (SEM) energy dispersive X-ray spectroscopy (EDS) X-ray diffraction (XRD) and Raman spectroscopy were all implemented to assist in identifying surface corrosion products. For all three steels evaluated the results indicate that 5Cr steel enables a higher critical water content to be tolerated before a general corrosion rate of 0.1 mm/year is reached in the presence of 100 ppm SO2. The results show that for each material tested the water content required to avoid excessive localized corrosion in these specific environments is far less than that to prevent significant general corrosion. No corrosion attack was observed at a water content of 650 ppm for 5Cr steel while X65 and 1 Cr produced signs of corrosion. The research presented highlights that one option for controlling the corrosion rate under specific impure supercritical CO2 conditions may be through the implementation low Cr steels which do not impose a significant cost penalty compared to corrosion resistant alloys.
A systematic study is undertaken to study the corrosion behavior of three different steels (X65 carbon steel 1Cr steel and 5Cr steel) that could be considered as pipeline/tubular materials for the transport and/or injection of supercritical CO2 for carbon capture and storage (CCS) applications. The purpose of the research is to establish the influence of low Cr-bearing steels on the critical water content required to avoid substantial levels of internal corrosion in an impure supercritical CO2 system containing sulphur dioxide (SO2). Experiments were performed in autoclaves containing supercritical CO2 at 80 bar and 35°C in the presence of 100 ppm (mole) SO2 under various levels of humidity from 0 to 100%. General and localized corrosion rates for all three materials were determined over a period of 48 hours through the implementation of gravimetric analysis and surface profilometry respectively. Scanning electron microscopy (SEM) energy dispersive X-ray spectroscopy (EDS) X-ray diffraction (XRD) and Raman spectroscopy were all implemented to assist in identifying surface corrosion products. For all three steels evaluated the results indicate that 5Cr steel enables a higher critical water content to be tolerated before a general corrosion rate of 0.1 mm/year is reached in the presence of 100 ppm SO2. The results show that for each material tested the water content required to avoid excessive localized corrosion in these specific environments is far less than that to prevent significant general corrosion. No corrosion attack was observed at a water content of 650 ppm for 5Cr steel while X65 and 1 Cr produced signs of corrosion. The research presented highlights that one option for controlling the corrosion rate under specific impure supercritical CO2 conditions may be through the implementation low Cr steels which do not impose a significant cost penalty compared to corrosion resistant alloys.
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Picture for Corrosion Assessment of Pipeline Steels in Supercritical Carbon Dioxide Stream
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51316-7223-Corrosion Assessment of Pipeline Steels in Supercritical Carbon Dioxide Stream

Product Number: 51316-7223-SG
ISBN: 7223 2016 CP
Author: Yimin Zeng
Publication Date: 2016
$20.00

Carbon Capture and Storage (CCS). The CO2 stream, captured from power plants contains highly corrosive impurities including H2O vapor, oxygen, and hydrogen sulfide. This paper presents our study on corrosion of pipeline steel in sc-CO2 containing H2O, H2S and/or O2 impurities in an autoclave.
Picture for 09255 Corrosion in Super Critical CO2
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09255 Corrosion in Super Critical CO2

Product Number: 51300-09255-SG
ISBN: 09255 2009 CP
Author: Feng Gui, Francois Ayello, Narasi Sridhar and Ramgopal Thodla
Publication Date: 2009
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Picture for Impact of O2 Content on Corrosion Behavior of X65 Mild Steel in Gaseous, Liquid and Supercritical CO2 environments
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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
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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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