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Impurity Reactions in Gaseous and Liquid CO2 Streams

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Safe transportation of CO2 for carbon capture and storage requires strict control of contaminants in the captured CO2, so that corrosion and particulate matter problems are avoided. The present work tested two almost similar CO2 specifications for chemical reactions and liquid or solid drop-out. The tests were carried out with CO2 in liquid and gaseous state, at field-relevant pressure and temperatures. It was shown that the NO2 content had a strong effect on chemical reactions and tendency to drop-out, but the threshold was different depending on the physical state of the CO2. Presence of NO2 resulted in chemical reactions. Drop-outs were observed for 3 ppm-mol NO2 in the liquid state (+4°C, 100 bar) and for 8 ppm-mol in the gaseous state ( -3°C, 25 bar).
Product Number: 51324-20788-SG
Author: Bjørn Helge Morland; Gaute Svenningsen; Johannes Sonke
Publication Date: 2024
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Picture for Material Selection for CCUS Injection Well: A Case Study in North Sea
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Material Selection for CCUS Injection Well: A Case Study in North Sea

Product Number: 51324-21062-SG
Author: Luciana Lima; Cecile Millet; Diana Rodrigues Barrera; Guillaume Néel; Robert Conder
Publication Date: 2024
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Carbon capture utilization and storage (CCUS) are technologies aimed at capturing CO2 and preventing its subsequent emission. Though CO2 transport and injection for enhanced oil recovery (EOR) has been a common practice for the Oil and Gas industry for over 40 years, new challenges arise when the CO2 source is anthropogenic. Industrial CO2 stream composition will carry impurities such as NO2 (nitrogen oxides), SO2 (sulfur oxides), O2 (oxygen), H2S (hydrogen sulfide) that could affect material corrosion behavior. A complete testing program was undertaken to assess the main corrosion risks associated to the application: Sulfide Stress Cracking (SSC), Stress Corrosion Cracking (SCC), crevice and mass loss resistance. The results confirm the effects of impurities such as SO2, NO2 and oxygen on corrosion behavior. Carbon low alloyed steel (N80Q) material presented a higher corrosion rate, and it is not suitable for injection tubing but may be acceptable for casing materials when not permanently exposed to the CO2 stream. UNS S41426 (S13Cr) material needs special considerations for CCS application due the presence of some localized corrosion when exposed to a high saline water phase. UNS S31803 (22Cr) could be suitable for a less severe environment including additional testing, whilst UNS S32760 (25CrS) presented good corrosion behavior and is suitable for the application.
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Compatibility of Dope Free Solution with Dense CO2 Streams

Product Number: 51324-20930-SG
Author: Cecile Millet; Guillaume Néel; Florian Thébault; Pierre Mauger
Publication Date: 2024
$40.00
In the framework of the injection of anthropogenic CO2 for supporting energy transition, more and more wells will be used for injecting dense CO2 streams. Dope free solutions for premium OCTG connections to replace both storage and running thread compounds are beneficial for saving time (lower running time), for environmental considerations (no discharge of dope) as well as improving running performances. However, they have never been qualified in dense CO2 stream environments containing brines, while dense CO2 is known to be a good solvent toward polymers. A test protocol has been designed for that purpose, that combines an exposure to dense CO2 stream then to CO2 saturated brine environment. The objective is to duplicate a CO2 injection well life, from the start of the production, shut-in phases with formation water going up the tubing and restart (saturation of the brines with high CO2 pressure). Evaluation of the performance of a proprietary dope free solution was done by direct comparison with conventional running compounds. It has been observed a resistance of the dope free connection to dense CO2 at least as good as the dope connection on a super duplex material.
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Corrosion reactions in simulated CO2 ship transport conditions

Product Number: 51320-14572-SG
Author: Morten Tjelta, Bjørn Helge Morland
Publication Date: 2020
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For certain CCS (carbon capture and storage) projects, ship transport of captured CO2 to the storage site may prove more optimal than pipeline transport. The CO2 will be transported under two-phase conditions at low temperature (-10 to -25 °C) and moderate pressure (1.7 – 2.7 MPa), which are quite different from the typical pipeline transport conditions (5 – 60 °C and 7 – 12 MPa). Corrosion under pipeline conditions has been relatively well studied, and several conditions (impurity mixtures) that results in formation of corrosive acids have been identified. In contrast, almost no research exists on corrosion under ship transport conditions when the CO2 contains impurities. The present work tested corrosion of carbon steel at -25°C in CO2 with different concentrations of H2O, H2S, O2, NO2 and SO2. The experiments demonstrated that certain combinations of impurities gave no chemical reactions and no corrosion, while other combinations resulted in formation of solids and corrosive components that attacked carbon steel. The mass loss corrosion rate was around 0.1 mm/y. 
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