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To analyse the influence of a non-corrosive hydrocarbon liquid phase with respect to CO2-corrosion in pipe flow and increase the understanding of use of natural inhibitors in the hydrocarbon liquid phase, an experimental study of corrosion and water distribution on the pipe wall has been carried out.
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The influence of acetate ion on the rate of corrosion of carbon steel (X65) in 3 % NaCl brine saturated with carbon dioxide has been investigated using voltammetry at a rotating disc electrode. The rate of corrosion can only be understood if it is recognised that the cathodic process in the steel corrosion is affected by acetic acid.
The NORSOK M-506 is an empirical model based on experiments undertaken in a single phase water flow loop. The data is from experiments with low content of iron ions in the water phase, and the model is thus regarded to give a fair representation of the maximum corrosion rate in a CO2 corrosion controlled system.
This paper discusses a classic example where the facts surrounding the failure of a lining system were ignored and undue reliance was placed on laboratory analysis. This “blind faith” in analytical data without a sound causal theory caused the failure analysts to disregard or overlook the obvious.
The work conducted produced conditions where preferential weld corrosion initiated in uninhibited conditions and was sustained throughout inhibition. Two types of weld metallurgies; one weld consumable with 1% nickel, the second matched the parent pipe.
This paper discusses the detailed inspection, testing, metallurgical analysis and supporting factors from which the most likely cause of pitting corrosion was revealed in the DSS flowline welds.
Effects of H2O and SO2 on oxidation in a CO2 environment. Experiments at 1 and 25 bar at 700° to 800°C in CO2, CO2+10%H2O and CO2+10%H2O+0.1%SO2. Alloys S30409, N07230, N07208 and superalloy N07247 exposed. Reaction products were characterized.
The increased corrosion rates of mild steel in acidic solutions in the presence of CO2, previously associated with carbonic acid direct reduction, are in fact due to the increased rate of iron dissolution in the presence of CO2
Fracture mechanical properties of scales from wet corrosion were considered with respect to the initiation steps of flow induced localized corrosion (FILC) of steel under conditions of scale forming corrosion processes.
Carbon capture and storage (CCS) represents to traditional industrial emitters a critical transitional technology to globally manage greenhouse gas emission, meet the latest carbon net-zero ambitions, and continue the commercial use of fossil fuels. In CCS, anthropogenic CO2 is captured near emission, treated, compressed, transported (usually by steel pipelines), injected underground through casings, tubings, and completion equipment, and finally permanently stored into saline formations, aquifers, depleted (abandoned) reservoirs, or un-mineable coal seams. [1] Depending upon emitters, the injected CO2 is either near or in a dense state (i.e., indistinctly including a supercritical phase and potentially liquids) having various impurities.