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This paper reviews the effect of low molecular weight organic acids ( acetic, propionic, butyric) on corrosion rates in the presence of CO2. The effect of the mineral content of the produced water is also discussed. Laboratory methods for determining the concentration of low concentrations of organic acids are discussed. Laboratory and field data are presented.
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There is uncertainty about the best way to determine the corrosion risk for gas-condensate pipelines, and use of chemical inhibitors as mitigation strategy. We present considerations when devising corrosion mitigation and inhibition strategies, as well as a recommended test for inhibitor qualification.
In this work, sour TLC was systematically studied in autoclaves with a special holder that exposed one side of the TLC coupon while the back side was exposed to cooling liquid.
This work presents a combined modeling and experimental methodology to determine the onset of droplet entrainment from the bottom and deposition at the top of the line.
A visual inspection of a subsea field development, transporting wet gas, containing approximately 1.5 to 2 mol% of CO2 to shore, was conducted via ROV (remotely operated vehicle). The pipeline system is largely carbon steel with only short lengths of CRA (corrosion resistant alloy) piping from the wellhead to the production/pigging manifold. Downstream of the pigging manifold the system has 20” carbon steel spools leading to the FTA (flowline termination assembly) and then 20” carbon steel flowlines to the riser platform.
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.
In this work, a specially made sample holder that can be fitted inside regular autoclaves was used for simulating sour TLC in the presence of methanol. The experiments showed that for 10 bar H2S + 10 bar CO2, the TLC mass loss rate was 0.2-0.3 mm/y of general corrosion without localized attacks.
The first case of top of line corrosion (TLC) in Tunu gas field was reported by Gunaltun et al in 19991. Inlineinspection (ILI) of two carbon steel pipelines distributing multiphase effluent, showed up to 50% metalloss at 11.00 – 01.00 o’clock at several sections. Visual examination of a cut section showed that the topof line was covered with iron carbonate layer with deep pits, and severe metal loss occurred on largesurfaces at these area.