By M. B. Kermani, L. M. Smith
Addresses the stairs essential to layout oil and gasoline dealing with amenities contemplating key surroundings parameters which impression CO2 corrosion probability in several components of the amenities. It considers corrosion keep watch over by using corrosion allowance on metal and deployment of inhibitors. this can be the 1st record which tackles all features helpful to handle CO2 corrosion layout of all goods of oil box apparatus and amenities incorporating creation, processing and transportation
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Extra info for B0688 CO2 Corrosion control in oil and gas production
G. ). A 'commercial' inhibitor is thus a blend, whose activity is currently much higher than that of the non-formulated active molecule. Prior to being applied, an inhibitor must be proven to be an innocuous additive. Therefore, its technological properties (non-foaming, non-gunking, etc), often improperly called 'secondary', must be tested before the field application. Based on these requirements, an inhibitor package needs to incorporate a combination of characteristics to be effective. 5. Inhibitor Compatibility It should be noted that corrosion inhibitors can act as emulsifying agents and can lead to foaming which may decrease the effectiveness of the separation process.
6. Inhibitor Deployment Since corrosion inhibitors are relied u p o n to protect an entire h y d r o c a r b o n transmission line, transport of inhibitors to all areas needing protection is necessary. Three methods of transport include: dissolution (or suspension) in the p r o d u c e d fluids and relying on the movement of the produced fluid to transport the inhibitor; transport in a carrier fluid added to the flow stream; and transport between p i g s - batch treatment. Combinations of the above such as inhibited gel transport between pigs are also possible.
A case is made for rationalising monitoring and inspection data with predicted rates, to strengthen the relevance and validity of the latter, whilst working to introduce a stronger predictive element to the former. Figure 5 summarises the necessary overall critical steps identified in working to define a risk of CO 2 corrosion. 4). 1. C O 2 Corrosion Prediction M o d e l s For Carbon Steel Different oil companies and research institutions have developed a large number of prediction models. 22) gives an overview of the parameters treated in To Hydrodynamics: ~ [ Acid(H2s)Co2gases: ] Local/bulk flow regimes | p of line/Bottom of lineJ Fluid chemistry: Steel: Composition Microstructure eld; composition, profile CO 2 corrosion design Local/bulk analyses pH, organic acids Operating condition: Temperature, pressure Number of phases, water cut Controlling Parameters: Micro-alloying elements Corrosion inhibition Glycol and methanol pH-control (over the life of the field) r- Others: Initial production condition Trend of water cut Carbonate scale Scale inhibitor Other additives Fig.
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