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Application of corrosion inhibitors confer many advantages for combatting internal pipeline corrosion in the upstream oil and gas industry. It is known that the associated costs for using corrosion inhibitors are low compared to other mitigation techniques [1]. For continuous injection procedures, water-soluble inhibitors are not expected to form long-lasting films, so they must be continuously injected to maintain their effectiveness. Batch inhibitors are usually higher molecular weight species and oil soluble. They tend to be more tenacious, providing a protective barrier between the water and the metal over a long period of time.
Organic corrosion inhibitors (CIs) are widely used in the oil and gas industry to mitigate corrosion in pipeline transmission systems. Upstream, there are two distinct internal pipeline corrosion mitigation methods using inhibitors: continuous injection and batch inhibition. Each treatment mode has its own challenges, requiring specific knowledge of inhibitor film persistency (i.e., interrupted continuous injection or irregularity in batch inhibitor application frequency). The performance of applied corrosion inhibitors is typically evaluated in laboratory conditions, prior to field application. This study is focused on development of methodologies to investigate inhibitor film persistency using inhibitor model compounds, possessing only one molecular type, in both continuous and batch inhibition. For persistency studies related to continuous treatment, experiments were divided into three main steps: pre-corrosion, inhibitor addition, and inhibitor dilution. For batch inhibition, an inhibitor testing procedure was developed that can maintain stable water chemistry and avoid O2 contamination, with the potential to be adapted for top-ofthe-line corrosion (TLC) environments. Corrosion rates were monitored using linear polarization resistance (LPR) in all experiments (except in TLC conditions). The Langmuir isotherm model was used to calculate adsorption coefficient kA and desorption coefficient kD for benzyldimethylammonium (BDA) inhibitor model compounds, possessing tetradecyl and hexadecyl tails, at different temperatures.
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TOL corrosion is reported to occur in large diameter wet gas pipeline in stratified flow conditionsdue to low fluid velocities1. With increasing distance from the inlet, the wet gas pipeline becomescooler as it loses heat to the environment. Such cooling causes water, hydrocarbon, and otherhigh vapor pressure species to condense on the pipe wall. The upper part of the pipe willconstantly be supplied with freshly condensed water while the less corrosive water saturatedwith corrosion products will be drained along the pipe wall to the bottom of the line.
A forty foot well annulus simulator is used to determine the flow and fate of the applied chemical inhibitors for typical backside batch and flush application in a packerless completion. The delivery depends upon both chemical parameters such as density, viscosity, and surface tension as well as flush parameters including volume and rate.