In the oil and gas production industry carbon steel tubing and piping are susceptible to erosion-corrosion damage due to the erosive and corrosive nature of the flow. The combined effect of solid particle erosion and corrosion can increase the metal degradation rate while simultaneously decreasing the efficiency of corrosion protection systems including iron-carbonate scale formation and chemical inhibition. These combined effects can lead to higher corrosion rates surface pitting and material failure. Thus prediction of chemical inhibitor effectiveness when solid particles are being produced particularly important. Modeling this behavior is critical when the wells are deep or off-shore because coupon testing is impractical and replacement costs are high. Considerable research has been devoted to investigate the effect of sand erosion on the efficiency of corrosion inhibitors in sweet production/CO2 environments in presence of sand particles. However sand particles are not the only particles that occur during oil and gas production. Calcium carbonate (CaCO3) particles can also be produced during oil and gas production because the majority of oil and gas production in the world is from carbonate reservoirs where calcium carbonate (CaCO3) particles can enter into the flow of produced gas and oil. Currently little is known about the erosive effects of CaCO3 particles on the performance of corrosion inhibitors in CO2 environments. This paper describes experimental and modeling studies directed at understanding the influence of CaCO3 particles on the effectiveness of imidazoline-based inhibitor in reducing CO2 corrosion of carbon steel material. The performance of the inhibitor with CaCO3 particles is compared with the inhibitor performance for a flow containing sand particles. A phenomenological model based on Frumkin-type isotherm is presented as a technique for predicting inhibitor effectiveness for these flow conditions. Erosion-corrosion experiments were performed using flow loop set up with a direct impingement configuration in an iron carbonate forming environment. Electrochemical linear polarization resistance and weight loss methods were utilized to experimentally characterize erosion-corrosion rates for both types of solid particles.

Crude oils with a total acid number (TAN) higher than 0.5 are highly corrosive at temperatures between 400 and 700°F typical to atmospheric and vacuum distillations of oil refineries. This destructive effect of naphthenic acids (NAP) is enhanced by the presence of hydrogen sulfide generated in thermal decomposition of sulfur compounds also contained in crude oils. The efforts of mitigating the acidic crudes corrosive effects include blending such oils with crudes of lower acids content neutralization or removal of naphthenic acids from oils and the use of corrosion inhibitors. Most commonly used inhibitors for mitigating the NAP corrosion are based on organic polysulfides or on phosphate esters. Two phosphate esters corrosion inhibitors were evaluated in laboratory experiments using a specific testing procedure – “pretreatment - challenge”. This experimental method evaluates the naphthenic corrosive effects at high temperature on scales formed from crude factions on metal surfaces. Adding the inhibitors to the crude fractions improved the protective properties of scales formed under such conditions. The corrosive effect of naphthenic acid was evaluated by sample weight loss. The scales formed on these samples were investigated using scanning electron microscopy (SEM) and transmission electron microscopy (TEM) coupled with energy dispersive spectroscopy (EDS).Keywords: phosphate esters corrosion inhibitors naphthenic acids high temperature

Coatings have the function of resistance to environmental attack i.e. barrier protection abrasion chemical yet a number of them have not been optimized to give high resistance against wetting when it comes to dual or enhanced properties that can result to higher durability. Moreover the wetting phenomena in coatings are also under-appreciated when it comes to de-icing and anti-MIC properties. This talk will highlight the fabrication of durable coatings with superhydrophobic coatings that can be fabricated from electrochemical polymers casted coatings and thermosetting curable coatings that can display superhydrophobic coatings and their resistance to corrosion. The applications of these properties could be in the preparation or augmentation of high-performance properties to existing coatings as well as addressing the various needs for exposure to transmission oil water and heat exchangers cooling tower coatings oil-water separation or purification etc. The test will also highlight unique opportunities for high-throughput testing with PETRO Case.