Global Journal of Researches in Engineering, G: Industrial Engineering, Volume 23 Issue 2

Fig. 5: Contour Plots V. C onclusions In this study, attempts were made to predict the corrosion penetration rate of the pipelines that are used for transporting crude oil between Sarir-Tobruk stations. The corrosion penetration rate values were determined by using Aspen HYSYS V10 software. The following points summarize the conclusions of the study: 1. Based on ANOVA analysis, the four factors considered had significant effects on the corrosion penetration rate, as well as the quadratic effect for pressure and flow rate were significant, while temperature and pH were insignificant. However, the interaction between (temperature and pH), and (pressure and pH) had no significant effect on corrosion penetration rate. Also the interaction between (temperature and pressure), (temperature and flow rate), (pressure and flow rate), and (flow rate and pH) had significant effects. 2. Based on the comparison between the actual values of corrosion penetration rate calculated by using Aspen HYSYS software and the predicted values of corrosion penetration rate by using the RSM technique, it can be concluded that the RSM model could be used to predict the values of corrosion penetration rate, under the specified parameters ranges, with a mean absolute percentage error of 0.02%. 3. The optimal value for the numerically calculated corrosion penetration rate using the RSM model, was found to be 3.98 mm/year, with operating parameters values of temperature (100 °F), pressure (360 psig), flow rate (150,000 bbl/day), and pH (5.65). A cknowledgments The authors would like to thank the engineers at the Arabian Gulf Oil Company's Corrosion Department for giving the data and allowing them to publish the research. R eferences R éférences R eferencias 1. Kermani, M., and Smith, L., “CO2 corrosion control in the oil and gas production design considerations”, European Federation of Corrosion, 1997. 2. Okoro, E., and et al., “Flow line corrosion failure as a function of operating temperature and CO2 partial pressure using real time field data”, Engineering Failure Analysis, pp 160-169, 2019. 3. Dai, M., “In situ mathematically simulation for CO2 internal corrosion in wet natural gas gathering pipelines system by HYSYS”, Engineering Failure Analysis, Vol. 122, 2021. 4. Tang, X., Richter, S., and Nesic, S., “An improved model for water wetting prediction in oil-water two- phase flow”, Corrosion 2013, NACE International, 2013. 5. Abd, A.A., Naji, S.Z. and Hashim, A.S., “Failure analysis of carbon dioxide corrosion through wet natural gas gathering pipelines”, Engineering Failure Analysis, pp 638-646, 2019. 6. Ossai, C.I., “Predictive modelling of wellhead corrosion due to operating conditions: a field data approach”, International Scholarly Research Notices, 2012. 7. Asmara, Y.P., Sutjipto, A.G.E., Kurniawan, J.T. and Siregar, J.J.P., “Analyses corrosion prediction software for co2 corrosion of carbon steel using statistical formulas”, International Journal of Temperature 115 Pressure 470 Flow Rate 195000 PH 5.58 Hold Values Pressure*Temperature 125 115 105 550 500 450 400 Flow Rate*Temperature 125 115 105 240000 220000 200000 180000 160000 PH*Temperature 125 115 105 5.64 5.61 5.58 5.55 5.52 Flow Rate*Pressure 560 480 400 240000 220000 200000 180000 160000 PH*Pressure 560 480 400 5.64 5.61 5.58 5.55 5.52 PH*Flow Rate 240000 200000 160000 5.64 5.61 5.58 5.55 5.52 > – – – < 4.5 4.5 5.0 5.0 5.5 5.5 6.0 6.0 CPR © 2023 Global Journals Global Journal of Researches in Engineering Volume XxXIII Issue II Version I 36 Year 2023 ( ) G Modeling and Optimization of Corrosion Penetration Rate in Crude Oil Pipeline using Response Surface Methodology based on Aspen HYSYS Simulation Software