Naphtha and kerosene are mixed with Iraqi heavy crude oil at different concentrations rounded between (3-12) wt.%, in order to reduce viscosity to enhance its followability. This research investigated drag reduction (%Dr) in heavy oil mixtures at different flow rates (2 to 10 m3/hr) in temperature range 20-50C. The experimental results proved that Naphtha offered 40% reduction in pressure drop. The Power law model was adopted in this study to empirically correlate fiction factor (f) and the percentage of drag reduction(%Dr) from experimental data for Reynolds number range (534– 14695) and the concentration range from 3 to12 wt.%.

This work explores the possibility of using Newtonian turbulence k−ϵ and k−ω models for modelling crude oil flow in pipelines with drag reduction agents. These models have been applied to predict the friction factor, pressure drop and the drag reduction percentage. The simulation results of both models were compared with six published experimental data for crude oil flow in pipes with different types of drag reduction agents. The velocity near the wall was determined using the log law line of Newtonian fluid equation and by changing the parameter ΔB to achieve an excellent agreement with experimental data. Simulated data for k−ϵ model shows better agreement with most experimental data than the k−ω turbulence model.

In the operating of TEG- dehydration unit in CentralRumaila Compression Station. Two operating parametersdetermine the efficient operating of the unit, the desired dewpoint depression and the losses of TEG. This work presents anattempt to study the effect of all the operating variables on theefficiency of the dehydration unit such as the effect of pressureand temperature of the natural gas has to be treated on thewater content. Contactor pressure, TEG circulating rate andstripping gas flow rate are also considered in this study. Theresults showed that decreasing the temperature of the absorberfrom 130 F to 120 F will reduce the mass fraction of water inthe dry gas stream from 0.000076 to 0.00002. Increasing theabsorber pressure from 549.7 psia (design pressure) to 600 psiawill also reduce the water content in the outlet dry gas from0.000076 to 0.000022 as a mass fraction. The simulation resultshows a linear relationship between the wet gas flow rate from theregeneration column and the lean glycol flow rate.

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This work describes the steady state simulation of the current performance of the crude oil distillation column at Basrah refinery, Iraq. Steady state simulation results were obtained by ASPEN HYSYS V9 simulation software and compared with the real plant operation conditions, such as temperatures, flowrate of refinery products (total naphtha, kerosene, light gas oil, and heavy gas oil). Also plant experimental ASTM D86 curves of different products were compared to those obtained by simulations. Finally, the temperature and flowrates profiles along the distillation column were obtained. The result shows that the simulated total naphtha mass flow rate (80600 kg/hr) was higher than plant value (73960 kg/hr) flowrate, while simulated residue mass flow rate (203900kg/hr) and waste water mass flow rate (6497 kg/hr) have the lowest mass flowrates than plant data (230200kg/hr,6910kg\hr) respectively. Also the simulated temperatures of product stream for, kerosene, LGO, HGO products (200.3 oC,261.5 oC, and 295 oC) shows good agreement with the plant data (191 oC ,260, oC and 301 oC) respectively, the maximum difference between the plant and simulation results were around 9 oC.