Petroleum University of TechnologyIranian Journal of Oil and Gas Science and Technology2345-24125420161001Table of Content48364ENJournal Article20170715https://ijogst.put.ac.ir/article_48364_e4443b6a36ded8e0c1ad0438f9347584.pdfPetroleum University of TechnologyIranian Journal of Oil and Gas Science and Technology2345-24125420161001An Experimental Study of Surfactant Alternating CO2 Injection for Enhanced Oil Recovery of Carbonated Reservoir1174156410.22050/ijogst.2016.41564ENAsghar GandomkarPh.D. Student, Department of Chemical Engineering, School of Chemical and Petroleum Engineering, Shiraz University, Shiraz, Iran, Petroleum EngineeringBijan HonarvarAssistant Professor, Department of Chemical Engineering, Islamic Azad University, Marvdasht, Shiraz, IranYousef KazemzadehPh.D. Student, Department of Chemical Engineering, School of Chemical and Petroleum Engineering, Shiraz University, Shiraz, Iran, Petroleum EngineeringZeinab DerikvandM.S. Student, Department of Chemical Engineering, School of Chemical and Petroleum Engineering, Shiraz University, Shiraz, Iran, Petroleum EngineeringJournal Article20150628Core flooding experiments were conducted with the objective of evaluating near miscible surfactant alternating CO<sub>2</sub> injection and the effect of surfactant concentrations on gas-oil and water displacements in porous media. The core samples were provided from a low permeability mixed wet oil reservoir at 156 °F and 1900 psia. In addition, very few studies of surfactant adsorption on carbonate minerals have been conducted. Hence, the surfactant adsorption on carbonate rock was determined by core flooding and crushed tests. It was found that for the crushed rock, the required equilibrium time is approximately five hours, while it is more than four days for the flow-through tests. Hysteresis effects demonstrated that the irreducible water saturations were 5 to 10% higher than the initial connate water saturation after drainage cycles during 5000 ppm surfactant solution. Furthermore, near-miscible surfactant alternating CO<sub>2</sub> injection process led to a 4-17% increase in the recovery factor in comparison to water alternating gas process.https://ijogst.put.ac.ir/article_41564_b68bacfc7e0b40746a4e2499219c8b05.pdfPetroleum University of TechnologyIranian Journal of Oil and Gas Science and Technology2345-24125420161001The Effect of Temperature and Injection Rate during Water Flooding Using Carbonate Core Samples: An Experimental Approach18244156910.22050/ijogst.2016.41569ENYaser AhmadiM.S. Student, Department of Petroleum Engineering, Tehran Petroleum Research Center, Petroleum University of Technology, Tehran, IranMehdi HassanbeygiM.S. Student, Department of Petroleum Engineering, Tehran Petroleum Research Center, Petroleum University of Technology, Tehran, IranRiyaz KharratProfessor, Department of Petroleum Engineering, Tehran Petroleum Research Center, Petroleum University of Technology, Tehran, IranJournal Article20131212In many reservoirs, after water flooding, a large volume of oil is still left behind. Hot water injection is the most basic type of thermal recovery which increase recovery by improved sweep efficiency and thermal expansion of crude.In the present work, the effects of injection rate and the temperature of the injected water were surveyed by using core flooding apparatus. Water flooding was performed at different rates (0.2, 0.3, and 0.4 cc/min) and temperatures (20 and 90 °C), and the reservoir temperature was about 63 °C. Oil recovery during hot water injection was more than water injection. Moreover, it was concluded that at injection rates of 0.2, 0.3, and 0.4 cc/min breakthrough time in hot water injection occurred 10 min later in comparison to water injection. The results showed that higher oil recovery and longer breakthrough time were obtained as a result of reducing injection rate. In the first 50 minutes, the oil recovery at injection rates of 0.2, 0.3 and 0.4 cc/min was 27.5, 34, and 46% respectively. It was found that at the beginning of injection, thermal and non-thermal injection recovery factors are approximately equal. Moreover, according to the results, recovery factor at the lowest rate in hot water (T=90 °C and q=0.2 cc/min) is the best condition to obtain the highest recovery.https://ijogst.put.ac.ir/article_41569_61e20558c3201967ef46a8dd94db9cb7.pdfPetroleum University of TechnologyIranian Journal of Oil and Gas Science and Technology2345-24125420161001A Novel Technique for Determination of the Onset of Alkane Induced Asphaltene Precipitation Using Accurate Density Measurements25354157310.22050/ijogst.2016.41573ENMahdi Kalantari MeybodiM.S. Student, Department of Petroleum Engineering, Petroleum University of Technology, Ahwaz, IranJamshid MoghadasiProfessor, Department of Petroleum Engineering, Petroleum University of Technology, Ahwaz, IraJournal Article20140611Onset of asphaltene precipitation is the key parameter in dealing with asphaltene problems because it is the starting point of the asphaltene separation from the solution. In this study, a new technique is provided based on the experimental observations for the determination of the onset of asphaltene precipitation using accurate density measurements of the crude oils upon titration with precipitating agents like n-alkanes. Moreover, density measurements have been conducted for three different crude oils diluted with different ratios of precipitating agents, i.e. n-pentane, n-hexane, and n-heptane. The experimental results confirmed that, as it was expected, the density showed a decreasing trend as the dilution ratio increased, except at one point, at which the density increased with raising dilution ratio; this corresponded to the onset of asphaltene precipitation. For all the crude oils used, a sample diluted with a non-precipitating solvent (toluene) was also used as a reference system, its densities were measured upon titration with toluene, and the results were used for comparison with the other systems diluted with precipitating solvents. The measured onsets of asphaltene precipitation using this technique were confirmed with the onsets obtained by using interfacial tension approach.https://ijogst.put.ac.ir/article_41573_1ff8d3b61941b5b1382bc534fdba2d9c.pdfPetroleum University of TechnologyIranian Journal of Oil and Gas Science and Technology2345-24125420161001A Numerical Study of the Sour Gas Reforming in a Dielectric Barrier Discharge Reactor36524157510.22050/ijogst.2016.41575ENSajedeh ShahsavariAssistant Professor, Department of Chemistry, Payame Noor University, Tehran, IranAlireza Ganjoviprofessor ,Photonics Research Institute, Institute of Science and High Technology and Environmental Sciences, Graduate University of Advanced Technology, Kerman, IranAlireza AhmadiAssociate professor,Department of Mechanical Engineering, Graduate University of Advanced Technology, Kerman, IranFahimeh Shojaei2 Associate professor ,Photonics Research Institute, Institute of Science and High Technology and Environmental Sciences, Graduate University of Advanced Technology, Kerman, Iran
3 Associate professor,Department of Mechanical Engineering, Graduate University of Advanced TechnologyJournal Article20150915In this paper, using a one-dimensional simulation model, the reforming process of sour gas, i.e. CH<sub>4</sub>, CO<sub>2</sub>, and H<sub>2</sub>S, to the various charged particles and syngas in a dielectric barrier discharge (DBD) reactor is studied. An electric field is applied across the reactor radius, and thus a non-thermal plasma discharge is formed within the reactor. Based on the space-time coupled finite element method, the governing equations are solved, and the temporal and spatial profiles of different formed charged species from sour gas inside the plasma reactor are verified. It is observed that the electric field increases radially towards the cathode electrode. Moreover, the electron density growth rate at the radial positions closer to the cathode surface is smaller than the one in the anode electrode region. Furthermore, as time progresses, the positive ions density near the anode electrode is higher. In addition, the produced syngas density is mainly concentrated in the proximity of anode dielectric electrode.https://ijogst.put.ac.ir/article_41575_c7e5ff707623e6c173ff0ffafc315887.pdfPetroleum University of TechnologyIranian Journal of Oil and Gas Science and Technology2345-24125420161001Modeling and Simulation of Kuhni Extraction Column Using a Rate-based Model53674160010.22050/ijogst.2016.41600ENAmir Hosein TahershamsiM.S. Student, Department of Chemical Engineering, Iran University of Science and Technology (IUST), Tehran, IranAhad GhaemiAssistant Professor of Department of Chemical Engineering, Iran University of Science and Technology (IUST), Tehran, Iran0000-0003-0390-4083Mansour ShirvaniAssociate Professor of Department of Chemical Engineering, Iran University of Science and Technology (IUST), Tehran, IranJournal Article20151109In this study, liquid-liquid extraction process in a Kuhni extraction column was modeled and simulated. A non-equilibrium dynamic model was developed for modeling liquid-liquid extraction processes based on a rate-based model. The model equations are inclusive of partial and ordinary differential equations which were discretized in column height direction. The population balance model was used for the calculation of droplet size distribution in the dispersed phase and the column hydrodynamic parameters. The equations were solved simultaneously through the finite difference method and the numerical method of lines. Experimental data on a bench scale Kuhni extraction column was used to evaluate the simulation results. The average correlation coefficient error of the mean diameter of the dispersed phase and mass transfer in various operating conditions are less than 2% 4 % respectively. A comparison between the experimental data and the simulation results proves the better productivity of the presented non-equilibrium dynamic model.https://ijogst.put.ac.ir/article_41600_607d05c6900b613949ac31668420d489.pdfPetroleum University of TechnologyIranian Journal of Oil and Gas Science and Technology2345-24125420161001Anti-corrosive Properties of CeO2 Conversion Coatings on Aluminum Alloy 2024 Prepared by Dip Immersion Method68764160110.22050/ijogst.2016.41601ENNiloufar BahramipanahAssistant Professor, Department of Chemistry, Payame Noor University, P.O.BOX 19395 -3697Tehran, IranIman DanaeeAssistant Professor, Department of Chemistry, Payame Noor University, Tehran, IranMaryam KananiM.S. Student, Department of Petroleum Engineering, Petroleum University of Technology, Abadan, IranMohammad Hosein MaddahyM.S Instructor, Department of Petroleum Engineering, Petroleum University of Technology, Abadan, IranJournal Article20140730As an alternative to chromate conversion coatings, rare-earth coatings especially cerium, because of the low toxicity, have attracted considerable attention. Using dip immersion method, cerium-based conversion coating was deposited on aluminum 2024. Corrosion resistance was studied in 3.5 wt.% NaCl solution using potentiodynamic polarization, electrochemical impedance spectroscopy, and surface methods. The coated samples revealed a considerable decrease in corrosion rate and with increasing immersion time up to 1200 s, the coating resistance increased. Electrochemical impedance data showed that the aluminum charge transfer resistance was increased in the existence of cerium oxide conversion coatings. Using energy dispersive spectroscopy (EDS) and scanning electron microscopy (SEM), the chemical composition and surface morphology were also evaluated.https://ijogst.put.ac.ir/article_41601_924aa882b8a47c77566d1dd817814939.pdfPetroleum University of TechnologyIranian Journal of Oil and Gas Science and Technology2345-24125420161001Persian Abstracts778248365ENJournal Article20170715https://ijogst.put.ac.ir/article_48365_2512641222cca336d83e6b4c3eff4b95.pdf