ORIGINAL_ARTICLE
Impact of H2S Content and Excess Air on Pollutant Emission in Sour Gas Flares
In sour gas flares, content like any other components in inlet gas influences adiabatic flame temperature, which, in turn, impacts on the pollutant emission. Wherever flame temperature increases, the endothermic reaction between and is accelerated, which means higher emission to the atmosphere. In this work, we developed an in-house MATLAB code to provide an environment for combustion calculations. Then, this written code was used to perform sensitivity analyses on content, air temperature, and excess air ratio in sour gas flares. We used Environmental Protection Agency (EPA) reports to assign weighting indexes to each air contaminant according to its harmfulness to environment; thereafter, sour gas flaring conditions were optimized for two real field case studies, namely Ahwaz (AMAK) and South Pars, to reach the minimum integrated pollutant concentrations. The results show that each 2% increase in the content of the entrance feed may produce 0.3% additional in the exhaust. The results also confirm that decreases of 20 °F and 50 °F in the oxidant temperature cause emission to reduce by 0.5% to 1% respectively. Finally, to verify and validate our results acquired from the written MATLAB code, FRNC 2012 industrial software was used to duplicate the oxidation results for the two sour flare case studies.
https://ijogst.put.ac.ir/article_85256_965090a7e4fced300e59e9d35c8513da.pdf
2019-01-01
1
10
10.22050/ijogst.2018.127937.1450
Sour Gas Flares
EPA Environmental Reports
Pollutant Emission
FRNC Software
Ahmed
Zoeir
ah_zoeir@sut.ac.ir
1
M.S. Student, Faculty of Petroleum and Natural Gas Engineering, Sahand University of Technology, Tabriz, Iran
AUTHOR
Alireza
Tabatabaei Nejad
tabatabaei@sut.ac.ir
2
Professor, Faculty of Petroleum and Natural Gas Engineering, Sahand University of Technology, Tabriz, Iran
AUTHOR
Elnaz
Khodapanah
ekhodapanah@yahoo.com
3
Associate Professor, Faculty of Petroleum and Natural Gas Engineering, Sahand University of Technology, Tabriz, Iran
LEAD_AUTHOR
Abdulkareem, A. S., Urban Air Pollution Evaluation by Computer Simulation: A Case Study of Petroleum Refining Company Nigeria, Leonardo Journal of Sciences, Vol. 4, No. 6, p. 17-28, 2005.
1
Abdulkareem, A. S., Odigure, J. O., and Abenege, S., Predictive Model for Pollutant Dispersion from Gas Flaring: A Case Study of Oil Producing Area of Nigeria, Energy Sources, Part A: Recovery, Utilization, and Environmental Effects, Vol. 31, No. 12, p. 1004-1015, 2009.
2
Al Rubai, H. A. G., Mathematical Modeling for Dispersion of Air Pollutants Emitted from Al Daura Oil Refinery Stacks, Master Thesis, University of Baghdad, 1999.
3
EPA, Enforcement Targets Flaring Efficiency Violations, Enforcement Alert, US Environmental Protection Agency, 2012.
4
EPA, Needs to Improve Air Emissions Data for the Oil and Natural Gas Production Sector, Office of Inspector General, US Environmental Protection Agency, 2013.
5
EPA, Proffered and Alternative Methods for Estimating Air Emission from Oil and Gas Field Production and Processing Operations, 1999.
6
Gzar, H. A. and Kseer, K. M., Pollutants Emission and Dispersion from Flares: A Gaussian Case-study in Iraq, Journal of Al-Nahrain University, Vol. 12, No. 4, p. 38-57, 2009.
7
Ismail, O. S. and Umukoro, G. E., Modelling Combustion Reactions for Gas Flaring and its Resulting Emissions, Journal of King Saud University, Engineering Sciences, Vol. 28, No. 2, p. 130-140, 2014.
8
Kahforoushan, D., Bezaatpour, J., and Fatehifar, E., Effect of Various Parameters on Emission Factors of Gas Flares, Iranian Journal of Chemical Engineering, Vol. 11, No. 3, p. 59-66, 2014.
9
Kahforoushan, D., Fatehifar, E., Babalou, A. A., Ebrahimin, A. R., Soltanmohammadzadeh, J. S., and Elkamel, A., Modeling and Evaluation of Air Pollution from a Gaseous Flare in an Oil and Gas Processing Area, WSEAS Conference, Spain, 2008.
10
Kahforoushan, D., Fatehifar E., and Soltan, J., The Estimation of Emission Factors for Combustion Sources in Oil and Gas Processing Plants, Energy Sources, Vol. 33, No. 3, p. 202-210, 2010.
11
McMahon, M., Estimating the Atmospheric Emission from Elevated Flares, BP Amoco Annual Report, 1994.
12
Susu, A. A., Abhulimen, K. E., and Adereti, A. B., Modeling of Air Pollution Systems with Chemical Reactions: Application to Gas Flares in Nigeria, International Journal for Computational Methods in Engineering, Vol. 6, No. 3, p. 201-213, 2005.
13
Talebi, A., Fatehifar, E., Alizadeh, R., and Kahforoushan, D., The Estimation and Evaluation of New , , and Emission Factors for Gas Flares Using Pilot Scale Flare, Energy Resources, Vol. 36, No. 7, 2014.
14
Umukoro, G. E. and Ismail, O. S., Modelling Emissions from Natural Gas Flaring, Journal of King Saud University, Engineering Sciences, Vol. 29, No. 2, p. 178-182, 2015.
15
ORIGINAL_ARTICLE
A Numerical Investigation into the Effect of Controllable Parameters on the Natural Gas Storage in a Weak Reservoir-type Aquifer
Natural gas storage process in aquifer, due to fluid flow behavior of gas and water in the porous medium and because of their contact with each other under reservoir conditions, faces several challenges. Therefore, there should be a clear understanding of the injected gas behavior before and after the injection into the reservoir. This research simulates the natural gas storage in aquifer by using Eclipse 300 software. For this purpose, a core sample was considered as the porous medium for gas injection, and a composition of natural gas was injected into the core in different conditions. Moreover, by using Plackett-Burman method, all of the factors affected in this process were screened, and finally four main significant parameters, including the flow rate of injected gas, permeability, pressure, and irreducible water saturation were selected for designing a design of experiments (DOE) plan. Response surface method (RSM) is one of the best methods of experimental design used for optimizing the process and finding the best combination of parameters to have a high stored gas volume and a high recovered gas volume. The simulation includes 28 runs with four considered parameters, and the output is the recovered gas, which in turn is vital for the process accomplishment. Sensitivity analysis and grid independency test were checked. To this end, three grids with different number of cells in x-direction were generated, and by analyzing the results of gas saturation in the porous medium for each model, a grid with 11250 cells (50 elements in x-direction and 15 elements in y- and z-directions) was then chosen as the main grid. Uncertainty analysis and the validation of numerical simulations were carried out, and good agreement was observed between the numerical results and experimental data. In addition, the numerical results showed that the flow rate of the injected gas had a significant impact on the process in comparison with other parameters. Furthermore, increasing permeability and decreasing pressure and irreducible water saturation raise the amount of trapped gas in aquifers. Therefore, for having the maximum stored gas volume and a high recovered gas volume, the best combination of parameters is a high gas injection flow rate (0.9 cc/min), high permeability (1.54 md), a low pressure (2254 psi), and irreducible water saturation. (0.46). Finally, in a natural gas storage operation in an aquifer, both rock properties and operational parameters play important roles, and they should be optimized in order to have the highest amount of stored gas.
https://ijogst.put.ac.ir/article_85257_296d558ddd0b6bd8e22ef56caf5461fa.pdf
2019-01-01
11
31
10.22050/ijogst.2018.119136.1441
Natural gas storage
Simulation
optimization
Stored Gas Volume
Recovered Gas Volume
Arezou
Jafari
ajafari@modares.ac.ir
1
Assistant Professor, Faculty of Chemical Engineering, Tarbiat Modares University, Tehran, Iran.
LEAD_AUTHOR
Peyman
Sadirli
2
MS Graduate Student, Faculty of Chemical Engineering, Tarbiat Modares University, Tehran, Iran.
AUTHOR
Reza
Gharibshahi
3
PhD Candidate, Faculty of Chemical Engineering, Tarbiat Modares University, Tehran, Iran.
AUTHOR
Esmaeel
Kazemi Tooseh
4
MS Graduate Student, Faculty of Chemical Engineering, Tarbiat Modares University, Tehran, Iran.
AUTHOR
Masoud
Samivand
5
Natural Gas Storage Company, Tehran, Iran.
AUTHOR
Ali
Teymouri
6
Natural Gas Storage Company, Tehran, Iran.
AUTHOR
Ahmed, T., Reservoir Engineering Handbook: 3rd Edition, 1376 P. Gulf Professional Publishing, 2006.
1
Aminu, M. D., Nabavi, S. A., Rochelle, C. A., And Manovic, V., A Review of Developments in Carbon Dioxide Storage, Applied Energy, Vol. 208, P. 1389-1419, 2017.
2
Antony, J., Design of Experiments for Engineers and Scientists: 2nd Edition, 220 P. Elsevier, 2014.
3
Azin, R., Nasiri, A., & Entezari, J., Underground Gas Storage in a Partially Depleted Gas Reservoir. Oil & Gas Science and Technology-Revue De L’ifp, Vol. 63, No. 6, p. 691–703, 2008.
4
Bruant, R., Guswa, A., Celia, M., & Peters, C., Safe Storage of CO~ 2 in Deep Saline Aquifers, Environmental Science And Technology, Vol. 36, No. 11, p. 240A–245A, 2002.
5
Coffin, P., & Lebas, G., Converting the Pecorade Oil Field into an Underground Gas Storage. SPE Projects, Facilities & Construction, Vol. 3, No. 1, p. 1–6, 2008.
6
Crochet, M. J., Davies, A. R., & Walters, K., Numerical Simulation Of Non-Newtonian Flow: 366 P. Elsevier Science, 2012.
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Dietert, J. A., & Pursell, D. A., Underground Natural Gas Storage. URL Http://Www.Worldoil. Com/WO_RESEARCH/Research/062800storage. Pdf, 2000.
8
Eghbali, M. H., Nazar, S., Reza, A., & Tavakoli, T., An Experimental Study on the Operational Factors Affecting the Oil Content of Wax During Dewaxing Process: Adopting a DOE Method, Iranian Journal Of Oil & Gas Science And Technology, Vol. 2, No. 1, p. 1–8, 2013.
9
Gharibshahi, R., Jafari, A., Haghtalab, A., & Karambeigi, M. S., Application of CFD to Evaluate Pore Morphology Effect in the Nanofluid Flooding for Enhanced Oil Recovery, RSC Advances, Vol. 5, No. 37, p. 28938–28949, 2015.
10
Gluyas, J., & Mathias, S., Geological Storage of Carbon Dioxide (CO2): Geoscience, Technologies, Environmental Aspects and Legal Frameworks; 1rd Edition, 366 P. Woodhead Publishing Series In Energy (Book 54), 2014.
11
Jafari, A., CFD Simulation Of Complex Phenomena Containing Suspensions And Flow Through Porous Media, Ph.D. Thesis, Lappeenranta University of Technology, Finland, 222 p., 2008.
12
Ji, S.-H., Kim, K.-S., & Koh, Y.-K., Performance Assessment of an Underground Gas Storage Cavern Using Water-Shed Scale Groundwater Flow Modeling with Large Grid Spacing, Engineering Geology, Vol. 222, p. 1–9, 2017.
13
Khashayar, T., Application of Rock-Eval6 in Detection Seepage of Yortshah Gas Storage, World Applied Sciences Journal, Vol. 8, No. 10, p. 1193–1199, 2010.
14
Kumar, A., Noh, M. H., Ozah, R. C., Pope, G. A., Bryant, S. L., Sepehrnoori, K., & Lake, L. W., Reservoir Simulation of CO2 Storage in Aquifers, SPE Journal, Vol. 10, No. 3, p. 336–348, 2005.
15
Kvamme, B., Graue, A., Buanes, T., Kuznetsova, T., & Ersland, G., Storage of CO2 in Natural Gas Hydrate Reservoirs and the Effect of Hydrate as an Extra Sealing in Cold Aquifers, International Journal of Greenhouse Gas Control, Vol. 1, No. 2, p. 236–246, 2007.
16
Lorenz, S., & Müller, W., Modelling of Halite Formation in Natural Gas Storage Aquifers, In Proceedings, TOUGH Symposium 2003, May 12–14, Lawrence Berkeley National Laboratory, Berkeley, California, 2003.
17
Mason, R. L., Gunst, R. F., & Hess, J. L., Statistical Design and Analysis of Experiments: With Applications to Engineering and Science: 2nd Edition, 760 p. John Wiley & Sons, 2003.
18
Michael, K., Golab, A., Shulakova, V., Ennis-King, J., Allinson, G., Sharma, S., & Aiken, T., Geological Storage of CO2 in Saline Aquifers—A Review of the Experience from Existing Storage Operations, International Journal of Greenhouse Gas Control, Vol. 4, No. 4, p. 659–667, 2010.
19
Montgomery, D. C., Design and Analysis of Experiments: 9ed Edition, 752 P. John Wiley & Sons, 2017.
20
Mousavi, S. M., Jafari, A., Chegini, S., & Turunen, I., CFD Simulation of Mass Transfer and Flow Behavior around a Single Particle in Bioleaching Process, Process Biochemistry, Vol. 44, No. 7, p. 696–703, 2009.
21
Muonagor, C. M., & Anyadiegwu, C. I. C., Development and Conversion of Aquifer for Underground Natural Gas Storage in Nigeria, Petroleum & Coal, Vol. 56, No. 1, p. 1–12, 2014.
22
Oh, J., Kim, K.-Y., Han, W. S., Kim, T., Kim, J.-C., & Park, E., Experimental and Numerical Study on Supercritical CO2/Brine Transport in a Fractured Rock: Implications of Mass Transfer, Capillary Pressure and Storage Capacity, Advances in Water Resources, Vol. 62, p. 442–453, 2013.
23
Reidel, S. P., Johnson, V. G., & Spane, F. A., Natural Gas Storage in Basalt Aquifers of the Columbia Basin, 277 P. Pacific Northwest USA: A Guide to Site Characterization, 2002.
24
Shahmorad, Z., Salarirad, H., & Molladavoudi, H., A Study on the Effect of Utilizing Different Constitutive Models in the Stability Analysis of an Underground Gas Storage within a Salt Structure, Journal of Natural Gas Science and Engineering, Vol. 33, p. 808–820, 2016.
25
Soave, G., Equilibrium Constants from a Modified Redlich-Kwong Equation of State. Chemical Engineering Science, Vol. 27, No. 6, p. 1197–1203, 1972.
26
Soroush, M., & Alizadeh, N., Underground Gas Storage in Partially Depleted Gas Reservoir, In Canadian International Petroleum Conference, 12-14 June, Calgary, Alberta, 2007.
27
Tek, M. R., Underground Storage of Natural Gas: Theory and Practice, Vol. 171, 472 p. Springer Science & Business Media, 1989.
28
Thompson, M., Davison, M., & Rasmussen, H., Natural Gas Storage Valuation and Optimization: A Real Options Application, Naval Research Logistics (NRL), Vol. 56, No. 3, p. 226–238, 2009.
29
Van Der Meer, B., Carbon Dioxide Storage in Natural Gas Reservoir, Oil & Gas Science and Technology, Vol. 60, No. 3, p. 527–536, 2005.
30
Wang, Z., & Holditch, S. A., A Correlation Analysis of the Effects of the Primary Reservoir Parameters on Aquifer Gas Storage Performance, In Canadian International Petroleum Conference, 7-9 June, Calgary, Alberta, 2005.
31
Yu, W., & Sepehrnoori, K., Optimization of Multiple Hydraulically Fractured Horizontal Wells in Unconventional Gas Reservoirs, Journal of Petroleum Engineering, Vol. 2013, p. 16, 2013.
32
ORIGINAL_ARTICLE
An Experimental Study of Acid Diversion by Using Gelled Acid Systems Based on Viscoelastic Surfactants: A Case Study on One of Iran Southwest Oilfields
In matrix acidizing operations, the main goal is increasing permeability. For production engineers, it is desirable that acid could be injected into whole [M.N.1] [amehri.gh2] pay zone. Sometimes, this pay zone has a long height and various sub-layers which have different permeability values. To prevent acid from going completely into the most permeable sub-layer, one of the useful techniques is using diverters, and one of the major groups of diverters is gel diverters. Diverter viscosity changes by temperature and pH, and an increase in viscosity leads to a decrease in its permeability; thus, acid can permeate further through less permeable sub-layers. In this study, two kinds of different viscoelastic surfactants (VES) provided by two different companies were used to produce gel to divert acid into a core plug sample having lower permeability in a dual parallel acid injection set-up. The core plug samples were taken from the pay zone of Ahwaz oilfield, one of Iran southwest oilfields. Before performing the injection test, some viscosity measurement tests were carried out. Unfortunately, one of these two VES’s did not have an acceptable quality and failed to pass the injection tests. However, the other one passed all the tests successfully and diverted the injection fluid. The water permeability values of the low-perm and high-perm core plug samples were 0.91 md and 6.4 md respectively, whereas, after injection, they rose to 1.5 and 18.5 md respectively.
https://ijogst.put.ac.ir/article_85258_65b707d5221b820c15c21f4aff7b3ab8.pdf
2019-01-01
32
46
10.22050/ijogst.2018.139168.1464
Carbonate Acidizing
Multi-layered Reservoirs
Diverters
Gels
Viscoelastic Surfactants
Abdorrahman
Mehri Ghahfarrokhi
amehri.ghahfarrokhi@gmail.com
1
Technical Expert, Iranian Offshore Oil Company, Tehran, Iran
LEAD_AUTHOR
Ezzatollah
Kazemzadeh
kazemzadehe@ripi.ir
2
Assistant Professor, Research Institute of Petroleum Industries (RIPI), Tehran, Iran
AUTHOR
Hassan
Shokrollahzadeh Behbahani
shokrollahzadeh@put.ac.ir
3
Assistant Professor, Department of Petroleum Engineering, Petroleum University of Technology, Ahwaz, Iran
AUTHOR
Gholam Abbas
Safian
safian.g@nisoc.ir
4
Senior Technical Expert, National Iranian South Oil Company, Ahwaz, Iran
AUTHOR
Ahmed, W. A. F., Nasr-El-Din, H. A., Moawad, T. M., and Elgibaly, A., Effects of Crosslinker Type and Additives on the Performance on in Situ Gelled Acids, SPE International Symposium and Exhibition on Formation Damage Control, Society of Petroleum Engineers, 2008.
1
Al-Sadat, W., Nasser, M., Chang, F., Nasr-El-Din, H., and Hussein, I., Rheology of a Viscoelastic Zwitterionic Surfactant Used in Acid Stimulation: Effects of Surfactant and Electrolyte Concentration, Journal of Petroleum Science and Engineering, Vol. 124, p. 341-349, 2014.
2
Bradley, H. B. Petroleum Engineering Handbook, Society of Petroleum Engineers, USA, 1987
3
Carpenter, C., Self-Diverting Acid for Effective Carbonate Stimulation Offshore Brazil, Journal of Petroleum Technology, Vol. 66, No. 06, p. 92-95, 2014.
4
Chang, F., Qu, Q. and Frenier, W., A Novel Self-diverting-acid Developed for Matrix Stimulation of Carbonate Reservoirs, SPE International Symposium on Oilfield Chemistry, Society of Petroleum Engineers, 2001.
5
Farajzadeh, R., Andrianov, A., Bruining, J. and Zitha, P. L. J., New Insights into Application of Foam for Acid Diversion, 8th European Formation Damage Conference, Society of Petroleum Engineers, 2009.
6
Gomaa, A. M. and Nasr-El-Din, H. A., New Insights into the Viscosity of Polymer-based in- Situ-Gelled Acids, SPE Production & Operations, Vol. 25, No.3, p. 367-375, 2010.
7
Gomaa, A. M. and Nasr-El-Din, H. A., Propagation of Regular HCl Acids in Carbonate Rocks: The Impact of an in Situ Gelled Acid Stage, Journal of Energy Resources Technology, Vol. 133, No.2, p. 023101, 2011.
8
Hull, K. L., Sayed, M. and Al-Muntasheri, G. A., Recent Advances in Viscoelastic Surfactants for Improved Production from Hydrocarbon Reservoirs, SPE International Symposium on Oilfield Chemistry, Society of Petroleum Engineers, 2015.
9
Kalfayan, L., Production Enhancement with Acid Stimulation, Pennwell Books, South Sheridan Road, Tulsa, Oklahoma, USA, 2008.
10
Magee, J., Buijse, M. And Pongratz, R., Method for Effective Fluid Diversion When Performing A Matrix Acid Stimulation in Carbonate Formations, Middle East Oil Show and Conference, Society of Petroleum Engineers, 1997.
11
McLeod, H. O., Matrix acidizing, Journal of Petroleum Technology, Vol. 36, No. 12, p. 2055-2069, 1984.
12
Miniawi, M. A., Ahmed, W. A. F., Ali, Y., and Soufi, A. R., in Situ Gelled Acid as A Diverting System in Water Injection Well, SPE/IADC Middle East Drilling and Technology Conference, Society of Petroleum Engineers, 2007.
13
Mumallah, N., Factors Influencing the Reaction Rate of Hydrochloric Acid and Carbonate Rock, SPE International Symposium on Oilfield Chemistry, Society of Petroleum Engineers, 1991.
14
Nasr-El-Din, H. A., Chesson, J. B., Cawiezel, K. E. and De Vine, C. S., Field Success in Carbonate Acid Diversion, Utilizing Laboratory Data Generated by Parallel Flow Testing, SPE Annual Technical Conference and Exhibition, Society of Petroleum Engineers, 2006.
15
Norman, L. R., Conway, M. W. And Wilson, J. M., Temperature-Stable Acid-gelling Polymers: Laboratory Evaluation and Field Results, Journal of Petroleum Technology, Vol. 36, p. 2011-2018, 1984.
16
Shu, Y., Wang, G., Nasr-El-Din, H. A. and Zhou, J., Interactions of Fe (III) and Viscoelastic- Surfactant-based Acids, SPE Production & Operations, 2015.
17
Smith, C. L., Anderson, J. L. and Roberts, P., New Diverting Techniques for Acidizing and Fracturing, SPE California Regional Meeting, Society of Petroleum Engineers, 1969.
18
Van Zanten, R., Stabilizing Viscoelastic Surfactants in High-Density Brines, SPE Drilling & Completion, Vol. 26, p. 499-505, 2011.
19
White, G., The Use of Temporary Blocking Agents in Fracturing and Acidizing Operations, Drilling and Production Practice, American Petroleum Institute, 1958.
20
ORIGINAL_ARTICLE
Optimization and Modeling of CuOx/OMWNT’s for Catalytic Reduction of Nitrogen Oxides by Response Surface Methodology
A series of copper oxide (CuOx) catalysts supported by oxidized multi-walled carbon nanotubes (OMWNT’s) were prepared by the wet impregnation method for the low temperature (200 °C) selective catalytic reduction of nitrogen oxides (NOx) using NH3 as a reductant agent in the presence of excess oxygen. These catalysts were characterized by FTIR, XRD, SEM-EDS, and H2-TPR methods. The response surface methodology was employed to model and optimize the effective parameters in the preparation of CuOx/OMWNT’s catalysts in NOx removal by NH3-SCR process. Three experimental parameters, including calcination temperature, calcination time, and CuOx loading were chosen as the independent variables. The central composite design was utilized to establish a quadratic model as a functional relationship between the conversion of NOx as a response factor and independent variables. The ANOVA results showed that the NOx conversion is significantly affected by calcination temperature and CuOx loading. At the optimal values of the studied parameters, the maximum conversion of NOx, 86.3 %, was obtained at a calcination temperature of 318 °C, a calcination time of 3.4 hr., and CuOx loading of 16.73 wt.%; the reaction conditions was as follows: T= 200 °C, P= 1 bar, NO = NH3 = 900 ppm, O2 = 5 vol.%, and GHSV = 30,000 hr.−1. The regression analysis with an R2value of 0.9908 revealed a satisfactory correlation between the experimental data and the values predicted for the conversion of NOx. The XRD and H2-TPR results of the best catalyst showed that the formation of CuO as the dominant phase of CuOx is the key factor in low temperature selective catalytic reduction (SCR) process.
https://ijogst.put.ac.ir/article_55728_9aef0bc2f8a2d2cdebbf0085d26beb77.pdf
2019-01-01
47
59
10.22050/ijogst.2017.108360.1424
CuOx/OMWNT’s
Selective Catalytic Reduction
Nitrogen Oxides
Response Surface Methodology
optimization
Mahnaz
Pourkhalil
pourkhalilm@ripi.ir
1
Assistance Professor, Nanotechnology Research Center, Research Institute of the Petroleum Industry, Tehran, Iran
LEAD_AUTHOR
Amin, F. and Solaimany Nazar A. R., Assessing the Asphaltene Adsorption on Metal Oxide Nanoparticles, Iranian Journal of Oil & Gas Science and Technology, Vol. 5, p. 62-72, 2016.
1
Badday, A. S., Abdullah A. Z. , and Lee K. T., Optimization of Biodiesel Production Process from Jatropha Oil Using Supported Heteropolyacid Catalyst and Assisted by Ultrasonic Energy, Renewable Energy, Vol. 50, p.427-432, 2013.
2
Barreau, M., M. L. Tarot, D. Duprez, X. Courtois & F. Can, Remarkable Enhancement of the Selective Catalytic Reduction of NO at Low Temperature by Collaborative Effect of Ethanol and NH3 Over Silver Supported Catalyst, Applied Catalysis B: Environmental, Vol. 220, p.19-30, 2018.
3
Bazarganipour, M. & M. Salavati-Niasari, Synthesis, Characterization and Chemical Binding of A Ni(II) Schiff Base Complex on Functionalized MWNT's; Catalytic Oxidation of Cyclohexene with Molecular Oxygen. Chemical Engineering Journal, Vol.286, p.259-265, 2016.
4
Belin, T. & F. Epron, Characterization Methods of Carbon Nanotubes: A Review, Materials Science and Engineering: B, Vol.119, p.105-118, 2005.
5
Chuang, K.-H., C.-Y. Lu, M.-Y. Wey & Y.-N. Huang, NO Removal by Activated Carbon-supported Copper Catalysts Prepared by Impregnation, Polyol, and Microwave Heated Polyol Processes, Applied Catalysis A: General, Vol.397, p.234-240, 2011.
6
Danmaliki, G. I., T. A. Saleh & A. A. Shamsuddeen, Response Surface Methodology Optimization of Adsorptive Desulfurization on Nickel/Activated Carbon, Chemical Engineering Journal, Vol.313, p.993-1003, 2017.
7
Fang, D., F. He, X. Liu, K. Qi, J. Xie, F. Li & C. Yu, Low Temperature NH3-SCR Of NO Over an Unexpected Mn-based Catalyst: Promotional Effect of Mg Doping, Applied Surface Science, Vol.427, p.45-55, 2018.
8
Gangupomu, R. H., M. L. Sattler & D. Ramirez, Comparative Study of Carbon Nanotubes and Granular Activated Carbon: Physicochemical Properties and Adsorption Capacities, Journal of Hazardous Materials, Vol.302, p.362-374, 2016.
9
Hosseini, S. A., S. Nouri, S. Hashemi & M. Akbari, Investigation of Performance of Ni / Clinoptilolite Nanoadsorbents in Desulfurization of Gas Oil: Experimental Design and Modeling, Iranian Journal of Oil & Gas Science and Technology, Vol.6, p.13-25, 2017.
10
Jiang, L. & L. Gao, Modified Carbon Nanotubes: an Effective Way to Selective Attachment of Gold Nanoparticles, Carbon, Vol.41, p.2923-2929, 2003.
11
Jung, H., E. Park, M. Kim & J. Jurng, A Pilot-scale Evaluation of A Novel Tio2-supported V2O5 Catalyst for Denox at Low Temperatures at A Waste Incinerator, Waste Management, Vol.61, p.283-287 , 2017.
12
Jung, Y., Y. J. Shin, Y. D. Pyo, C. P. Cho, J. Jang & G. Kim, NOx and N2O Emissions over A Urea-SCR System Containing both V2O5-WO3/Tio2 and Cu-Zeolite Catalysts in A Diesel Engine, Chemical Engineering Journal, Vol.326, p.853-862, 2017.
13
Kibria, A. K. M. F., M. Shajahan, Y. H. Mo, M. J. Kim & K. S., Nahm, Long Activity of Co–Mo/MgO Catalyst for The Synthesis of Carbon Nanotubes in Large-scale and Application Feasibility of The Grown Tubes, Diamond and Related Materials, Vol.13,p.1865-1872, 2004.
14
Kumar, S. & R. K. Singh, Optimization of Process Parameters by Response Surface Methodology (RSM) for Catalytic Pyrolysis of Waste High-density Polyethylene to Liquid Fuel, Journal of Environmental Chemical Engineering, Vol.2, p.115-122, 2014.
15
Li, Q., H. Yang, Z. Ma & X. Zhang, Selective Catalytic Reduction of NO with NH3 over CuOx-Carbonaceous Materials, Catalysis Communications, Vol.17, p.8-12, 2012.
16
Liu, M., Y. Yang, T. Zhu & Z. Liu, Chemical Modification of Single-walled Carbon Nanotubes with Peroxytrifluoroacetic Acid. Carbon, Vol.43, p.1470-1478, 2005.
17
Liu, X., X. Wu, D. Weng & L. Shi, Modification of Cu/ZSM-5 Catalyst with Ceo2 for Selective Catalytic Reduction of NOx with Ammonia, Journal of Rare Earths, Vol.34, p.1004-1009, 2016.
18
Luo, J., F. Gao, K. Kamasamudram, N. Currier, C. H. F. Peden & A. Yezerets, New Insights into Cu/SSZ-13 SCR Catalyst Acidity, Part I: Nature of Acidic Sites Probed by NH3 Titration, Journal Of Catalysis, Vol.348, p.291-299, 2017.
19
Lv, J., D. Li, K. Dai, C. Liang, D. Jiang, L. Lu & G. Zhu, Multi-walled Carbon Nanotube Supported Cd's-DETA Nanocomposite for Efficient Visible Light Photocatalysis, Materials Chemistry and Physics, Vol.186, p.372-381, 2017.
20
Pourkhalil, M., N. Izadi, A. Rashidi & M. Mohammad-Taheri, Synthesis of CeOx/Γ-Al2O3 Catalyst for the NH3-SCR of NOx. Materials Research Bulletin, Vol.97, p.1-5, 2018
21
Pourkhalil, M., A. Z. Moghaddam, A. Rashidi, J. Towfighi & Y. Mortazavi, Preparation of Highly Active Manganese Oxides Supported on Functionalized MWNT's for Low Temperature NOx Reduction with NH3, Applied Surface Science, Vol.279, p.250-259, 2013.
22
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23
Sakkas, V. A., M. A. Islam, C. Stalikas & T. A. Albanis, Photocatalytic Degradation Using Design Of Experiments: A Review and Example of The Congo Red Degradation, Journal of Hazardous Materials, Vol.175, p.33-44, 2010.
24
Samojeden, B., M. Motak & T. Grzybek, The Influence of the Modification of Carbonaceous Materials on their Catalytic Properties in SCR-NH3: A Short Review, Comptes Rendus Chimie, Vol.18, P.1049-1073, 2015.
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Sedaghatzadeh, M., A. Khodadadi & M. R. Tahmasebi Birgani, an Improvement in Thermal and Rheological Properties of Water-based Drilling Fluids Using Multiwall Carbon Nanotube (MWCNT), Iranian Journal of Oil & Gas Science and Technology, Vol.1, P.55-65, 2012.
26
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36
ORIGINAL_ARTICLE
Viscosity Reduction of Heavy Crude Oil by Dilution Methods: New Correlations for the Prediction of the Kinematic Viscosity of Blends
Dilution is one of the various existing methods in reducing heavy crude oil viscosity. In this method, heavy crude oil is mixed with a solvent or lighter oil in order to achieve a certain viscosity. Thus, precise mixing rules are needed to estimate the viscosity of blend. In this work, new empirical models are developed for the calculation of the kinematic viscosity of crude oil and diluent blends. Genetic algorithm (GA) is utilized to determine the parameters of the proposed models. 850 data points on the viscosity of blends (i.e. 717 weight fraction-based data and 133 volume fraction-based data) were obtained from the literature. The prediction result for the volume fraction-based model in terms of the absolute average relative deviation (AARD (%)) was 8.73. The AARD values of the binary and ternary blends of the weight fraction-based model (AARD %) were 7.30 and 10.15 respectively. The proposed correlations were compared with other available correlations in the literature such as Koval, Chevron, Parkash, Maxwell, Wallace and Henry, and Cragoe. The comparison results confirm the better prediction accuracy of the newly proposed correlations.
https://ijogst.put.ac.ir/article_55719_47d1c328365b2d960c0e21ccafe21eaf.pdf
2019-01-01
60
77
10.22050/ijogst.2018.97887.1405
Heavy crude oil
Kinematic viscosity
blending
Genetic Algorithm
Binary blend
Saeed
Mohammadi
smgh1991@gmail.com
1
M.S. Student, School of Chemical Engineering, Iran University of Science and Technology, Tehran, Iran
AUTHOR
Mohammad Amin
Sobati
sobati@iust.ac.ir
2
Assistant Professor, School of Chemical Engineering, Iran University of Science and Technology, Tehran, Iran
LEAD_AUTHOR
Mohammad
Sadeghi
sadeghi@iust.ac.ir
3
Associate Professor, School of Chemical Engineering, Iran University of Science and Technology, Tehran, Iran
AUTHOR
Aburto, J., Mar-Juarez, E., & Juarez-Soto, C., Transportation of Heavy and Extra-Heavy Crude Oil by Pipeline: A Patent Review for Technological Options, Recent Patents on Chemical Engineering, Vol2, No.2, p.86-97,2009.
1
AHMED, A., Rheological Changes in Crude Oil Diluted with Alcohols. Journal of Petroleum Science and Engineering, Vol75, p.274-282,2013.
2
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3
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6
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7
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12
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13
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Miadonye, A., Latour, N., & Puttagunta, V., A Correlation for Viscosity and Solvent Mass Fraction of Bitumen-Diluent Mixtures. Petroleum Science and Technology, Vol.18, No.1-2, p.1-14, 2000.
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39
ORIGINAL_ARTICLE
CFD Simulation of Parameters Affecting Hydrodynamics of Packed Beds: Effects of Particle Shape, Bed Size, and Bed Length
Packed bed reactors have many applications in different industries such as chemical, petrochemical, and refinery industries. In this work, the effects of some parameters such as the shape and size of particles, bed size, and bed length on the hydrodynamics of the packed beds containing three spherical, cylindrical, and cubic particles types are investigated using CFD. The effect of the combination of three particles types in a packed bed was also simulated. The simulation results show that flow channeling occurs in some parts of the bed which are not suitably covered by particles. It was also seen that flow channeling in the packed bed with cubic particles are more than those containing spherical and cylindrical particles. According to the CFD simulations, wake and vortex flows are created in all the beds, and the shape of particles affects these phenomena. The comparison of the pressure drop created in the packed beds indicates that the pressure drop in the packed beds having three particle types is lower than the packed beds containing only spherical, cylindrical, or cubic particles. Finally, the numerical results were compared with empirical correlations in the literature and showed good agreement.
https://ijogst.put.ac.ir/article_55726_a775ec2b2bddcf71bbcffff722ce9b72.pdf
2019-01-01
78
102
10.22050/ijogst.2018.104379.1418
Bed size
Flow Pattern
Combination of particles
Packing shape
Stationary points
Saeid
Mohammadmahdi
saeidmohammadmahdi@yahoo.com
1
M.S. Student, Department of Chemical Engineering, University of Mohaghegh Ardabili, Ardabil, Iran
AUTHOR
Ali Reza
Miroliaei
armiroliaei@uma.ac.ir
2
Assistant Professor, Department of Chemical Engineering, University of Mohaghegh Ardabili, Ardabil, Iran
LEAD_AUTHOR
Allen, K. G., von Backstrom, T. W., and Kroger, D. G., Packed Bed Pressure Drop Dependence on Particle Shape, Size Distribution, Packing Arrangement and Roughness, Powder Technology, Vol. 246, p. 590-600, 2013.
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5
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6
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21