Iranian Gas Institute
Journal of Gas Technology
2588-5596
3
1
2018
06
01
Prediction of H2S and CO2 Solubility in Aqueous MDEA and MDEA/PZ Solutions Using ELECNRTL and ACID GAS Packages
4
13
EN
Omid
Sabbagh
0000-0002-1719-242X
Department of Chemical Engineering
Ferdowsi, University of Mashhad, Mashhad, Iran
omidsabbagh@yahoo.com
Maysam
Vahidi Ferdowsi
Department of Chemical Engineering, Ferdowsi University of Mashhad, Iran
Mohammad Ali
Fanaei
0000-0001-5535-8657
Department of Chemical Engineering, Ferdowsi University of Mashhad, Iran
fanaei@um.ac.ir
In this study, the solubility of acid gases of hydrogen sulfide and carbon dioxide in MDEA and MDEA/PZ aqueous solutions was evaluated by different thermodynamic packages. Comparison of modeling results with a series of laboratory and industrial data released from 1997 to 2010 indicates the high accuracy of ACID GAS thermodynamic package (Aspen HYSYS 8.3) to prediction of acid gases solubility in the mentioned solutions compared to the ELECNRTL thermodynamic package (Aspen plus V8.2), especially in the range of acid gases operational concentration in the gas refineries.
MDEA,Pz,Thermodynamic package,Acid gas solubility,Acid gas,ELECNRTL
https://www.jgt.irangi.org/article_251616.html
https://www.jgt.irangi.org/article_251616_e241cf593a30a9eed9b7e31270fee70b.pdf
Iranian Gas Institute
Journal of Gas Technology
2588-5596
3
1
2018
06
01
Investigation on Solubility of Hydrogen Sulfide in Molten Sulfur Using Iodometric Back Titration Method
14
20
EN
Faezeh
tari
Chemical, Polymeric and Petrochemical Technology Research Division, Faculty of Research and Development in Downstream Petroleum Industry, Research Institute of Petroleum Industry (RIPI), P.O. Box 1485733111, Tehran, Iran
fa.tari64@gmail.com
Marzieh
Shekarriz
Chemical, Polymeric and Petrochemical Technology Research Division, Faculty of Research and Development in Downstream Petroleum Industry, Research Institute of Petroleum Industry (RIPI), P.O. Box 1485733111, Tehran, Iran
shekarriz@ripi.ir
Saeed
Zarrinpashne
Gas Technology Research Division, Research Institute of Petroleum Industry (RIPI), P.O. Box 146651998, Tehran, Iran
Ahmad
Ruzbehani
Gas Technology Research Division, Research Institute of Petroleum Industry (RIPI), P.O. Box 146651998, Tehran, Iran
ruzbehania@ripi.ir
In order to conduct laboratory studies on composition and behavior of Claus-derived molten sulfur, the examined sulfur should contain dissolved H<sub>2</sub>S and H<sub>2</sub>S<sub>x</sub> with a concentration of about 230-250ppmw. Here, by injecting hydrogen sulfide to sulfur, a method for synthesis of molten sulfur containing hydrogen sulfide and polysulfide as a proper sample for laboratory studies is developed. The molten sulfur product was prepared by injecting the pressurized hydrogen sulfide on the surface of solid sulfur followed by further heat treatments during the time. According to the Iodometric Back Titration (IBT) analysis, final molten sulfur contained 500-1100ppmw of soluble hydrogen sulfide and polysulfide components based on the initial gas pressure.
Molten sulfur,Gassing,Degassing,Iodometric Back Titration
https://www.jgt.irangi.org/article_251617.html
https://www.jgt.irangi.org/article_251617_85b380a57167f320e3df174cee623a61.pdf
Iranian Gas Institute
Journal of Gas Technology
2588-5596
3
1
2018
06
01
Analysis of Counter-Current Imbibition Including Gravity Force through Finite Difference Scheme
21
26
EN
Mojgan
Ebrahiminejadhasanabadi
Department of Chemical Engineering, Isfahan University of Technology, Isfahan, Iran
mojgan.ebrahiminejad@gmail.com
Mohammad Reza
Ehsani
Department of Chemical Engineering, Isfahan University of Technology, Isfahan, Iran
ehsanimr@cc.iut.ac.ir
Mahnaz
Tayari
School of Chemical Engineering, University of Tehran, Tehran, Iran
m_tayari@alumni.ut.ac.ir
Mohammad
Nikukar
Enhanced oil recovery Institute NIOC, Tehran, Iran
Spontaneous counter-current imbibition is one of the most important crude oil recovery processes in water-wet fractured reservoirs with low matrix permeability. This paper presents a numerical modeling of imbibition process when water is imbibed by capillarity and gravity forces in to an oil saturated vertical cube core to examine the effect of gravity force on spontaneous imbibition. In this modeling, It is assumed that imbibition is a diffusion process. Finite difference implicit method was used to solve the spontaneous imbibition equations. Accuracy of the modeling is investigated with comparison of the modeling results and the experimental data.
Spontaneous imbibition,Counter-current imbibition,Oil recovery,gravity force
https://www.jgt.irangi.org/article_251621.html
https://www.jgt.irangi.org/article_251621_267d4ec7307a23d5c3935894d81c9a7c.pdf
Iranian Gas Institute
Journal of Gas Technology
2588-5596
3
1
2018
06
01
Impact of Compressor Performance on the Flow Capacity of Gas Transmission Pipelines
27
38
EN
Seyed Mohammad
Fatemi
Petroleum Department, National Iranian South Oilfield company, Ahvaz, Iran
Morteza
Esfandyari
Petroleum Department, National Iranian South Oilfield company, Ahvaz, Iran
m.esfandyari@ub.ac.ir
Mahdi
Koolivand Salooki
Gas Research Division, Research Institute of Petroleum Industry, Tehran, Iran
Flow capacity of a gas transmission pipeline is usually affected by different parameters. In this study several determining factor are selected for sensitivity analysis of flow capacity prediction in IGAT-IV. These parameters include; pipeline parameters, gas parameters, system parameters, heat transfer parameters, compression parameters and compressor fuel consumption parameters. Detail calculation has been performed by developing a computer program by Microsoft Visual Basic. Moreover, a computer program for generating the compressor performance curve has been written by MATLAB. This curve has been used to design and optimize the compressor stations. From the present investigation, it has concluded that AGA Fully Turbulent, Colebrook-White and Weymouth equations have the best prediction of flow rate in gas transmission pipelines. 87.85 % flow changes due to 1% isentropic exponent change, which has a very large effect on the flow capacity. 10% to 30% flow changes due to 1% suction compressibility factor and discharge compressibility factor change. They have large effect on the flow capacity. 1% to 10% flow changes due to 1% compressor horsepower, compressor suction and discharge temperature and adiabatic efficiency change. They have medium effect on the flow capacity. The other parameters have not significant effect on the flow capacity.
Gas Transmission Pipeline,Flow Capacity,Compression parameters,Compressor Fuel Consumption Parameters
https://www.jgt.irangi.org/article_251622.html
https://www.jgt.irangi.org/article_251622_762eca9ccdc5f2e1c5690c88e84284c2.pdf
Iranian Gas Institute
Journal of Gas Technology
2588-5596
3
1
2018
06
01
Pressure Drop in Randomly Packed Absorption Tower in Transient Flow Regime
38
47
EN
Seyedeh Gita
Sharafi
Department of Chemical Engineering University of Sistan and Baluchestan, Zahedan, Iran
sharafi.gita@gmail.com
Rahbar
Rahimi
0000-0002-0133-4980
Department of Chemical Engineering University of Sistan and Baluchestan, Zahedan, Iran
rahimi@hamoon.usb.ac.ir
Mortaza
Zivdar
0000-0003-2853-8286
Corresponding Author: Chem. Eng. Dept., Faculty of Eng, University of Sistan and Baluchestan, Zahedan, Iran
mzivdar@eng.usb.ac.ir
In this work computational fluid dynamics is used to describe the fluid flow across a randomly packed absorption tower. The CFD simulation method is employed on a packed tower that is packed with 1cm Raschig rings. Tower is 175cm in height. Air flow rate range was 1.5 to 5 m/s. The measured pressure drops were in 1.5 to 12 Pascal per height of tower in meter. The Klerk’s approach is examined to define the influence of confining walls on pressure drop in packed areas. It is concluded that CFD model that uses the Klerk’s definition of radial porosity distribution is a successful way for pressure drop prediction in packed beds. Model prediction of dry pressure drop is about 4% lower than the experimental measurements. Ergun’s pressure drop prediction is compared with that of Reichelt’s using averaged and distributed porosity profiles. In both methods Ergun’s approach in comparison with Reichelt’s approach has %6 lesser error in dry pressure drop prediction.
Pressure drop,absorption packed tower,random packing,Computational fluid dynamics
https://www.jgt.irangi.org/article_251623.html
https://www.jgt.irangi.org/article_251623_1ee5bdf1086d3b8376332a9f6714a864.pdf
Iranian Gas Institute
Journal of Gas Technology
2588-5596
3
1
2018
06
01
Effect of Coating Method and Feed Pressure and Temperature on CO2/CH4 Gas Separation Performance of Pebax/PES Composite Membranes
48
59
EN
Hamid Reza
Afshouna
Chemical Engineering Department, Faculty of Engineering, Ferdowsi University of Mashhad, Mashhad, Iran
afshoun@gmail.com
Mahdi
Pourafshari Chenar
Chemical Engineering Department, Faculty of Engineering, Ferdowsi University of Mashhad, Mashhad, Iran
pourafshari@um.ac.ir
Ahmad
Fauzi Ismail
Advanced Membrane Technology Research Centre (AMTEC), University Technology Malaysia, Malaysia
In this study, PES/Pebax composite membranes were prepared by coating the porous PES support layers by Pebax-1657. Film casting and pouring methods were used for coating Pebax layer. The effects of coating technique and conditions including coating solution concentration and curing temperature on CO<sub>2</sub> and CH<sub>4</sub> gas permeabilities of prepared composite membranes were investigated. SEM images were used to investigate the structure of the prepared membranes. Pure CH<sub>4</sub> and CO<sub>2</sub> gases were used to investigate the gas permeation properties of the prepared membranes at different trans-membrane pressures (1-11 bar) and feed temperatures (25-55°C). The obtained data showed that the prepared PES supports did not provide any CO<sub>2</sub>/CH<sub>4</sub> selectivity. The results also showed the CO<sub>2</sub>/CH<sub>4</sub> selectivity for the membrane prepared via pouring technique was higher than that of the film casting procedure due to the defect-free Pebax layer formation. CO<sub>2</sub> and CH<sub>4</sub> permeance increased as the feed temperature increased from 25 to 55°C. The results also showed that CO<sub>2</sub> permeance increased from 6.8 to 10.1GPU with an increase in feed pressure from 2 to 12barg, while CH<sub>4</sub> permeance remained almost constant and CO<sub>2</sub>/CH<sub>4</sub> selectivity increased from 27 to 42.
Pebax,Composite membrane,CO2 separation,Coating method,Feed pressure,Temperature
https://www.jgt.irangi.org/article_251624.html
https://www.jgt.irangi.org/article_251624_1437d2fede33e1ce6842610fcd276880.pdf