Petroleum University of Technology
Iranian Journal of Oil and Gas Science and Technology
2345-2412
2345-2420
8
4
2019
10
01
Chemometrics-enhanced Classification of Source Rock Samples Using their Bulk Geochemical Data: Southern Persian Gulf Basin
1
17
EN
Majid
Alipour
0000-0002-3759-993X
Assistant Professor, Department of Geology, Faculty of Earth Sciences, Shahid Chamran University of Ahvaz, Iran
alipour.magid@gmail.com
Bahram
Alizadeh
Professor, Petroleum Geology and Geochemistry Research Center (PGGRC), SCU, Ahvaz, Iran
bahramalizadeh@gmail.com
Scott
Ramos
Professor, Infometrix, Inc. 11807 North Creek Parkway South, Suite B-111, Bothell, WA 98011
scott_ramos@infometrix.com
Behzad
Khani
Ph.D., Research Institute of Petroleum Industry (RIPI), Tehran, Iran
behkhani@gmail.com
Shohreh
Mirzaie
Ph.D., Pars Petro Zagros Engineering & Services Co. (PPZ), Tehran, Iran
shohrehmirzaie@yahoo.com
10.22050/ijogst.2019.142950.1469
Chemometric methods can enhance geochemical interpretations, especially when working with large datasets. With this aim, exploratory hierarchical cluster analysis (HCA) and principal component analysis (PCA) methods are used herein to study the bulk pyrolysis parameters of 534 samples from the Persian Gulf basin. These methods are powerful techniques for identifying the patterns of variations in multivariate datasets and reducing their dimensionality. By adopting a “divide-and-conquer” approach, the existing dataset could be separated into sample groupings at family and subfamily levels. The geochemical characteristics of each category were defined based on loadings and scores plots. This procedure greatly assisted the identification of key source rock levels in the stratigraphic column of the study area and highlighted the future research needs for source rock analysis in the Persian Gulf basin.
Chemometric Classification,Source Rock Geochemistry,Rock-Eval Pyrolysis Data,HCA,PCA
https://ijogst.put.ac.ir/article_100882.html
https://ijogst.put.ac.ir/article_100882_849d09c3f26848b7ac00be89ee511fde.pdf
Petroleum University of Technology
Iranian Journal of Oil and Gas Science and Technology
2345-2412
2345-2420
8
4
2019
10
01
Foam Application in Fractured Carbonate Reservoirs: A Simulation Study
18
34
EN
Ahmed
Zoeir
M.S. Student, Faculty of Petroleum and Natural Gas Engineering, Sahand University of Technology, Tabriz, Iran
ah_zoeir@sut.ac.ir
Mohammad
Chahardowli
Assistant Professor, Faculty of Petroleum and Natural Gas Engineering, Sahand University of Technology, Tabriz, Iran
chahardowli@sut.ac.ir
Mohammad
Simjoo
Assistant Professor, Faculty of Petroleum and Natural Gas Engineering, Sahand University of Technology, Tabriz, Iran
simjoo@sut.ac.ir
10.22050/ijogst.2019.147229.1476
Fractured carbonate reservoirs account for 25% of world’s total oil resources and for 90% of Iranian oil reserves. Since calcite and dolomite minerals are oil wet, gas oil gravity drainage (GOGD) is known as the most influencing production mechanism. The most important issue within gas injection into fractured media is the channeling problem which makes the efficiency of gas injection process extremely low. As a solution, foam is used to change the mobility ratio, to increase volumetric sweep efficiency, and to overcome the fingering problem. In this work, we inspected three main influencing mechanisms that affect oil extraction from matrix, namely foam/oil gravity drainage, viscous pressure drop due to foam flow in fractures, and foaming agent diffusion from fractures into the matrixes. Foam injection simulations were performed using CMG STARS 2015, on a single matrix unit model and on some vertical cross section models. A number of sensitivity analyses were performed on foam strength, injection rate, fracture and matrix properties, matrix heights, and the initial oil saturation within matrixes. The results show that the roles of the mass transfer of the foaming agent and viscous pressure drop are significant, especially when matrix average heights are small. Moreover, the mechanism for viscous pressure drop remains unchanged, which continues to aid oil extraction from matrixes while the other two mechanisms weaken with time.
Foam,Fractured Reservoir,Gravity Drainage,Gas Invaded Zone,CMG STARS
https://ijogst.put.ac.ir/article_100881.html
https://ijogst.put.ac.ir/article_100881_d4743852fce50ab3f1fd097d537d34b8.pdf
Petroleum University of Technology
Iranian Journal of Oil and Gas Science and Technology
2345-2412
2345-2420
8
4
2019
10
01
Chemical Modification of Lignite and Investigation of its Properties in Controlling Fluid Loss of Oil Well Cement Slurries
35
49
EN
Ali
Nemati Kharat
Professor, School of Chemistry, University College of Science, University of Tehran, Tehran, Iran
alnema@khayam.ut.ac.ir
Ali akbar
Ghaffari
M.S. Student, School of Chemistry, University College of Science, University of Tehran, Tehran, Iran
aliakbar.ghaffari@ut.ac.ir
10.22050/ijogst.2019.128036.1457
The aim of this research was to produce a convenient additive for enhancing the properties, especially the fluid loss, of oil well cement slurries. In this regard, a variety of drilling/cementing chemical additives known as fluid loss controllers were prepared through derivatization and chemical modification of lignite. Lignite-based graft copolymers were synthesized using different groups of acrylic monomers via aqueous the free radical polymerization method. Then, it was allowed to react with sulfomethylating agents to enhance its water solubility. Subsequently, a comparative sulfomethylated lignite was prepared and employed as the backbone in the free radical polymerization. ATR-FTIR and elemental analyses were performed to demonstrate the structures of the fluid loss controller and incorporated elements. The performance of these additives in improving the properties of oil well cement slurries was investigated through analyzing the quality of fluid loss controller in saline saturated slurries. Under similar desired well conditions, i.e. a compressive strength of 800-1100 psi, a thickening time of 400 minutes, and a viscosity of 25 cP, a fluid loss below 130 ml API was obtained. The best standard performance was assigned to the cement slurry which employed sulfomethylated lignite graft copolymer.
Lignite,Sulfomethylation,Graft Copolymers,cement slurry,Fluid Loss Controller
https://ijogst.put.ac.ir/article_100883.html
https://ijogst.put.ac.ir/article_100883_c0f551862d19ccdb54c1be8aa549fe0e.pdf
Petroleum University of Technology
Iranian Journal of Oil and Gas Science and Technology
2345-2412
2345-2420
8
4
2019
10
01
Salinity Effect on the Surfactant Critical Micelle Concentration through Surface Tension Measurement
50
63
EN
Naser
Akhlaghi
Ph.D. Candidate, Department of Petroleum Engineering, Kish International Campus, University of Tehran, Kish, Iran
naserakhlaghi@yahoo.com
Siavash
Riahi
Associate Professor, Institute of Petroleum Engineering, School of Chemical Engineering, College of Engineering, University of Tehran, Tehran, Iran
riahi@ut.ac.ir
10.22050/ijogst.2019.156537.1481
One of the tertiary methods for enhanced oil recovery (EOR) is the injection of chemicals into oil reservoirs, and surface active agents (surfactants) are among the most used chemicals. Surfactants lead to increased oil production by decreasing interfacial tension (IFT) between oil and the injected water and to the wettability alteration of the oil reservoir rock. Since surfactants are predominantly expensive materials, it is required to consider an appropriate and high-performance plan for project economics when they are injected into oil reservoirs. One of the operational issues in surfactant flooding is the critical micelle concentration (CMC), which is usually achieved by the injection of surfactant at concentrations higher than CMC. Therefore, the lower the CMC is, the lower the amount of the material needed to be injected into the reservoir becomes, so it will help to economize the project. The salinity of the aqueous phase is a factor affecting the CMC, and with its optimal design, it can reduce the CMC. In this study, the variations of Triton X-100 CMC’s as a nonionic surfactant were measured by altering the concentration of three salts with divalent ions (CaCl<sub>2</sub>, MgCl<sub>2</sub>, and Na<sub>2</sub>SO<sub>4</sub>) and a single-capacity ion salt (NaCl), as the predominant salts in the porous medium of oil reservoirs, using surface tension (ST) method at ambient temperature and pressure. Each of these salts was dissolved at three concentrations of 0.1, 0.5, and 1 wt.% in distilled water containing specific concentrations of surfactant, and the surfactant CMC in the presence of these salt concentrations was measured. The results showed that increasing the concentration of each salt resulted in a decrease in the CMC, and, in the studied salts, NaCl produced the lowest CMC.
CMC,Triton X-100,Salinity,Surface tension,Micelle,EOR
https://ijogst.put.ac.ir/article_101904.html
https://ijogst.put.ac.ir/article_101904_ba648ea6af0afe73e0bf07fbdb04f9a2.pdf
Petroleum University of Technology
Iranian Journal of Oil and Gas Science and Technology
2345-2412
2345-2420
8
4
2019
10
01
An Investigation into the Effect of Hydrotalcite Calcination Temperature on the Catalytic Performance of Mesoporous Ni-MgO-Al2O3 Catalyst in the Combined Steam and Dry Reforming of Methane
64
84
EN
Gholamreza
Roohollahi
R&D Manager, Kharazmi Technology Development Company, Tehran, Iran
reza.roohollahi@gmail.com
Mohammadreza
Ehsani
Professor, Department of Chemical Engineering, Isfahan University of Technology, Isfahan, Iran
ehsanimr@cc.iut.ac.ir
10.22050/ijogst.2018.132105.1456
Several mesoporous nickel-based catalysts with MgO-Al<sub>2</sub>O<sub>3</sub> as the catalyst support were prepared using a co-precipitation method at a constant pH. The supports were prepared from the decomposition of an Mg-Al hydrotalcite-like structure which had already been prepared with Mg/Al=1. Prior to impregnating 10 wt.% nickel on the supports, the precursor was decomposed at several temperatures of 500, 600, 700, and 800 °C in order to elucidate the effect of calcination temperature on the physical and chemical characteristics of Mg-Al mixed oxides and the ultimate catalytic performance of the synthesized catalysts in the combined steam and dry reforming (CSDRM). The catalyst the precursor of which was calcined at 700 °C shows an excellent nickel dispersion and the highest activity among the other samples. It also exhibits the most stable performance during the long-term 36-hour run with high resistance against coke formation in the harsh condition of CSDRM.
Combined Steam and Dry Reforming,MgO-Al2O3,Mesoporous,Hydrotalcite-derived Catalysts
https://ijogst.put.ac.ir/article_101905.html
https://ijogst.put.ac.ir/article_101905_6299b39f54ace8bb872b1d5928d0c0f6.pdf
Petroleum University of Technology
Iranian Journal of Oil and Gas Science and Technology
2345-2412
2345-2420
8
4
2019
10
01
Prediction of Dispersed Phase Holdup in the Kühni Extraction Column Using a New Experimental Correlation and Artificial Neural Network
85
105
EN
Mohsen
Keshavarz
M.S. Student, School of Chemical, Petroleum, and Gas Engineering, Iran University of Science and Technology, P.O. Box 16846-13114, Tehran, Iran
mohsenkeshavarz7@gmail.com
Ahad
Ghaemi
0000-0003-0390-4083
Associate Professor, School of Chemical Engineering, Iran University of Science and Technology, P.O. Box 16846-13114, Tehran, Iran
aghaemi@iust.ac.ir
Mansour
Shirvani
Associate Professor , School of Chemical Engineering, Iran University of Science and Technology, P.O. Box 16846-13114, Tehran, Iran
shirvani.m@iust.ac.ir
Ebrahim
Arab
M.S. Student, School of Chemical Engineering, Iran University of Science and Technology, P.O. Box 16846-13114, Tehran, Iran
ebrahimarab@chemeng.iust.ac.ir
10.22050/ijogst.2018.143946.1472
In this work, the dispersed phase holdup in a Kühni extraction column is predicted using intelligent methods and a new empirical correlation. Intelligent techniques, including multilayer perceptron and radial basis functions network are used in the prediction of the dispersed phase holdup. To design the network structure and train and test the networks, 174 sets of experimental data are used. The effects of rotor speed and the flow rates of the dispersed and continuous phases on the dispersed phase holdup are experimentally investigated, and then the artificial neural networks are designed. Performance evaluation criteria consisting of <em>R</em><sup>2</sup>, RMSE, and AARE are used for the models. The RBF method with <em>R</em><sup>2</sup>, RMSE, and AARE respectively equal to 0.9992, 0.0012, and 0.9795 is the best model. The results show that the RBF method well matches the experimental data with the lowest absolute percentage error (2.1917%). The rotor speed has the most significant effect on the dispersed phase holdup comparing to the flow rates of the continuous and dispersed phases.
Solvent extraction,Kühni Extraction Column,Dispersed Phase Holdup,Multilayer Perceptron,radial basis function
https://ijogst.put.ac.ir/article_101906.html
https://ijogst.put.ac.ir/article_101906_5244898d6d92187516352f1c22e67c05.pdf
Petroleum University of Technology
Iranian Journal of Oil and Gas Science and Technology
2345-2412
2345-2420
8
4
2019
10
01
Influence of Pipeline Operating Pressure on Value Setting of Automatic Control Valves at Different Pressure Drop Rates
106
121
EN
Mehdi
Mahmoodi
Ph.D. Candidate, Babol Noshirvani University of Technology, Mazandaran, Iran
mehdymahmoody@gmail.com
Mofid
Gorji Bandpy
Professor, Babol Noshirvani University of Technology, Mazandaran, Iran
gorji@nit.ac.ir
10.22050/ijogst.2018.105249.1420
<span>When a natural gas pipeline ruptures, the adjacent upstream and downstream automatic control valves (ACV) should close quickly to prevent leakage or explosion. The differential pressure set point (DPS) at each valve location is the main criteria for value setting in ACV actions. If the DPS is not properly adjusted, the ACV may mistakenly close or it may not take any actions at a proper time. In this study, the effect of characteristic parameters such as pipeline operational pressure (POP) and pipeline pressure drop rate (ROD) due to rupture or a major leak was experimentally investigated on DPS. 25 different conditions with the double set of the mentioned typical characteristic parameters were chosen. In each condition, the differential pressure (DP) was measured over a period of 180 s by statistically analyzing the experimental results, so 25 maximum DP values (DPSs) were obtained. The DPS rises by an increase in ROD or a decrease in POP. Because of using nitrogen gas instead of natural gas for safety reasons and the uncertainties, the DPS results can be practically applied by adding a safety factor of 15%. Finally, the diagram of DPS with respect to ROD and that of non-dimensional DPS (DOP) versus non-dimensional ROD (RTP) were provided for different POP’s.</span>
Automatic Control Valve,Gas Pipelines,Operating Pressure,Pressure Drop Rate
https://ijogst.put.ac.ir/article_58003.html
https://ijogst.put.ac.ir/article_58003_237109aa652d72eea2e7bf1b476573c4.pdf