Petroleum University of TechnologyIranian Journal of Oil and Gas Science and Technology2345-241211120220101Investigation of Origin, Sedimentary Environment and Preservation of Organic matter: A Case Study in Garau Formation11513546110.22050/ijogst.2021.291679.1601ENMeisam HemmatiM.S. Student, School of Geology, College of Science, University of Tehran, Tehran, Iran.Yaser AhmadiAssistant Professor, Chemical and Petroleum Engineering Department, Ilam University, P.O. Box 69315/516, Ilam, Iran.Journal Article20210622Knowing the characteristics of suitable environments for precipitation of oil prone source rocks facilitates oil explorations and leads to development of oil fields. The current study investigates the organic matter properties and sedimentary environment conditions of the Garau Formation in various outcrop sections in Lurestan province from south-west of Iran (High Zagros) with using elemental analysis, visual kerogen analysis and Rock-Eval pyrolysis data. The geochemistry parameters indicate that the Garau Formation is an excellent oil prone source rock and composed of kerogen type I and II. The oxygen index (OI) is very low which reveals that organic matter deposited in an anoxic sedimentary environment and suitable for the preservation of organic matter and hydrocarbon generation. The visual analysis of isolated kerogens from source rock samples indicates the abundance of dark amorphous organic matter (AOM) with small amounts of phytoclasts and pyrite with no palynomorphs. Sedimentation seems to have occurred in deep and reduced parts of a carbonate basin during a rapid transgression. In addition, due to the effect of thermal maturation, the color of amorphous organic matter has darkened. The elemental analysis and Van-Krevelen diagram was shown that the type of organic matter and reveals the thermal maturity of the oil window. Moreover, amount of pyritic sulfur (Sp) and organic sulfur (So) contents have been calculated, and it was reveals that the high content of organic sulfur is a key element in the structure of organic matter.https://ijogst.put.ac.ir/article_135461_a207c46ca0c48e8f65ef0411feda1de9.pdfPetroleum University of TechnologyIranian Journal of Oil and Gas Science and Technology2345-241211120220101Experimental Investigation of Effect of SiO2, CuO, and ZnO Nanoparticles on Filtration Properties of Drilling Fluid as Functions of Pressure and Temperature152714449610.22050/ijogst.2022.322972.1619ENBorzu Asgari PirbaloutiAssistant Professor, Department of Petroleum Engineering, Masjed Soleiman Branch, Islamic Azad University, Masjed Soleiman, IranJournal Article20211103Among the different operating parameters that must be carefully controlled during the drilling operation, penetration of drilling mud into the permeable zone of formations is one of the essential ones that can have a destructive effect on the productive zone. Thus, the current investigation concentrates on investigating the effects of different nanoparticles (NPs), namely SiO<sub>2</sub>, CuO, and ZnO, considering their size, type, and concentration (0.2 to 2 wt % for each nanoparticle) on the properties of the drilling fluid, including rheology and high- and low-temperature filtration. NPs can improve the rheological properties of the mud by changing the friction coefficient favorably. Moreover, the effects of temperature and pressure as two critical thermodynamic parameters are examined. The results show that it is possible to enhance the rheological properties (viscosity) of the drilling mud to a maximum value of about 20 % if NPs with a concentration of 2 wt % are added to the drilling fluid. Extreme gel strength will lead to high pump initiation pressure to break circulation after the mud is in a static condition for some time. The results reveal that reducing the gelation properties of the drilling mud is possible using low concentrations of NPs. Moreover, the results reveal that SiO<sub>2</sub> and ZnO exhibit a lower filtration rate than CuO. Finally, the effects of temperature and pressure were investigated, which revealed that regardless of the reductive effect of NPs (reducing the filtration rate from 17.7 to about 10 cm<sup>3</sup>), increasing the pressure and temperature lead to an increase in the filtration rate (reducing the filtration rate from 67 to 35 cm<sup>3</sup>). Further, the rheological properties of the mud remain relatively constant.https://ijogst.put.ac.ir/article_144496_38feffc4b81e9e38acedbdb801f4ee92.pdfPetroleum University of TechnologyIranian Journal of Oil and Gas Science and Technology2345-241211120220101Risk Assessment and Risk Management of Kermanshah Province Gas Company Using HAZOP Method283714697210.22050/ijogst.2022.292733.1604ENZahra HeydariM.S. Student, Put-Gas Company, Sistan and Balochestan, IranVahid RahmaniM.S. Student, Razi University-Gas Company, Kermanshah, IranAli Akbar HeydariM.S. Student, Sistan and Balochestan-Gas Company, Sistan and Balochestan, IranMohsen MotavasselAssistant Professor, Department of Chemical Engineering, Petroleum University of Technology, Abadan, IranJournal Article20210402Every day’s large amount of gas is consumed which is transported through pipelines. Due to irreparable consequences of gas related accident and their heavy financial losses; therefore, the safety of pipeline is one of the priorities of gas companies, government and consumers. Hazard is part of every human endeavor, so hazard identification and risk management is very important. As some of event may not be exactly predictable, the study of risk is very important. The risk management is a determinative step of the health, safety and environmental management system (HSEMS). In this study performance of Hazard and operability (HAZOP) method for asses of hazards and risks, for all process, that present in Kermanshah Province Gas Company was evaluated. There are different risk analysis techniques. As the HAZOP is Process Hazard Analysis that not only identifies system hazards, but also determines their probability of occurrence by the effects of any deviations from design conditions and it gives us the accurate results, it’s used for risk assessment in this project. This research was conducted by a team of 3 experts and identified the process hazards by means of quid words. At the end of this study in Kermanshah Province Gas Company’s about 282 risks were identified and only 03 risk is unacceptable e and 111 are Conditional that must be eliminated without delay , the others are acceptable that the risk must be eliminated but it is not an emergencyhttps://ijogst.put.ac.ir/article_146972_e1a48dd957ac350c4414e53e7bc0b9d6.pdfPetroleum University of TechnologyIranian Journal of Oil and Gas Science and Technology2345-241211120220101ASPHALTENE, NAPHTHENIC ACID AND NAPHTHENATE COMPONENTS OF SOME CRUDE OIL SAMPLES AND THEIR IMPACT ON PRODUCTION AND EXPORT14839810.22050/ijogst.2022.277619.1615ENTEMPLE NCHIKWEUNIVERSITY OF PORT HARCOURTRemy UkachukwuDuruDepartment of Pure and Industrial Chemistry. University of Port HarcourtJournal Article20211005The Asphaltene and metal naphthenate components of crude oil samples from ten different wells within an oil reservoir were determined using different analytical techniques. The asphaltene content was determined by gravimetric analyses while the metal naphthenate components were determined by obtaining the metal ion concentration of the produced water and the naphthenic acid concentration of the crude using Atomic absorption spectrometer (AAS) and potentiometric titration respectively. Results obtained showed that the asphaltene content of the crude samples ranges from 2.0000 – 8.000 %w while the naphthenic acid concentration indicated by the total acid number (TAN) ranges from 0.3000 – 1.4600 mg/KOH/g. All the crude samples possess asphaltene components as well as the propensity to form calcium and sodium naphthenate scale deposits having a Ca2+ concentration between 32.5000 – 94.5000 mg/L and a Na+ concentration between 27.7 – 105.1 mg/L respectively, however the formation of naphthenate scale deposits is highly dependent on the pH of the produced water of the crude which makes well FT01 less likely to form naphthenate scales since it has a pH < 6. Both asphaltene and naphthenate deposits are directly proportional to the specific gravity of the crude and inversely proportional to the API gravity implying that both components reduce the quality of the crude. Asphaltene and metal naphthenate solid deposits in the crude can cause a lot of flow assurance difficulties such as, blocking of expedition lines, pore plugging, wettability, crude oil parameter alteration, as well as reduction in oil recovery.https://ijogst.put.ac.ir/article_148398_e61bb548867b15680edbfac937555010.pdfPetroleum University of TechnologyIranian Journal of Oil and Gas Science and Technology2345-241211120220101Numerical and laboratory modeling of smart water polymer flooding to enhance oil recovery in one of the oil reservoirs in southwestern Iran14974310.22050/ijogst.2022.335043.1633ENAliPanah RostamzadehDepartment of Chemical Engineering, Yasuj Branch, Islamic Azad University, Yasuj, IranSeyed Aboutaleb Mousavi ParsaDepartment of Chemical and Petroleum Engineering, Yasuj Branch, Islamic Azad University, Yasuj, Iran0000-0002-2807-3987Faramarzi MehdiDepartment of Chemical Engineering, Gachsaran Branch, Islamic Azad University, Gachsaran, IranJournal Article20220324One of the most important ways to enhance oil recovery in oil reservoirs is chemical flooding. The study of performance and efficiency of these processes in increasing the range of oil recovery from reservoirs depends on several factors, including the rock and fluid properties of the reservoir, and therefore one of the most important steps in evaluating the performance of these methods for a reservoir is the laboratory study and calculating the chemical agent potential to recover oil. For this purpose, a laboratory study and integrated simulation in order to identify the effective mechanisms in the injection of smart water polymer in order to identify the necessary and dominant conditions of this method was performed to improve the recovery of Iranian carbonate reservoirs. Initially, four injection scenarios, water injection-polymer injection-smart water injection, water injection-smart water injection-polymer injection, water injection-smart water polymer injection and smart water injection- smart water polymer injection were tested in a laboratory and then simulation of smart water polymer flooding using Eclipse simulator 100 and the effect of polymer injection on oil recovery and oil trapping in the reservoir rock was performed and finally the results of the simulator and the results of laboratory data were validated. The results showed that smart water injection- smart water polymer injection have better performance in improving secondary oil recovery by 63.45% and wettability changing is one of the main mechanisms to improve oil recovery. The results also showed that in optimal conditions, despite the mechanical degradation of the polymer, initial oil in place recovery is achieved up to 85% by controlled adsorption of polymer on the rock surface.Petroleum University of TechnologyIranian Journal of Oil and Gas Science and Technology2345-241211120220101Prediction of Shale Volume and Water Saturation using Pre-Stack Seismic and Well-Log Data in an Oil Field15062910.22050/ijogst.2022.338963.1638ENAli JelvegarfilbandPh.D. Candidate, Department of Petroleum Engineering, Faculty of Civil and Earth Resources Engineering, Central Tehran Branch, Islamic Azad University, Tehran, IranMohammad Ali RiahiProfessor, Institute of Geophysics, University of Tehran, Tehran, Iran0000-0002-3827-4467Majid BagheriAssociate Professor, Institute of Geophysics, University of Tehran, Tehran, IranJournal Article20220423The petrophysical parameters of the Ghar Formation are characterized in this study. A combination of pre-stack seismic data gathers and well-log data is used to estimate water saturation and shale volume in the Ghar reservoir. For such a purpose, first, the highest possible correlation between the well logs and the seismic inverse data was established. After extracting the best wavelet, an accurate relationship between the estimated and the values from core data was obtained. Secondly, using the data of another well, the validity of the constructed model was examined. The results showed that the combination of three attributes of instantaneous cosine of phase, √(Z_P ), and √(V_P ) is suitable to estimate the shale volume of the reservoir with considerable accuracy with a correlation coefficient of about 70%. Although the two layers in the Ghar section have a shale volume of about 10%, in general, the shale volume in the reservoir area is negligible. The logarithm of the ratio of compressional wave velocity to shear wave velocity attribute shows the highest correlation, about 62%. Finally, validation of the results of the mentioned properties with unintroduced well-log data showed an accuracy of about 90% in prediction.Petroleum University of TechnologyIranian Journal of Oil and Gas Science and Technology2345-241211120220101Defect Analysis in Functionally Graded Spherical Pressure Vessels15161710.22050/ijogst.2022.244926.1560ENHadi Eskandaripetroleum university of technologyJournal Article20200822This work pertains to investigate the values of the stress intensity factor (SIF) in a functionally graded spherical pressure vessel with an embedded surface defect (semi elliptical crack) under thermo-mechanical loading. The three dimensional finite element analysis is performed to evaluate the SIFs through the crack front for a wide range of crack profiles and the various layer thickness. It is assumed that the elastic modulus of sphere varies exponentially in the radial direction of the vessel.<br /><br />The effect of non-uniform coefficient of thermal expansion (CTE) on the fracture parameters is also studied. The obtained results show that the material gradation of spherical pressure vessel can considerably affect the distribution of the SIFs along the crack front. The gradation of material, the wall thickness of spherical pressure vessel and the profile of crack front can affect the critical point through the crack front which is apt to the crack growth.