List of Articles
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Open Access Article
1 - Geochemical study of Tar-mat formation in Bangestan reservoir in Kupal oil field
Kupal anticline is elongated and almost symmetric. This structure is located in Northwest of Ahwaz city and consists of two reservoir including Bangestan and Asmari. Kazhdumi, Pabdeh and Gurpi formations are probable source rocks and Gachsaran Formation constitutes the MoreKupal anticline is elongated and almost symmetric. This structure is located in Northwest of Ahwaz city and consists of two reservoir including Bangestan and Asmari. Kazhdumi, Pabdeh and Gurpi formations are probable source rocks and Gachsaran Formation constitutes the cap rock. Because project topic is defined on Bangestan Group, so reservoir studies of Bangestan is focused on Sarvak Formation. Rock-Eval and geochemical analyses conducted on source rocks indicated that Pabdeh Formation is at early stage of oil generation window in the Kupal oil field. Kazhdumi Formation has not been drilled at this field, so geochemical and maturity assessment of this formation has been evaluated using samples from adjacent oil fields including Marun and Haftgel. Geochemical analyses indicated that Kazhdumi Formation is mature enough and is considered to be the main source rock. The aim of this project is investigating Tar-mat in Bangestan reservoir in Kupal field. It is thought that Tar-mat layer was formed in vicinity of oil-water contact and can be related to processes including natural deasphaltening, gravity segregation and oil-mixing. Based on Rock-Eval pyrolysis, pyrolysis-GC performed on Sarvak oil, it is suggested primary asphaltene formed from source rock does not exist in the studied oil but it is derived from secondary asphaltene by chemical reactions occurring due to oil-mixing in production well. In addition, analysis performed on asphaltene in oil zone, oil-water contact and water zone suggest that Tar-mat was formed in oil water contact region due to oxidation process. This layer acts as impermeable seal and prevents water flow to oil Manuscript profile -
Open Access Article
2 - Microfacies and depositional environment of the Asmari Formation in the Izeh zone
Mohammad.reza Taheri Ali asghar GabishaviIn this study, microfacies features of the Asmari Formation have been studied. The study area is located in the Izeh zone, in the vicinity of Izeh city. Accordingly four outcrop sections (Halayjan, Kuh Shur, Kuh-e Bad and Gharibi Ha) have been sampled and investigated. MoreIn this study, microfacies features of the Asmari Formation have been studied. The study area is located in the Izeh zone, in the vicinity of Izeh city. Accordingly four outcrop sections (Halayjan, Kuh Shur, Kuh-e Bad and Gharibi Ha) have been sampled and investigated. Due to unique tectonical characteristic and lateral as well as spatial variations of the outcrops, different facies have been deposited across the Asmari Formation platform in the study area. Based on the sedimentary structures, texture, skeletal and non-skeletal grains, 11 microfacies have been recognized which have been deposited in three different sub environments including open marine, shoal and lagoon. Based on this reaserch, for the Asmari Formation, three independent depositional models have been considered during the Chattian, Aquitanian and Burdigalian. On the basis of the results of this study, during the Chattian, Aquitanian and Burdigalian the Asmari Formation has been deposited in a homoclinal ramp system. During the Burdigalian toward the NE of study area (Gharibi Ha section), the shallow water deposits are abruptly overlain by pelagic limestone. Therefore, during the Burdigalian toward the NE of study area, probably, the carbonate ramp has been changed to drowned carbonate platform. It is interpreted as the result of a regional tilting that started in the late of the Burdigalian. During the Chattian in the Gharibi Ha area, the base of the carbonate Asmari Formation transits into the marl-dominated Pabdeh Formation towards the Halayjan area which could be concerned as an analogue to investigate about the stratigraphic oil traps potential in the Izeh zone. Manuscript profile -
Open Access Article
3 - Geochemical evaluation of the Sarvak and Fahliyan reservoirs crude oils by biomarker data in one of the Abadan Plain oilfields
ELham Asadi. Mehmandosti Seyed Ali Moallemi Mahnaz amirhoseyni Azizolah HabibiIn this study, 8 crude oil samples of the Sarvak (5 samples) and Fahliyan (3 samples) reservoirs from one of the main oilfields of the Abadan Plain was assessed geochemically by Liquid Chromatography, Gas Chromatography (GC) and Gas Chromatography Mass Spectrometry (GC- MoreIn this study, 8 crude oil samples of the Sarvak (5 samples) and Fahliyan (3 samples) reservoirs from one of the main oilfields of the Abadan Plain was assessed geochemically by Liquid Chromatography, Gas Chromatography (GC) and Gas Chromatography Mass Spectrometry (GC-MS) techniques. Types of crude oils of the Sarvak reservoir are Paraffinic Naphtenic and Aromatic Intermediate and are Paraffinic type for the Fahliyan reservoir crude oils. Biomarker ratios of saturate fractions such as variation of Pr/nC17 and Ph/nC18 ratios and Pr/Ph versus C27/C29 (20R) Sterane diagram indicate formation of source rock in reducing marine environment for both oil reservoirs. Furthermore, high amount of C29 Sterane in compare to C27 and C28 Steranes show that organic matter of source rock was formed in marine environment with terrestrial kerogen input. High amount C29 Hopane versus C30 Hopane, variation C27 (Dia/Dia+Reg) Steranes versus Pr/(Pr+Ph), low amount of Diasteranes versus Steranes and variation Sterane/Hopane versus C27/C29 Steranes show carbonate- shale lithology for source rock of studied oils. Depending on high amount of resin, scattering of normal alkanes, high values of Pr/nC17 and Ph/nC18 and higher UCM in compare to other samples, K11 and K15 samples of the Fahliyan reservoir and B5 sample of the Sarvak reservoir demonstrate slight to moderate biodegradation while B19 sample show very slight biodegradation. According to variation of Pr/nC17 vs. Ph/nC18, C29 Sterane 20S/(20S+20R) vs. C32 Hopane 22S/(22S+22R), C29 Sterane 20S/(20S+20R) vs. C29 Sterane αββ/(αββ+ααα) samples from both reservoirs denote early oil window formation. Samples from the Fahliyan reservoir have high thermal maturity in compare to the Sarvak reservoir samples. Manuscript profile -
Open Access Article
4 - Geochemical evaluation of the Sarvak and Fahliyan reservoirs crude oils by biomarker data in one of the Abadan Plain oilfields
Seyed Ali Moallemi Mahnaz Amir hosyeni Azizolah HabibiIn this study, 8 crude oil samples of the Sarvak (5 samples) and Fahliyan (3 samples) reservoirs from one of the main oilfields of the Abadan Plain was assessed geochemically by Liquid Chromatography, Gas Chromatography (GC) and Gas Chromatography Mass Spectrometry (GC- MoreIn this study, 8 crude oil samples of the Sarvak (5 samples) and Fahliyan (3 samples) reservoirs from one of the main oilfields of the Abadan Plain was assessed geochemically by Liquid Chromatography, Gas Chromatography (GC) and Gas Chromatography Mass Spectrometry (GC-MS) techniques. Types of crude oils of the Sarvak reservoir are Paraffinic Naphtenic and Aromatic Intermediate and are Paraffinic type for the Fahliyan reservoir crude oils. Biomarker ratios of saturate fractions such as variation of Pr/nC17 and Ph/nC18 ratios and Pr/Ph versus C27/C29 (20R) Sterane diagram indicate formation of source rock in reducing marine environment for both oil reservoirs. Furthermore, high amount of C29 Sterane in compare to C27 and C28 Steranes show that organic matter of source rock was formed in marine environment with terrestrial kerogen input. High amount C29 Hopane versus C30 Hopane, variation C27 (Dia/Dia+Reg) Steranes versus Pr/(Pr+Ph), low amount of Diasteranes versus Steranes and variation Sterane/Hopane versus C27/C29 Steranes show carbonate- shale lithology for source rock of studied oils. Depending on high amount of resin, scattering of normal alkanes, high values of Pr/nC17 and Ph/nC18 and higher UCM in compare to other samples, K11 and K15 samples of the Fahliyan reservoir and B5 sample of the Sarvak reservoir demonstrate slight to moderate biodegradation while B19 sample show very slight biodegradation. According to variation of Pr/nC17 vs. Ph/nC18, C29 Sterane 20S/(20S+20R) vs. C32 Hopane 22S/(22S+22R), C29 Sterane 20S/(20S+20R) vs. C29 Sterane αββ/(αββ+ααα) samples from both reservoirs denote early oil window formation. Samples from the Fahliyan reservoir have high thermal maturity in compare to the Sarvak reservoir samples. Manuscript profile -
Open Access Article
5 - The application of clustering methods (MRGC, AHC, DC, SOM) determining permeability carbonate reservoir rocks Ilam Formation in South West Iran
Seyed Ali Moallemi farhad khoshbakht sakineh naghdiThe permeability of reservoir parameters is important in the calculation and modeling reservoir plays a role. Measured directly via cores taken from the reservoir layer can be achieved. But due to the limited amount of core taken in a field and laboratory methods as wel MoreThe permeability of reservoir parameters is important in the calculation and modeling reservoir plays a role. Measured directly via cores taken from the reservoir layer can be achieved. But due to the limited amount of core taken in a field and laboratory methods as well as high cost; use indirect methods to determine the wells without core permeability is great value. In this study, using clustering methods using petrophysical logs permeability values were measured and analyzed. For this purpose, petrophysical logs Ilam Formation selection of 8 wells and addition of data measured in vitro permeability 3-ring is used to compare the results. Log permeability effective porosity in the well using the parameters A with the core permeability data, estimates and then check the accuracy of estimates, calculations also took place in other fields of study. In the next step, using clustering method, was estimated permeability. Then the results with experimental data and correlation coefficient, the best method is introduced. Manuscript profile -
Open Access Article
6 - Biostratigraphy, sedimentary environment and sequence stratigraphy of the Asmari Formation in well no. 4 of Lab-e Safid oil field (north of Dezful embayment, SW of Lurestan) and Tang- e Lendeh (Kuh-e Safid, NW of Dehdasht)
Selahedin Arab pour Ali Seyrafian Ali RahmaniIn this research biostratigraphy, microfacies, sedimentary environment and sequence stratigraphy of the Asmari Formation in well no.4 of Lab-e Safid (north of Dezful embayment, SW of Lurestan) and Tang- e Lendeh (Kuh-e Safid, NW of Dehdasht) has been studied. The tota MoreIn this research biostratigraphy, microfacies, sedimentary environment and sequence stratigraphy of the Asmari Formation in well no.4 of Lab-e Safid (north of Dezful embayment, SW of Lurestan) and Tang- e Lendeh (Kuh-e Safid, NW of Dehdasht) has been studied. The total thickness of the Asmari Formation is 360 m and 260 m in the Lab-e Safid and Tang- e Lendeh sections, respectively and composed of thick, medium and thin bedded limestone. The correlation of recognized biozones in the studied regions with other regions in Zagros (Bangestan Anticline: tang-e Band, tang-e Nayab and Tang-e Bulfares, Parsi oil field, Kuh-Asmari and Khaviz Anticline: Tang-e Bibinarjes) indicates that Asmari Formatin in Tang-e Bibinarjes, Tang-e Band and, well no.4 of Lab-e Safid has deposited earlier than other regions. Four different sub environments were identified in the Asmari Formation based on microfacies analysis including tidal flat, lagoon, shoal, open marine. These depositional environments correspond to inner, middle and outer ramp. On the basis of deepening and shallowing patterns in the microfacies five and two third-order sequences have been recognized in the Lab-e Safid and Tang- e Lendeh sections, respectively. In order to study the changes of depositional environment of the Asmari Formation during the Oligocene-Miocene, the recognized sequences in this study have been correlated with those recognized in other parts of the Zagros basin. Manuscript profile -
Open Access Article
7 - Biostratigraphy, microfacies and sedimentary environment of the Asmari Formation at Somghan area and correlation with other sections in the Zagros basin
Mehrnaz Rahimzadeh Ali Seyrafian Ali RahmaniThe difference in the depositional setting of the Zagros, causes multiple carbonate facies.The Asmari Formation deposited in the foreland basin during Oligo-Miocene time. In this study, biostratiography and microfacies of the Asmari Formation at Nowdan anticline next to MoreThe difference in the depositional setting of the Zagros, causes multiple carbonate facies.The Asmari Formation deposited in the foreland basin during Oligo-Miocene time. In this study, biostratiography and microfacies of the Asmari Formation at Nowdan anticline next to Somghan village (39 Km north of Kazerun) are studied. The thickness of the Asmari Formation is 302 meters and its upper and lower boundries are coverd. Field work studies resulted to recognize 4 lithostratigraphic units (unit 1: thin to medium bedded limestone, unit 2: thick and some thin and medium bedded limestone, unit 3: thin and thick bedded nudular limestone, unit 4: thin bedded nudular limestone). Based on microscopic studies, 20 genera and 19 species of benthic foraminifera were identified and two biozones related to the Oligocene were identified. Based on textural and faunal studies, nine microfacies related lagoon and open marine were differentiated. Also in this study, to reconstract geometry and to analyze the role of Qatar-Kazerun fault during Oligocene, 11 sections of the Asmari Formation were examined. Manuscript profile