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Iranian Journal of Petroleum Geology
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Open Access Article
1 - Biostratigraphy of the deposits of the Katkoyeh Formation in the Gezoiye section, northwest of Kerman (southeast of Zarand) based on conodont fauna.
Farzad Poursalehi Ali Bahrami Hamed Ameri Gustavo Gabriel VoldmanIssue 24 , Vol. 12 , Autumn_Winter 2023The Ordovician marine sedimentary sequences of Iran are located in different structural blocks along the northern margin of Gondwana. In the north of the Kerman Basin, Ordovician sedimentary sequences named Katkoyeh Formation have been introduced, which consist of 70 to MoreThe Ordovician marine sedimentary sequences of Iran are located in different structural blocks along the northern margin of Gondwana. In the north of the Kerman Basin, Ordovician sedimentary sequences named Katkoyeh Formation have been introduced, which consist of 70 to 300 meters of siliceous siliceous rocks, one or two thin carbonate horizons in the upper part, and pyroclastic deposits. Traditionally, the Cambrian-Ordovician boundary in the Kerman Basin has been determined between the Hatken Dolomite Member of the Kuhbanan Formation (Late Furongian) and the Lower Shale Member of the Katkuye Formation. However, determining the location of the previous Tremadocine boundary is uncertain because no fossils have been documented from this interval. For the purpose of biostratigraphy of the Katkuye formation in Kerman basin, Gezoye section with an approximate thickness of about 170 meters was selected. In this section, the Katkoyeh Formation is located on the Hatken Dolomite Member and under the Shabjareh Formation sandstones of Silurian age. In the Gezoiye section, due to the action of basalt dikes and intense tectonics in the region, the limestone layers containing fossils have been severely altered, and during three sampling stages, 320 conodonts were recovered from the carbonate horizon of the upper part of this formation, and 3 Genus and 7 species were identified and based on this, three conodont ranges were recorded: 1) Icriodella superba Range Zone (Katian - ? Hirnantian; Late Ordovician), 2) Amorphognathus ordovicicus Range Zone (Katian - Late Ordovician), 3) Amorphognathus superbus Range Zone (Katian - ? Hirnantian; Late Ordovician). Late Ordovician age in the Katkuye formation in the Gezoye section with at least three species of the conodont genus Icriodella (I. superba, I. deflecta, (I. cf. discrete and two species of A. superbus) Amorphognathus, A. ordovicicus) determined and led to the identification of the Katian-?Hirnantian rocks. Manuscript profile -
Open Access Article
2 - Stratigraphy, facies and depositional conditions of the Asmari Formation (Rupelian-Burdigalian) in the south-eastern folded Zagros, Bandarlengeh embayment (Khamir salt mountain section)
Peyman Rezaei Seyedeh Akram Jooybari Abdullah NajafiIssue 24 , Vol. 12 , Autumn_Winter 2023Asmari Formation (Rupelian-Burdigalian) is one of the most well-known formations in Iran. In order to investigate the stratigraphy and sedimentary environment, a section of this formation was selected in Khamir salt mountain section in Bandarlengeh embayment. In this nu MoreAsmari Formation (Rupelian-Burdigalian) is one of the most well-known formations in Iran. In order to investigate the stratigraphy and sedimentary environment, a section of this formation was selected in Khamir salt mountain section in Bandarlengeh embayment. In this number, 70 limestone microscopic thin sections and 3 marl samples (XRF) were evaluated to identify the microfacies and the sedimentation conditions.The petrographic study led to the identification of 10 microfacies belonging to the facies belts of tidal, lagoon, carbonate bar, open marine, which were deposited in the homoclinal carbonate ramp environment. The composition of marl facies oxides also indicates the presence of carbonate minerals, quartz and clay minerals, which along with field observations and alternating calcareous facies suggest that this facies was deposited in an open marine environment. Finally, it seems that the facies and fossil diversity of the Asmari Formation in the mentioned section is such that during the Aquitanian stage, this formation was located closer to the coast line and during the Rupelian and Chattian-Burdigalian times, it was located at a further distance from the coast line. Manuscript profile -
Open Access Article
3 - Petrographical factor and Petrophysical parameter: An approach to reservoir evaluation of the Sarvak formation in NW, of the Persian Gulf
Alireza BashariIssue 24 , Vol. 12 , Autumn_Winter 2023Sarvak formation is a major oil reservoir in the Persian Gulf. Various nomenclature of the Sarvak formation were applied by different operative oil companies In the northern part of the Persian Gulf. The aim at this study is to harmonize stratigraphical nomenclatu MoreSarvak formation is a major oil reservoir in the Persian Gulf. Various nomenclature of the Sarvak formation were applied by different operative oil companies In the northern part of the Persian Gulf. The aim at this study is to harmonize stratigraphical nomenclature in this district , as well as to study the reservoir qualities and to asses hydrocarbon accumulations in this area. By using different petrophysical data and integration with geological factor, resulted in revealing three stratigraphy members ( Mishrif, Ahmadi and Mauddud), as well as reservoir qualities variations , in this district. By applying, available petrophsical data, and integration with geological information, various 3D geological maps, ( porosity, water & oil saturation maps etc…) were made. Preliminary assessment of the reservoir potential of the Bahregansar & Hendijan Fields shows , Sarvak formation in these two fields, have a good reservoir qualities, but other part of this district has poor reservoir qualities. This study shows , having high portions of clay mineral in the Sarvak reservoir along with lack of suitable cap rock and poor reservoir qualities , diminished reservoir potentials in this district. Manuscript profile -
Open Access Article
4 - Reservoir characteristics prediction using the geostatistical model. Case study: Bangestan reservoir, Ziloi Field, SW Iran
Somaieh Khoram abadi Bahman Soleimani Hussin SheikhzadehIssue 24 , Vol. 12 , Autumn_Winter 2023The geostatistical model is considered as a useful tool for predicting the oil potential of reservoirs. In the present study, an attempt is made to review the importance of the geostatistical model in the reservoir characteristics, to model and examine the changes in th MoreThe geostatistical model is considered as a useful tool for predicting the oil potential of reservoirs. In the present study, an attempt is made to review the importance of the geostatistical model in the reservoir characteristics, to model and examine the changes in the petrophysical parameters of the Bangestan reservoir in the Ziloi field despite the limited number of boreholes. This carbonate reservoir consists of Ilam, Surgah and Sarvak formations and was divided into eight zones. In the modeling process, the information required for the 3D model, including geophysical interpretations, well description information, and 2D maps along with their quality control (QC), were entered into the RMS software. The construction model was prepared based on the top levels of the structures and the depth information of the wells entering the reservoir. These data were used indirectly or directly in software with high grading capability to create levels. The depth level map of the top of Ilam Formation was entered into the model as an interpretation level, digitalization and as a base contour map. Isochore maps of other zones were prepared using the depths of wells entering different parts of the reservoir. The prediction of the distribution pattern of changes in the petrophysical features of the reservoir was prepared based on geostatistical methods, average porosity maps, and water saturation. According to the results of the modeling, it was revealed that the Ziloi field has a structural complexity, caused the heterogeneity of the reservoir and increased the risk of predicting the behavior of the reservoir. Comparison of reservoir zones showed that zone 3 has better hydrocarbon potential than other zones. One of the effective factors to improve its reservoir quality is the dolomitization process. Changes in the distribution values of water saturation and porosity showed that the reservoir properties improve from the southeast to the northwest of the field. Manuscript profile -
Open Access Article
5 - Reconstruction of Asmari Formation Sedimentary Environment in Asmari and Gurpi Anticlines in the oil field of Masjed Soleiman (Southwest of Iran)
Navab Varnaseri Davood Jahani Nader Kohansal Ghadimvand Mohsen PourkermaniIssue 24 , Vol. 12 , Autumn_Winter 2023In this research, the process of lithological changes and diagenetic processes of Asmari formation with Oligo-Miocene age has been investigated. For this purpose, 400 samples were selected and collected from a section of the Masjid Suleiman oil field and the surface sec MoreIn this research, the process of lithological changes and diagenetic processes of Asmari formation with Oligo-Miocene age has been investigated. For this purpose, 400 samples were selected and collected from a section of the Masjid Suleiman oil field and the surface section of the Asmari anticline in the Dezful depression and the Gurpi anticline in the Izeh zone. Petrographic studies revealed 18 sedimentary microfacies that were deposited on a ramp-type carbonate platform. Among the significant diagenetic processes in the region are the process of micritization, bioturbation and the influence of burrowing organisms, cementation (types of cement related to marine, meteoric and burial diagenesis environments), dissolution (meteoric and burial dissolution), dolomitization (in different phases), silicification, pyritization, phosphatization, mechanical compaction, chemical compaction, fracture and porosity. Based on the identification of the sequence boundaries and following the facies depth changes, the carbonate sequence of the Asmari formation in the subsurface section and the Asmari anticline section are introduced in the form of 3 sedimentary sequences of the third order shallowing upwards, which are the former Aquitanian, the late Aquitanian and Bordigalin belong. Among the dominant porosities in the Asmari Formation, we can mention the hole, mold and fracture porosities. Manuscript profile -
Open Access Article
6 - Lithostratigraphy and Biostratigraphy of Pabdeh Formation based on planktonic foraminifera in the Ilam dam section (south Ilam_ Zagros sedimentari basin)
somaye taherizade Mohammad Vahidinia Mohammadhossein mahmoudi gharaiiIssue 24 , Vol. 12 , Autumn_Winter 2023Zagros Sedimentary basin is located in the south and southwest of Iran and Pabdeh Formation is one of the most important Cenozoic units of Zagros Sedimentary basin. In addition, Pabdeh Formation is of special importance as one of the source rocks of Zagros Sedimentary b MoreZagros Sedimentary basin is located in the south and southwest of Iran and Pabdeh Formation is one of the most important Cenozoic units of Zagros Sedimentary basin. In addition, Pabdeh Formation is of special importance as one of the source rocks of Zagros Sedimentary basin. In order to study the Lithostratigraphic and Biostratigraphic rocks of Pabdeh Formation, the section of Ilam dam in the northwest of Zagros sedimentary basin has been selected and sampled. 360 samples were taken, of which 260 washing samples and 100 thin section samples were prepared. Based on the studies performed on these samples, 25 genera and 105 species have been identified in the Ilam dam section. 26 biozones and 2 sub-biozones have been identified based on the biological zoning of Wade et al., 2011 in the Tethys area. Based on the identified biozones, the age of Pabdeh Formation in the Ilam dam section, Middle Danian-Early Aquitanian has been obtained. The deposits of Pabdeh Formation in the section of Ilam dam have a thickness of 764 m (beginning of Pabdeh to the beginning of Kalhor anhydrite) which includes purple shale units (2 Units), marl limestone with lower limestone, cherti limestone, marl limestone with upper limestone. The lower boundary of Pabdeh Formation in this section is conform and continuous with shales and marls of Gurpi Formation but its upper boundary with the gypsums of the Asmari formation is most likely accompanied by a disconform. Manuscript profile
Most Viewed Articles
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Open Access Article
1 - Study of Petrography & Petrophysics of Permian- Triassic carbonate sediments in Qatar –South Pars Arch
Ali reza BashariIssue 7 , Vol. 3 , Spring 2014Abstract Dalan and Kangan Formations are major gas reservoirs in the Persian Gulf and surrounding area. Several supper giant gas fields has been found in the region. In this study reservoir rock types were identified and were divided into four lithostratigraphic zo MoreAbstract Dalan and Kangan Formations are major gas reservoirs in the Persian Gulf and surrounding area. Several supper giant gas fields has been found in the region. In this study reservoir rock types were identified and were divided into four lithostratigraphic zones: K1 to K4. Each of the four succeeding zones have been divided into different subzone. This Studies identified different facies-types on the Dalan and Kangan formation in this region. Petrophysical & Petrographycal studies indicate that the best reservoir unites are found in: Dolo-grainstones, Dolowakestones/Packstones and Grainstones. Isopach maps and Depth maps show variations in thickness and depth of different zones in this region. Depth map on top of Kangan formation shows this formation getting deeper toward north- west and south east in the Persian Gulf. Continuity of marker beds in Permian/Triassic sediment and paleontological evidence support diachroneity of these sediments. Manuscript profile -
Open Access Article
2 - Studying Maturity and Migration Routes Using Two-Dimensional Modeling in a number of Dezful Dam Oilfields
Ashkan Maleki Seyed Ali Moallemi Mohammad Hossein Saberi Mohammad Hassan JazayeriIssue 17 , Vol. 9 , Spring_Summer 2019To the southwest of Iran there are large reservoirs of oil and gas including Jurassic and Cretaceous carbonates, with good source rocks in the succession of the Early Cretaceous and Jurassic. The purpose of this study was to investigate the production, migration and cha MoreTo the southwest of Iran there are large reservoirs of oil and gas including Jurassic and Cretaceous carbonates, with good source rocks in the succession of the Early Cretaceous and Jurassic. The purpose of this study was to investigate the production, migration and characterization of Pabdeh, Kazhdumi, Garru and Serglu source rocks in the study area. For this purpose, burial history and one-dimensional thermal modeling in four wells and two-dimensional modeling in one section for the study area were evaluated using Openuploo software to determine the maturity of layers and hydrocarbon outflow. Comparison of measured vitrinite temperature and reflectance values with model results was used for model calibration. The results of one-dimensional modelling of the burial and thermal history in this study show that the Sergloo, Grove and Kazhdumi formations have reached maturity and have had hydrocarbon outflow, but the Pabdeh Formation has not reached sufficient maturity for hydrocarbon maturation and production. The results of migration model in the studied section show that the two Early Cretaceous and Middle Cretaceous hydrocarbon systems were separated by Kazhdumi Formation and therefore hydrocarbon migration in deeper layers of Kazhdumi was mostly lateral to Abadan plain. The hydrocarbon produced from the Kazhdumi Formation, in addition to ornithologically rearing the upper layers, migrated to the Ilam and Sarvak layers due to the general slope of the layers laterally and toward the Abadan plain. In general, the process of maturation of source rocks decreased from east to west of the study area. Manuscript profile -
Open Access Article
3 - Interpretation of sedimentary environment and factors affecting reservoir quality in upper Sarvak Formation in one the oil fields of Abadan plain
Arad Kiani Mohammad Hossein Saberi Bahman Zare nejad Elham Asadi Nasim RahmaniIssue 16 , Vol. 8 , Autumn_Winter 2019The Sarvak Formation of the Albian-Turonian Formation is one of the most important hydrocarbon reservoirs in south and southwest of Iran. In this study, in order to assess the reservoir quality, from a petrographic study and porosity and permeability data, an importan MoreThe Sarvak Formation of the Albian-Turonian Formation is one of the most important hydrocarbon reservoirs in south and southwest of Iran. In this study, in order to assess the reservoir quality, from a petrographic study and porosity and permeability data, an important well in one of the oil fields of Abadan plain has been used. Based on microscopic studies, 13 microfacies have been identified in the form of Four facies tidal flat, lagoon, shoal and open marine for Sarvak Formation deposits in the studied oil field, indicating that the upper part of the Sarvak Formation is deposited in a homoclinal carbonate ramp. Among the identified diagenetic processes, dissolution, cementation, dolomitization, fracturing, compaction, neomorphism, micritization, bioturbation, pyritization, hematitization, phosphatization and silicification are mentioned. Diagenetic processes of Sarvak Formation occurred in three marine, meteoric and burial environments. Among the dissolution and fracturing diagenetic processes, the most important role has been in increasing the reservoir quality, and cementation and compaction have been the most important factors in reducing reservoir quality. Sequence stratigraphy studies identified third order sedimentary sequences of the age of Turonian, Late Cenomanian, and Middle Cenomanian, and studied the facies and diagenetic processes within its framework. Correlation of porosity and permeability data of the core showed that the reservoir quality in this formation was influenced by facies and diagenetic processes. So that the microfacies containing the rudist have the highest reservoir quality. Due to the diagenetic processes, sedimentary and porosity and permeability data, the facies shoal and open marine to the land have the best reservoir quality. Manuscript profile -
Open Access Article
4 - Modeling Mud Loss in Asmari Formation Using Geostatistics in RMS Software Environment in an Oil Field in Southwestern Iran
Kioumars Taheri Farhad Mohammad TorabIssue 11 , Vol. 6 , Spring_Summer 2016Studying lost circulation in Asmari formation is very important because about 25% to 40% of drilling costs is allocated to drilling mud expenses. Considering that Studied oil field encounters severe mud loss in Asmari formation, therefore the purpose of this study is re MoreStudying lost circulation in Asmari formation is very important because about 25% to 40% of drilling costs is allocated to drilling mud expenses. Considering that Studied oil field encounters severe mud loss in Asmari formation, therefore the purpose of this study is recognition of the lost circulation zones and illustrating the mud loss distribution in Asmari formation. The mud loss maps in Asmari field were plotted in RMS software using moving average algorithm method. For this purpose, the data of 363 wells in this oil field was processed after data preparation, for mapping and 3D modeling of 11 different zones in Asmari formation. The data processing includes different stages such as elimination of outliers, normal transformation, drawing the histogram, variography and estimation and modeling. In this research, the geostatistical kriging method was also used for estimation and 3D modeling of mud loss in Asmari formation so that the output of geostatistical modeling method shows the localized and better results. Consequently, by applying and analysis of results, the 2D and 3D models of mud loss in Asmari formation were demonstrated. By simulation and modeling of mud loss and its comparison with reservoir fault modeling and production indexes plots, it was identified that the dominant mud losses are related to fault zone fractures and in minor cases the increasing of mud weight is the reason of mud loss. Applying appropriate operations such as under balance drilling (UBD) and suitable well placement, use of drilling mud with proper mud weight in severe mud loss points, use of NIF and MMH especial drilling muds with lowest formation damage, or a combination of these methods are suggested for mud loss control in critical points of the oil field. Manuscript profile -
Open Access Article
5 - Study the role of drilling mud loss modeling and FMI log in determining Asmari reservoir fractures in one of the oil fields in Southwest Iran
Kioumars Taheri Mohammad Reza Rasaei Abbas AshjaeiIssue 14 , Vol. 7 , Autumn_Winter 2017Understanding of oil and gas reservoirs is of great help in maximizing hydrocarbon recovery. In the study of the characteristics of oil structures, the study of fractures of reservoir rock in the stages of production and development of the field is very necessary. Nowad MoreUnderstanding of oil and gas reservoirs is of great help in maximizing hydrocarbon recovery. In the study of the characteristics of oil structures, the study of fractures of reservoir rock in the stages of production and development of the field is very necessary. Nowadays, the use of mud loss modeling and image logs in helping accomplish this task is of great assistance to oil geologists. Since the most of Iran's reservoirs are carbonate kind, investigating and identifying fractures, the degree of fissures opening and porosity distribution in the Asmari reservoir field of study, It is one of the most effective factors in the production of hydrocarbons from this field. One of the best ways to identify and interpret geology in the well, using of the FMI image log is, which can create high quality images from the well. With the help of the images provided, can determine the types of fractures, porosity, the distribution of diagenetic porous spaces and the estimation of permeability trend. In this article, first, structure and Functionality of the FMI image log and then drilling and production problems were evaluated in Asmari reservoir. In the following, the functional role of the log in interpreting and determining the degree of fissures opening, porosity distribution and permeability level in 8 wells in Asmari reservoir, has been evaluated. In this study, identification of Asmari reservoir fractures and how to expand these fractures in the reservoir By using mud loss modeling, interpretation of the FMI image log and the effect of these fractures was on the porosity and permeability of the reservoir. In this study, it has been determined that, fractures identified in wells very good matching with drilling mud loss maps with rock basement faults at the has anticline of the Asmari reservoir. Manuscript profile -
Open Access Article
6 - Three-dimensional geological modeling in two zones of eastern side of Ahvaz oil field
Razeyeh . Doosti Irani Maryam Payrovi Mohammad .rahim karimi Mehdi . Doosti IraniIssue 9 , Vol. 5 , Spring_Summer 2015The Ahvaz field is one of the most important oil fields in the Zagros Basin which is located in the Dezful Embayment. The trend of Ahvaz oil field is northwest- southeast parallel to the Zagros mountains. The purpose of this study is the geological 3D simulation (petrop MoreThe Ahvaz field is one of the most important oil fields in the Zagros Basin which is located in the Dezful Embayment. The trend of Ahvaz oil field is northwest- southeast parallel to the Zagros mountains. The purpose of this study is the geological 3D simulation (petrophysical) for the zone one and two in the eastern part of the Ahvaz oil field. In this investigation, porosity modeling, water saturation and shale volume by using sequential Gaussian Simulation (SGS) was performed. At first, well logs, cores, well’s coordination, top and thickness of formations of the zone three of Ilam Formation and zone one of Sarvak Formation were collected. These information related to 25 wells in the eastern part of the Ahvaz oil field was used for the 3D modeling of the reservoir by using Petrel software. For the recognition of spatial correlation, variograms based on water saturation and permeability and three dimensional model of the petrophysical parameters and net to gross ratio (NTG) were drawn. Manuscript profile -
Open Access Article
7 - Genetic classification of the Persian Gulf Eastern part oil fields by infrared spectroscopy of asphaltene samples
Morteza Taherinezhad Morteza Asemani Ahmad reza RabbaniIssue 12 , Vol. 6 , Autumn_Winter 2016Asphaltene is always considered as a problem in oil industry. But, asphaltenes are desirable compounds in geochemical studies specially in oil-oil correlation. Oil-oil correlation is one of the most important issues in geochemical studies that enables to classify oils g MoreAsphaltene is always considered as a problem in oil industry. But, asphaltenes are desirable compounds in geochemical studies specially in oil-oil correlation. Oil-oil correlation is one of the most important issues in geochemical studies that enables to classify oils genetically. Asphaltenes due to their structural similarity with kerogen and unaffected and/or little affected from secondary processes are known as valuable compounds in geochemical studies. So, in this paper the structural characteristics of asphaltenes were considered as a correlation parameter. For this study 5 oil samples were collected from the Persian Gulf eastern part oil fields. Structural characteristics of these asphaltenes were investigated by Fourier transform infrared (FTIR) spectroscopy. 2D and 3D graphs based on aliphatic and aromatic compounds (predominant compounds in asphaltenes structure) and sulfoxide and carbonyl functional groups (which are represent of sulfur and oxygen abundance in asphaltenes) were used for comparison of asphaltenes structure in different samples. According to the results of these defined graphs, the studied oil samples comprise two oil families with distinct genetic characteristics. The first oil family consists of the Salman and Reshadat oil samples, and the second oil family consists of the Resalat, Siri E and Siri D oil samples. To validation and complement the obtained results, the other common geochemical techniques such as stable carbon isotope and biomarkers parameters, were employed and these techniques completely confirmed previous results. According to biomarker parameters, the first oil family originated from marl source rock and the second oil family was sourced from carbonate source rock. Manuscript profile -
Open Access Article
8 - A comprehensive study of shale intervals of Burgan Formation: implications for borehole stability
Mohammad سلیمانی سعیده رعیت دوستIssue 6 , Vol. 3 , Autumn 2013Abstract This aims of this study is to characterize the Shale intervals of Burgan Formation from a borehole stability point of view. This paper describes the process and workflow for data-acquisition and interpretation in a shale formation characterization program an MoreAbstract This aims of this study is to characterize the Shale intervals of Burgan Formation from a borehole stability point of view. This paper describes the process and workflow for data-acquisition and interpretation in a shale formation characterization program and demonstrates not only the benefits of acquiring specific data, but also highlights the uses of the data to aid the exploration decision process. The next purpose of this paper is to provide a research process that can be applied in similar geological settings. In the study process, we collected a complete set of information and samples from the field and presented a detailed case study, including laboratorial studies of formation samples and interpretation of the information. Available samples and information sources from Burgan Formation include drillhole cores. The minerals were defined by direct and indirect methods. Bulk XRD analyses performed on core samples showed presence of traces of clay minerals. For determination of the exact clay mineral type, clay minerals were extracted and treated by heat and ethylene glycol saturation. Treated samples were subjected to XRD analyses. Interpretation of the natural gamma spectrometry logs allowed the determination of the type and content of clay minerals. In a next step, in order to study the distribution of minerals types, SEM photomicrographs and Cation exchange capacity (CEC) of the samples were carried out. The results revealed that shale intervals of Burgan Formation are not expandable clays. The instability problem cannot be completely solved by drilling fluid design. The study shows, different approached methods reached the same results. Manuscript profile -
Open Access Article
9 - Calculation of elasticity modulus and rock strength parameters and their relationship with porosity in Dalan formation in one of the well in south pars gas field
Reza Khoshnevis Zadeh Alireza Hajian Ehsan LarkiIssue 14 , Vol. 7 , Autumn_Winter 2017The elastic parameters of the rock include the Young modulus, the Poisson ratio, the bulk modulus and the shear modulus. Young modulus with the unconfined compressive strength of rock, are two key parameters in the definition of intact rock. Elastic modulus represents t MoreThe elastic parameters of the rock include the Young modulus, the Poisson ratio, the bulk modulus and the shear modulus. Young modulus with the unconfined compressive strength of rock, are two key parameters in the definition of intact rock. Elastic modulus represents the amount of rock rigidity and is known as the stress-strain chart slope. These parameters represent of rock strength to failure, are important parameters for the stability analysis of wellbore stability. According to the unavailability and cost of core data, and also attended to this fact that the data from the core are not continuous and not available at all points in the well, the uses of DSI logs is one of the best methods for calculating elastic modules. Using these logs, you can also study elastic moduli continuously in a well. In this study, elastic dynamic parameters were calculated using the DSI and density logs for the Dalan Formation. Attention to the fact that the calculated parameters using the velocity of the sound waves are of the type of dynamic parameters, these parameters were have converted to the static modules using appropriate empirical relationships. The rock strength Parameters were calculated using the experimental relationships commonly used in the oil industry to determine rock strength parameters. These parameters were calculated according to static elastic modulus as well as porosity and shale volume. Comparing the values of elastic modulus and rock strength parameters with porosity showed that porosity with elastic modulus and rock strength parameters has an inverse relationship, so that with increases the porosity, the elastic modulus and rock strength parameters have been reduced. Manuscript profile -
Open Access Article
10 - Estimation of relative permeability curves from capillary pressure data in one of iranian carbonate reservoir
بابک شعبانی عزت اله کاظم زادهIssue 2 , Vol. 1 , Autumn_Winter 2012Relative permeability can be measured directly from cores, but due to problems such as unavailability of experimental results of direct relative permeability measurement, indirect techniques also have been used to calculate relative permeability. One of these methods is MoreRelative permeability can be measured directly from cores, but due to problems such as unavailability of experimental results of direct relative permeability measurement, indirect techniques also have been used to calculate relative permeability. One of these methods is estimating relative permeability curves from capillary pressure data that the reliability of this method for approximation of liquid-gas relative permeability curves had thoroughly investigated. However, there is not enough information to conclude which method is the standard one for calculating oil-water relative permeability curves. Various capillary pressure techniques such as the Corey, Brooks-Corey, Li-Purcell and Li-Burdine methods were utilized to calculate oil-water relative permeabilities using the measured oil-water capillary pressure data in drainage process in an oil-wet Carbonate reservoir. Despite wide popularity of Purcell and Burdine methods for calculating relative permeability, new Li-Purcell and LiBurdine methods were used. The calculated results were compared to the experimental data of oil-water relative permeabilities measured in a Carbonate reservoir. The Corey and Brooks-Corey models are shown an acceptable and nearly exact match with the measured oil relative permeability values. However, the Li-Purcell and Li-Burdine models underestimate the values for wetting phase in most cases. It is also worth mentioning that, except Li-Purcell method, the results of all other methods for calculating non-wetting phase relative permeability are almost the same and overestimate the values. Then, rock typing on the basis of pore throat radius at 35% mercury saturation were done and the accuracy of each model were examined for all rock types. Results of this work revealed that calculation of oil-water relative permeability using the capillary pressure data is also a reliable technique in oil-wet carbonate reservoirs. Manuscript profile
