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Iranian Journal of Petroleum Geology
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Open Access Article
1 - Biostratigraphy, biofacies and CAI of the late Devonian deposits in Kale-Sardar section, North-east Tabas, based on conodont fauna
Mina Ramshini ٍٍElahe Sattari Ali Bahrami Hosyen Vaziri moghadamIssue 22 , Vol. 11 , Autumn_Winter 2022Kale-Sardar section, is located at the vicinity of Niaz village, 15 kilometers east of Tabas town. This section consists of 80 m thick and from Late Devonian deposits as known as Shishtu formation that upper part of this section has cut by a fault by Frasnian’s deposits MoreKale-Sardar section, is located at the vicinity of Niaz village, 15 kilometers east of Tabas town. This section consists of 80 m thick and from Late Devonian deposits as known as Shishtu formation that upper part of this section has cut by a fault by Frasnian’s deposits. The entire studied thickness is subdivided into 12 lithostratigraphic units and in order to study of conodont elements, 27 species and subspecies belonging to 7 genera were recognized, that due to these revealed conodont elements, Shishtu formation’s age in the studied section spans from Eifelian to late Frasnian. The Frasnian-Famennian bio event in studied section is located between two intervals linguiformis Zone and Lower to Middle triangularis zones which is located at the top of the dark Frasnian shales and at the base of the thin limestones of the Famennian layer. The microfacies determined in studied section are subdivided into siliciclastic-carbonate and carbonate facies, which were deposited from the shore to the deep part of the marine environment. Gradual changes in facies within stratigraphical sequence, sedimentological hiatus due to sudden change in sedimentary environment’s slope, absence of reef facies (related to Wilson’s 5th facies zone) and presence of discontinuous bioclastic barrier (existence of semi-enclosed lagoon), convey that studied sediments were deposited in a homoclinal carbonate ramp. Manuscript profile -
Open Access Article
2 - Source rock characterization of the Fahlian, Gadvan, and Surmeh formations in giant Gachsaran oilfield
Majid Safaei-Farouji Hossain Rahimpour-Bonab Buyuk GhorbaniIssue 22 , Vol. 11 , Autumn_Winter 2022The aim of this study is geochemical evaluation of the Fahlian, Gadvan, and Surmeh formations as possible source rocks in Gachsaran oil field using Rock-Eval Pyrolysis manner. All of the studied samples possess migration index amounts lower than 1.5 showing indigenous n MoreThe aim of this study is geochemical evaluation of the Fahlian, Gadvan, and Surmeh formations as possible source rocks in Gachsaran oil field using Rock-Eval Pyrolysis manner. All of the studied samples possess migration index amounts lower than 1.5 showing indigenous nature of their hydrocarbons. TOC versus S2 and TOC against S1+S2 diagrams suggest fair hydrocarbon generation potential for the Fahlian and Surmeh formations and fair to good potential for the Gadvan formation. for the Fahlian and Surmeh formations type III kerogen and for the Gadvan formation mixed type II and II-III kerogens were identified. So, the Fahlian and Surmeh formations contain organic matter with terrigenous source (gas prone) and the Gadvan Formation possess both of marine and terrigenous organic matter (oil and gas prone). According to the cross plot of Tmax versus Hydrogen index (HI), the Gurpi formation is capable of mixed gas and oil, and gas generation and the Fahlian and Surmeh formations considered only gas prone formations. In terms of organic facies type, the surmeh, Fahlian, and Gurpi formations located in CD, C and CD, and BC and C zones of jones diagram, respectively. So, the Gadvan formation in compare to the Fahlian formation and the Fahlian formation in compare to the Surmeh formation, deposited under more anoxic conditions. In terms of thermal maturity, All of the Fahlian, Gadvan, and Surmeh formations located in oil window zone, but the Surmeh formation possess higher maturity than the Fahlian formation and the Fahlian formation have highr maturity in compare to the Gadvan formation. Manuscript profile -
Open Access Article
3 - Permeability improvement calculated from Stoneley-FZI method in Kangan reservoir, one of Iran's gas fields
hossein rezaie yegane doostIssue 22 , Vol. 11 , Autumn_Winter 2022Permeability in fluid flow is for a porous rock, which is exactly what causes the problem. core analysis and well testing are two most commonly used methods of permeability measurement, but in-vitro measurement of permeability by applying core analysis on all wells in a MorePermeability in fluid flow is for a porous rock, which is exactly what causes the problem. core analysis and well testing are two most commonly used methods of permeability measurement, but in-vitro measurement of permeability by applying core analysis on all wells in a specific field is very time consuming and costly and even impossible when dealing with Horizontal wells. Wells testing, on the other hand, is not cost-effective for reasons such as; High costs and zero production during the testing process. Therefore, thanks to their low cost, comprehensiveness and availability, permeability estimation methods developed according to conventional logs land DSI diagrams are of critical importance. Taking this into account, in the present study, permeability was first estimated using multi-resolution graph-based clustering (MRGC) and the results were compared with permeability rates obtained from core analysis. In the second stage, permeability was measured by ST-FZI method and the results were compared with permeability rates obtained from core analysis. In the third stage, the multi-resolution graph-based clustering (MRGC) method was used to improve the permeability calculated by the ST-FZI method and overcome the reservoir heterogeneity. First the flow units were identified, and then the ST-FZI method was applied on each flow unit to calculate permeability and finally the calculated permeabilities were combined to obtain an accurate permeability graph of the studied well. The correlation coefficients of permeability rates estimated via core analysis in the multi-resolution graph-based clustering method (R2 = 77), ST-FZI method (R2 = 47) and improved method (R2 = 84) were measured. The afore-mentioned method was able to improve the permeability calculated in the previous step by 37% and was recognized as the best permeability measurement method in the Kangan reservoir of the well subjected to study. Manuscript profile -
Open Access Article
4 - Strain and shortening amount analysis in the Asmari anticline, Khuzestan province
Babak Samani Abbas Charchi Narges KhatibIssue 22 , Vol. 11 , Autumn_Winter 2022The only outcrop of Asmari formation in the Dezful embayment is visible in the Asmari anticline. In order to estimate the strain parameters and shortening values, 26 geological cross sections were prepared perpendicular to the anticline axis. Based on the, interlimb ang MoreThe only outcrop of Asmari formation in the Dezful embayment is visible in the Asmari anticline. In order to estimate the strain parameters and shortening values, 26 geological cross sections were prepared perpendicular to the anticline axis. Based on the, interlimb angle measurements, the interlimb angles of the northern and central parts of the anticline show smaller angles than the southern parts. Determination of strain ratio (R) values indicates the strain values between 1.12 - 1.52. The zoning map of strain ratio values shows higher strain values in the northern and central parts of the anticline. Using geological cross sections and measuring the base length of the folded layer of Asmari formation (L0) and the straight length of the layer (L1), the percentage of shortening values were calculated in each section. The results show the occurrence of 1.8% to 12% shortening in different parts of the anticline. Shortening map of the Asmari anticline shows more shortening amounts in the northern and central parts of the anticline than the southern parts. Manuscript profile -
Open Access Article
5 - Biostratigraphy and Lithostratigraphy of Pabdeh Formation is based on planktonic foraminifera in the section of Jahangirabad (south Ilam_ Zagros basin)
somaye taherizade Mohammad Vahidinia mohammadhossein mahmoudi gharaiiIssue 22 , Vol. 11 , Autumn_Winter 2022After the Late Cretaceous and during the Paleogene, with the sea level rising, the Zagros sedimentary basin is covered with a progressive sea in which the Pabdeh Formation is deposited. The dual function of this formation as a source of oil and its reservoir capacity MoreAfter the Late Cretaceous and during the Paleogene, with the sea level rising, the Zagros sedimentary basin is covered with a progressive sea in which the Pabdeh Formation is deposited. The dual function of this formation as a source of oil and its reservoir capacity due to the diversity of lithology and its location between the two reservoirs Asmari and Bangistan, and the age of this formation is one of the issues that has attracted the attention of geologists. In order to study the stratigraphic and biostratigraphic rock of the Pabdeh Formation, the Jahangirabad section in the northwest of Zagros sedimentary basin has been selected and sampled. 320 samples were taken, of which 230 samples were prepared by washing method, and 90 samples were prepared by thin section method and examined. Based on studies conducted in the Jahangirabad section, 25 genera and 110 species have been identified, and based on the identified fossils, 27 biozones and 7 sub-biozones have been identified. Based on the identified biozones, the age of the Pabdeh Formation in the Jahangirabad Danian Early-Late Chattian section has been obtained. Pabdeh Formation deposits in the Jahangirabad section have a thickness of 676 m (beginning of purple shale to anhydrite Kalhor) which includes units of purple shale (2 parts), marl limestone with lower limestone, limestone, and marl limestone with limestone It is high. In this section, the lower boundary of the Pabdeh Formation is continuous with shales and marls of Gurpi Formation, and its upper boundary is with continuous limestone of Asmari Formation. Manuscript profile -
Open Access Article
6 - Biostratigraphy and paleoecology of Family Gavelinellidae in Sanganeh and Aitamir Formations at the Kopeh-Dagh basin
Maryam Motamedalshariati Mahmoud JalaliIssue 22 , Vol. 11 , Autumn_Winter 2022The sedimentary basin of Kopeh-Dagh is located in the northeast of Iran. This sedimentary basin has been of interest for a long time because of hydrocarbon materials. Gavelinellids are the most abundant and dominant groups of benthic foraminifera in epicontinenal seas d MoreThe sedimentary basin of Kopeh-Dagh is located in the northeast of Iran. This sedimentary basin has been of interest for a long time because of hydrocarbon materials. Gavelinellids are the most abundant and dominant groups of benthic foraminifera in epicontinenal seas during Cretaceous period which belong to Rotaliinacean foraminifera. They have shown a wide biogeographical distribution and dispersion in many areas of Tethys. Their evolutionary trend during the Cretaceous time was success. The high concentration of marine sedimentary rocks and the absence of igneous activities in the Kope-Dagh sedimentary basinhave caused it to be considered the most suitable basin for the formation and accumulation of hydrocarbons after the Zagros sedimentary basin. This basin has suitable layers of carbonate rocks and porous sandstones to store hydrocarbon materials, also thick layers of shales in this basin can act as suitable source and cap rocks. In this research some genera and species from this family in Sanganeh and Aitamir Formations at five stratigraphic sections including Marave Tappeh, Takal kuh, Sheykh, Gadvecanlou and Kalat from point of biostratigraphical and paleoecological applications have been investigated. In this study, four biozones including Gavelinella flandrini-Gaudryina cf. praedividens assemblage zone, Berthelina intermedia assemblage zone, Berthelina cenomanica Assemblage Zone, Berthelina intermedia-Osangularia schloenbachi Assemblage Zone have been introduced. Based on the reported genera and species of the Gavellinidae family, it can be stated that the studied formations were deposited in the middle and outer part of the continental shelf to the upper part of the continental slope and in aerobic to semi-aerobic environments. The presence of more planktonic foraminifera than benthic foraminifera in the Aitamir Formation, the depth of the basin increases. 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
محمد 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
