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Open Access Article

1 - Sonic wave velocity estimation using intelligent system and multi resolution graph base clustering: A case study from one of Iranian south field
مرتضی نوری مینا کریمی خالدی

20.1001.1.22518738.1392.3.6.3.5

Abstract Compressional and shear velocity are two fundamental parameters, which have many applications in petrophysical, geophysical, and geomechanical operations. These two parameters can be obtained using Dipole Sonic Imaging tool (DSI), but unfortunately this tool More

Abstract Compressional and shear velocity are two fundamental parameters, which have many applications in petrophysical, geophysical, and geomechanical operations. These two parameters can be obtained using Dipole Sonic Imaging tool (DSI), but unfortunately this tool is run just in few wells of a field. Therefore it is important to predict compressional and shear velocity indirectly from the other conventional well logs that have good correlation with these parameters in wells without these logs. Classical methods to predict the mentioned parameters are utilizing correlations and regression analysis. However, the best tool is intelligent systems including Artificial Neural Network, Fuzzy Logic, Adaptive Neuro Fuzzy Inference System, and Multi resolution graph base clustering for performing such tasks. In this paper 1321 data points from Kangan and Dalan formations which have compressional and shear velocity are used. These data are divided into two groups: 995 and 326 data points were used for construction of intelligent systems and model testing, respectively. The results showed that despite differences in concept, all of the intelligent techniques were successful for estimation of compressional and shear velocities. The Multi resolution graph base clustering. The method had the best performance among the others due to precise clustering the data points. Using this method, the compressional and shear velocity were correlated with correlation factor of 0.9505 and 0.9407, respectively. The developed model does not incorporate depth or lithological data as a part of the inputs to the network. This means that utilized methodology is applicable to any field. Manuscript profile

Open Access Article

2 - Numerical calculation of permeability tensor in fractured reservoirs
سیما جلیلی رئوف حسین معماریان محمد رضا رسائی بهزاد تخم چی

Abstract Proper characterization of fracture reservoir is crucial for their sound development plan. It is however very difficult to correctly obtain various fracture reservoir properties such as permeability due to high order of heterogeneity and anisotropy within th More

Abstract Proper characterization of fracture reservoir is crucial for their sound development plan. It is however very difficult to correctly obtain various fracture reservoir properties such as permeability due to high order of heterogeneity and anisotropy within these reservoirs. Classical dual porosity and/or dual permeability models consider a regular fracture network across the reservoir. To improve the concept, we develop a numerical method for tonsorial permeability calculation of blocks with random/disordered fracture distribution. We considered a 2D Cartesian fine grid in which the fractures were defined explicitly with their endpoints coordinates. Applying proper boundary conditions, single phase flow is then solved. Full tensor permeability is then obtained analytically from the calculated flow and pressure fields. The result of our method is compared well with that of the analytical models for simple fracture systems. In addition we reported the permeability tensor values of random fracture networks where no analytical solution is available. Manuscript profile

Open Access Article

3 - A comprehensive study of shale intervals of Burgan Formation: implications for borehole stability
Mohammad سلیمانی سعیده رعیت دوست

20.1001.1.22518738.1392.3.6.7.9

Abstract 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 More

Abstract 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

4 - Making the lithology log by Clustering-Estimation approach in the wells of an oil field in south of Iran
ساره صدیق مهرنوش علی پور شهسواری حسین معماریان بهزاد تخم چی

20.1001.1.22518738.1392.3.5.3.3

Abstruct Reservoir lithology determination is one of the main studies used for well correlation and analyzing productive zones of the reservoir. The best way foer lithology determination is using core and cutting information . Nevertheless,in most More

Abstruct Reservoir lithology determination is one of the main studies used for well correlation and analyzing productive zones of the reservoir. The best way foer lithology determination is using core and cutting information . Nevertheless,in most wells these data is not complete and continual, so in these cases usually use well logging for lithology estimation of petrophysical well data with Clustering- Estimation approach . This method has been generalized according to one well from one of the oil fields in South of Iran that contains core data . Then this method is generalized in un cored wells. Clustering is used as a way for grouping well data in homogenous lithology clusters After ward, percentage of mineral is estimated in each of these clusters. The regression coefficients are calculated 92.93% and 74.99% between real and estimated data respectively for calcite and dolomite in one of the wells. The results with high accuracy show the generalization of this method. Manuscript profile

Open Access Article

5 - Using hyperion hyperpectral data and field spectrometry for identification of hydrocarbon leakagesvia VISA-SCM combined methodology and spatial data mining
Mohammad حمزه علی درویش بلورانی سید کاظم علوی پناه فروغ بیک حسین نصیری

20.1001.1.22518738.1392.3.5.5.5

The hydrocarbon seepages theory puts forward a cause and effect relation ship between the oil and gas reservoir s and the specific surface anomalies which are basically related to hydrocarbon leakages as well as their related alterations. Hence,the s More

The hydrocarbon seepages theory puts forward a cause and effect relation ship between the oil and gas reservoir s and the specific surface anomalies which are basically related to hydrocarbon leakages as well as their related alterations. Hence,the spectral reflectance of the hydrocarbons and their linked mineral alterntions produce credible pieces of evidence for oil and gas ex ploration .Hyperion images of EO-1 satellite was used in this study for identifying the oil seepages and their relevant alterations. After collecting the required data,the images under went the needed preprocessing. In order to recognize the oil seepages, these corrected data along with field-sampled spectrometric ones were employed. Then, VISA and SCM combined model was applied to indirectly identify the hydrocarbon seepages . Moreover, two hydrocarbon indexes were developed for direct recognition of the hydrocarbon seeps using Hyperion images. The finding indicate that the two mentioned techniques are efficacious for the purpose of the study at hand Manuscript profile

Open Access Article

6 - Klinkenberg Permeability Prediction by Using Absolute Gas Permeability in Carbonate Hydrocarbon Reservoir Rocks of South-West of
حمید شریفی گلویک

20.1001.1.22518738.1391.2.4.6.7

Permeability is one of the main parameters in the study of hydrocarbon reservoirs which are needed to be measured correctly. The conventional methods are well testing and direct permeability measurement on the drilled core samples. Absolute air permeability of core p More

Permeability is one of the main parameters in the study of hydrocarbon reservoirs which are needed to be measured correctly. The conventional methods are well testing and direct permeability measurement on the drilled core samples. Absolute air permeability of core plug samples is often measured in the laboratory which is cheap and fast. The absolute air permeability of a rock sample depends on the flowing mean pressure and type of gas and varies with changing them. Hence, measuring liquid permeability of fully saturated core sample or determination of corrected gas permeability which is equivalent to the liquid permeability is essential. This needs to spend enough time and budget. Klinkenberg investigated the effect of gas slippage in porous media and measured absolute permeability of different gases in various mean pressures. He yielded an equation for correcting absolute gas permeability and defining equivalent liquid permeability. The aim of this study was to present some practical relations for determining Klinkenberg corrected gas permeability of carbonate rocks by using their absolute air permeability, which has not been reported yet. For this purpose, Klinkenberg corrected gas permeability of 541 core plugs, with various petrophysical properties from different carbonate formations in the Southwest of Iran was measured. Exponential relations were obtained with very good correlation coefficients. Considering vast petrophysical properties of the studied samples, the yielded equations can be used to predict and determine equivalent liquid permeability of carbonate core samples of Southwest of Iran from their absolute air permeability Manuscript profile

Open Access Article

7 - Comparative study between Rock-Eval pyrolysis and biomarkers parameters: A case study of Horn Valley Siltstone source rock in central- Australia
مهدی شیری سید رضا موسوی حرمی محمد رضا رضائی

20.1001.1.22518738.1391.2.4.7.8

In this study 44 Sedimentary rock samples from the Amadeus Basin, in southern portion of the Northern Territory, Australia, were analyzed by two well-proven organic geochemical methods: Rock-Eval (RE) pyrolysis and gas chromatography–mass spectrometry (GC–MS) analysis. More

In this study 44 Sedimentary rock samples from the Amadeus Basin, in southern portion of the Northern Territory, Australia, were analyzed by two well-proven organic geochemical methods: Rock-Eval (RE) pyrolysis and gas chromatography–mass spectrometry (GC–MS) analysis. These techniques were used to obtain independent parameters on organic matter composition, its thermal maturity, and environment of deposition. This study reveals a close concordance between Rock-Eval pyrolysis data and polycyclic biomarkers parameters such as steranes. RE pyrolysis in conjunction with GC–MS analysis show that the Amadeus Basin sediments contain a variable but notable organic-rich facies in the Horn Valley siltstone and prove an unequivocal evidence for Type-II organic matter, which lies dominantly to the peak stage of the conventional oil window (end of diagenesis-middle of catagenesis). The case study from the Amadeus Basin shows that these methods remain undoubtedly suitable for a good assessment of the petroleum potential of source rocks and rapid geochemical characterization of sedimentary organic matter, and can be used in other similar basins. Manuscript profile

Open Access Article

8 - Application of Kuster and Toksoz equations in inverse modeling technique to estimate the percentages of pore types in carbonate rocks
اصغر نادری مصطفی حیدری ایرج مداحی ناصر کشاورز فرج خواه

20.1001.1.22518738.1391.2.3.1.0

The most prominent parameter of seismic studies is seismic wave velocity. This parameter is influenced by different factors such as rock properties (Compaction, age, Lithology, Porosity, Pore Shape and etc), fluid properties (Viscosity, Density, fluid type, Saturation) More

The most prominent parameter of seismic studies is seismic wave velocity. This parameter is influenced by different factors such as rock properties (Compaction, age, Lithology, Porosity, Pore Shape and etc), fluid properties (Viscosity, Density, fluid type, Saturation) and environment (Stress history, Depositional environment, production history, temperature, pressure, etc). Therefore, by identification, study and investigation of the relationship between seismic velocity and these parameters, properties of rock, fluid and environment from seismic data can be inferred. The main factors affecting these parameters are the porosity and pore ambiences. Many studies have been conducted to obtain and understand these relations. Most of the theoretical equations haven’t considered changes in seismic properties from pores. Therefore, the seismic inversion, AVO and pore volume calculated based on these equations, include much uncertainties. One of the equations that consider several factors such as porosity, pore type, mineralogy and pore fluid is provided by Kuster and Toksoz. In this study, using this equation and inverse modeling technique, geometry and pore type and percentage of any type of pore shape in 3 wells penetrated one Irainain hydrocarbon reservoir were estimated. In this reservoir, Spherical and Disk shape have the highest percentage. Manuscript profile

Open Access Article

9 - Petrophysical evaluation and determination of reservoir rock types in the Ghar member,the Abouzar oilfield, Persian Gulf.
مهرناز نصیری محمدرضا رجلی نوده

20.1001.1.22518738.1391.2.3.3.2

This study is aimed at petrophysical evaluation of the Ghar reservoir using Multimin method by Geolog software in five wells from the Abouzar oilfield. For this purpose, well log data comprising of neutron, density, sonic, gamma, resistivity and photoelectric absorption More

This study is aimed at petrophysical evaluation of the Ghar reservoir using Multimin method by Geolog software in five wells from the Abouzar oilfield. For this purpose, well log data comprising of neutron, density, sonic, gamma, resistivity and photoelectric absorption were utilized and their analysis lead to determination of quantitative petrophysical properties such as porosity, volume of shale, water, oil saturation and qualitative parameters including lithology and clay mineral types. The analyses revealed that three zones could be identified in the Ghar reservoir. Meanwhile, there are three shaly interlayers within the Ghar foemation. By application of the cutoff values on oil in place (OIP), petrophysical properties were determined zone by zone and based on Net to Gross ratio (N/G) high reservoir quality zone was identified. Finally by using clustering algorithm, reservoir rock types were identified based upon six properties including density, neutron, gamma ray, volume of shale, water saturation and effective porosity. The facies were introduced on the basis of their priority in reservoir quality so that there is an agreement between petrophysical evaluation results and electrofacies. General lithology of the reservoir in composed of upper loose sands and consolidated sand in the lower part. The lower sands are consolidated by the calcite cement. Overall, the volume of clay minerals in the lower part is less than that of upper part. However, productive zones were separated by a thin shaly layer. The clay minerals type in the shaly layer differs from those present in the reservoir rocks. Total and effective porosity are almost identical which is due to low volume of shale. Manuscript profile

Open Access Article

10 - Porosity modeling in Azadegan oil field: a comparative study of Bayesian theory of data fusion, multi layer neural network, and multiple linear regression techniques
عطیه مظاهری طرئی حسین معماریان بهزاد تخم چی بهزاد مشیری

20.1001.1.22518738.1391.2.3.4.3

Porosity parameter is an important reservoir property that can be obtained by studying the well core. However, all wells in a field do not have a core. Additionally, in some wells such as horizontal wells, measuring the well core is practically impossible. However, for More

Porosity parameter is an important reservoir property that can be obtained by studying the well core. However, all wells in a field do not have a core. Additionally, in some wells such as horizontal wells, measuring the well core is practically impossible. However, for almost all wells, log data is available. Usually these logs are used to estimate porosity. The porosity value obtained from this method is influenced by factors such as temperature, pressure, fluid type, and amount of hydrocarbons in shale formations. Thus it is slightly different from the exact value of porosity. Thus, estimates are prone to error and uncertainty. One of the best and yet most practical ways to reduce the amount of uncertainty in measurement is using various sources and data fusion techniques. The main benefit of these techniques is that they increase confidence and reduce risk and error in decision making. In this paper, in order to determine porosity values, data from four wells located in Azadegan oil field are used. First, multilayer neural network and multiple linear regressions are used to estimate the values and then the results of these techniques are compared with a data fusion method (Bayesian theory). To check if it would be possible to generalize these three methods on other data, the porosity parameter of another independent well in this field is also estimated by using these techniques. Number of input variables to estimate porosity in both the neural network and the multiple linear regressions methods is 7, and in the data fusion technique, a maximum of 7 input variables is used. Finally, by comparing the results of the three methods, it is concluded that the data fusion technique (Bayesian theory) is a considerably more accurate technique than multilayer neural network, and multiple linear regression, when it comes to porosity value estimation; Such that the results are correlated with the ground truth greater than 90%. Manuscript profile

Open Access Article

11 - Secondary porosity index effect on improving approaches permeability estimation from petrophysical logs utilizing artificial intelligent
سجاد کاظم شیرودی مرتضی خانیان

20.1001.1.22518738.1391.2.3.5.4

Abstract Permeability estimation using core data and petrophysical logs is a conventional approach which bears high uncertainty especially in carbonate reservoir characterization. In essence, the problem consists not only due to coring expenses rate, but also ambig More

Abstract Permeability estimation using core data and petrophysical logs is a conventional approach which bears high uncertainty especially in carbonate reservoir characterization. In essence, the problem consists not only due to coring expenses rate, but also ambiguity in finding proper explicit log correlation to core data. Moreover, utilizing the correlated formula in wells without core data can pose errors. In this research the permeability was estimated from conventional petrophysical logs and it was calibrated with permeability obtained from core lab experiments. Applied intelligent systems are the matter of this research for permeability values estimation. To construct permeability estimation model, three techniques have been applied including conventional ANN, the Gonzalez, and Hambalek fuzzy logic techniques. These methods were applied in two wells drilled in Surmeh reservoir in Balal field to establish ANN and to derive a relation between core and well. The models were applied in control well in order to check the reliability and capability of models to estimate representative permeability value. The result showed however three foresaid techniques for permeability estimation were successful the secondary porosity distributed the correlation due to its reduction effect on permeability so that they were not interconnected. Therefore this effect was omitted using secondary porosity index in which the permeability estimation were improved and were estimated close to core value. Manuscript profile

Open Access Article

12 - Determining Geological, Environmental and Economical Impact Weight for Oil Field Prioritization to Implement Smart Well Technology
تورج بهروز سید مهدیا مطهری مهدی ندری پری

20.1001.1.22518738.1391.2.3.6.5

Deep oil reservoirs with high heterogeneity need thorough management to maximize production and recovery along with minimizing OPEX and CAPEX. This management is integration between technology, human resource and processes. Smart Well technology helps oil companies t More

Deep oil reservoirs with high heterogeneity need thorough management to maximize production and recovery along with minimizing OPEX and CAPEX. This management is integration between technology, human resource and processes. Smart Well technology helps oil companies to meet aforementioned goals. Since smart well technology imposes high initial expenditure it is a risky and costly decision for oil companies to apply it for all companies. Indeed, this fact dictates prioritization of oil fields based on several parameters to decide where this technology should be implemented first. In this paper we present a novel screening technique under Analytical Hierarchy Process (AHP) engine. This technique needs criteria and sub-criteria affecting smart well potential of fields such as Geological, Geographical, Environmental and Economical parameters. In this study, the main components of the four main mentioned parameters have been extracted. All of them weighted according to our objective function. The result of this research would be impact weight of each parameter with respect to each other that can be used an engineering box for making decision among several fields for implementing smart well technology. Manuscript profile

Open Access Article

13 - Geochemical Investigation and Mineral Matrix Effect on Probable Source Rock's Potentiality, Darquain Oilfield in the Abadan Plain
بهرام علیزاده نسیم آزاد بخت سید حسین حسینی الهام ترهنده

20.1001.1.22518738.1391.2.3.7.6

Darquain anticline is located at 5 km northeast of city of Abadan. The axis trend of this oilfield is north through south. In this study, Kazhdumi, Gadvan, Garu and Sargelu Formations in Darquain Oilfield, in Abadan Plain, were analyzed by Rock-Eval 6 instrument. S2 v More

Darquain anticline is located at 5 km northeast of city of Abadan. The axis trend of this oilfield is north through south. In this study, Kazhdumi, Gadvan, Garu and Sargelu Formations in Darquain Oilfield, in Abadan Plain, were analyzed by Rock-Eval 6 instrument. S2 vs. TOC plot revealed that kerogen type in this oilfield predominantly is of mixed of types II & III. Significant S2 Adsorption by matrix of Kazhdumi Formation in well numbers 1 and 2 (5.33-14.06 mg HC/gr rock) and Gadvan Formation in well numbers 2 and 3 (3.1-3.2 mg HC/gr rock) is due to low thermal maturity as well as low Gas-Oil Ratio factor. In Garu and Sargelu Formations amounts of adsorbed S2 by matrix are respectedly 0.82 and 0.84 mg HC/gr rock, that represent a medium thermal maturation and medium to high Gas-Oil Ratio factor. Quantity of TOClive in the Kazhdumi, Gadvan, Garu and Sargelu formations estimated to be in the range of 0.6-1.6, 0.2-1.9, 1.53 and 8.38 by weight percent respectively. This represents potential for the studied formations fair to excellent petroleum generation. Also the studied wells were modeled, by which the Ro of the source rocks were calculated according to their depth. Also transformation ratio of organic matter and the initial TOC is estimated. Transformation Ratio of Kerogen in studied formations ranges from 0.12 to 0.66. This is in accordance with estimated Easy Ro by PBM software (0.5-0.8). It can then be concluded that Kazhdumi Formation is in early oil window and already started to generate hydrocarbon. This is also verified by Tmax data. The Gas-Oil Ratio of Kazhdumi and Gadvan Formations is 0-1 indicating variable hydrocarbon generation. Also this factor for Garu and Sargelu is 0.58-1 indicates that they have more gas generation potential rather than oil generation potential. The inferences drawn from It can be inferenced from iso TOCoil and TOCgas maps led to the conclution that, in west and southwestern parts of the basin, the depth during deposition of mentioned formations was more in compare to other parts of Darquain. Manuscript profile

Open Access Article

14 - Estimation of relative permeability curves from capillary pressure data in one of iranian carbonate reservoir
بابک شعبانی عزت اله کاظم زاده

20.1001.1.22518738.1390.1.2.1.1

Relative 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 More

Relative 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

Open Access Article

15 - Geochemical analysis &petrophysical studies: An approach to clay minerals investigation of E member of Qom Formation, Sarajeh gas field
عباس دهکار سهیلا اصلانی

20.1001.1.22518738.1390.1.2.3.3

Geochemical and petrophysical studies on E member of Sarajeh Gas field shows presence of different type of clay minerals. Petrography studies along with XRD , SEM and EDX analysis on the present samples, indicate presence of Illite, Chlorite and expandable clay mine More

Geochemical and petrophysical studies on E member of Sarajeh Gas field shows presence of different type of clay minerals. Petrography studies along with XRD , SEM and EDX analysis on the present samples, indicate presence of Illite, Chlorite and expandable clay minerals. Expandable clays comprise, smectite and mixed layer or interstratified Illite/Smectite (I/S) minerals. Petrophsical studies show Th/K on NGS log in Sarajeh, well 12, composed mainly, Illite, chlorite with minor amount of interstratified Illite/Smectite (I/S). Geochemical studies confirm validity of petrophysical results. The presence of different clay minerals of Qom formation in E member, Sarajeh Gas field, may have significant impact on petrophysical properties of reservoir, and hence affect reservoir productivity as well as cause problem during drilling operations. Manuscript profile

Open Access Article

16 - Effect of multi-walled carbon nanotubes to improve hydrocarbon wells annular clearance space
Mohammad سلیمانی سعیده رعیت دوست

20.1001.1.22518738.1390.1.2.4.4

Proper drilling fluids has vital role for achieving to hydrocarbon reservoirs by using Drilling operation. Some important problems such as friction, stuck pipe, slow drilling rate, high torque and drag, lost of materials, density variation of mud can be happened due of More

Proper drilling fluids has vital role for achieving to hydrocarbon reservoirs by using Drilling operation. Some important problems such as friction, stuck pipe, slow drilling rate, high torque and drag, lost of materials, density variation of mud can be happened due of poor hole annulus and cuttings down falling that induce expensive drilling. Various drilling fluids have been widely used in the wells drilling to improve lifting capacity of drilled cuttings. In this paper, the experimental results have been studied that conducted on effect of Multiwall Carbon Nano tubes (MWNTs) as additives for lifting capacity of water based mud. The effect of Useful parameters such as amount of MWNTs used, cutting size and mud annular velocity on the drilling fluid cleaning capacity have been studied. The results show that lifted cuttings increase as the amount of MWNTs added increases. MWNTs associated with water based mud displays the stability against base mud since surface forces easily balance the gravity force and attached to drilled cuttings, resulting in increase of drag force acts to drilled cuttings and easily lifted cuttings to the surface. The MWNTs also will improve viscosity which will significantly increase carrying capacity of the mud. For small and medium cuttings, the improvement relatively simplified compare to the big cuttings. The impact will significantly Manuscript profile

Open Access Article

17 - Using information entropy theory and bayesian decision method to identify appropriate parameters for evaluating and discriminating oil facies (mansuri oil field, south of Iran)
حسین معماریان

20.1001.1.22518738.1390.1.2.6.6

Due to subsurface heterogeneity and existing vagueness in geophysical interpretation, identifying and interpretation of facies in wellbores is always prone to uncertainty and risk. Nowadays several methods have developed for quantitative facies interpretation. These met More

Due to subsurface heterogeneity and existing vagueness in geophysical interpretation, identifying and interpretation of facies in wellbores is always prone to uncertainty and risk. Nowadays several methods have developed for quantitative facies interpretation. These methods are generally divided into deterministic and stochastic categories. Deterministic methods, in spite of their simple modeling procedure, cannot expose the amount of error or accuracy of the model. On the other hand, stochastic methods, in addition to quantifying the error of the model, can provide the probability of the model’s accuracy in each point of the reservoir. The Bayesian approach is one of the stochastic methods that use conditional probabilities for modeling. This approach, as well as probabilistic modeling of hydrocarbon facies, quantitatively computes the effect of additional data in decreasing the error of the classification. Information entropy theory, by quantifying the intrinsic uncertainty in each model input parameter, can easily provide the selection of valuable parameters. The present study was carried out on one of the wells of Mansuri oil field, south of Iran. After generation of training data by using rock physics techniques and Gassmann’s relation, the value of each input parameter was identified by entropy analysis. Then, by use of Bayesian analysis and valuable parameters, oil facies classification and discrimination was implemented. The five optimum parameters were elastic impedance, compressional wave velocity, shear wave velocity, density and porosity .The amount of error in this method is approximated to be 11 percent. This investigation also showed that gamma ray parameter does not have a drastic positive effect on identification and discrimination procedure of oil facies, which has a good agreement with the results of entropy analysis . Manuscript profile

Open Access Article

18 - Geochemical evaluation of source rocks in the Kilur Karim oilfield, Southwest of Iran
هاشم صراف دخت

20.1001.1.22518738.1390.1.2.8.8

Kilorkarim oilfield is located in 40 Km North of the Persian Gulf and in the vicinity of Siah Makan, Golkhari, Bibi Hakeemeh oilfields. The present study focuses on geochemical evaluation of probable source rocks in this oilfield. For this purpose, source rock samples t More

Kilorkarim oilfield is located in 40 Km North of the Persian Gulf and in the vicinity of Siah Makan, Golkhari, Bibi Hakeemeh oilfields. The present study focuses on geochemical evaluation of probable source rocks in this oilfield. For this purpose, source rock samples that selected from three wells were evaluated using Rock-Eval pyrolysis and reconstruction of burial history modeling. The results show that organic matter of these source rocks are mostly a mixture of Kerogen types II and III. Also organic petrography study showed that Vitrinite, Detrovitrinite, Hominite and Fuzinite macerals in Pabdeh, Gurpi and Kazhdomi Formations, and reworked Bitumen in some sections of the Pabdeh Formation. Based on Vitrinite Reflectance measurments in well#1, Pabdeh and Gurpi Formations aren’t interred in oil window and Kazhdumi Formation interred in oil window. In well#2 Pabdeh and Gurpi Formations are in the beginning and in oil window, respectively. In well#4 Vitrinite Reflectance is emphasized the entrance of Kazhdumi Formation into oil window. Reconstruction of Burial history and thermal modeling was performed by PBM 1D software. Modeling showed that Pabdeh Formation in well #1 and 4a interred in oil window but the opposite is true for middle section of well #2. Because of more deposition of Aghajari Formation in the south part, oil window occurs in shallower depth and therefore the maturity is higher in the south toward north of the oilfield. Manuscript profile

Open Access Article

19 - Comparisons of intelligent systems and empirical equation results in permeability prediction: a case study in one of the southern Iranian carbonate reservoirs
الهام عزیز ابادی فراهانی مجتبی رجبی

Prediction of permeability that is one of the most important parameters in oil and gas reservoirs is probably the most challenging issue geologists, petrophysicists, and reservoir engineers have to deal with. This parameter control fluid flow in production stage. The mo More

Prediction of permeability that is one of the most important parameters in oil and gas reservoirs is probably the most challenging issue geologists, petrophysicists, and reservoir engineers have to deal with. This parameter control fluid flow in production stage. The most reliable data of permeability are taken from laboratory analysis of cores. Since coring is a costly and time consuming operation, researchers have tried to predict this parameter from other methods. Empirical equation is one of these methods, but results of these equations are not satisfied for all lithology and reservoirs. So far, several studies have been carried out for the estimation of reservoir parameters using intelligent systems. These studies indicate the successful role of these methods such as fuzzy logic, neuro-fuzzy and genetic algorithms for reservoir characterization. In this study, we try to compare results of these two methods (empirical equations and intelligent systems) for permeability prediction in a carbonate reservoir. For this purpose, petrophysical and core data of four well in a carbonate reservoir in the Southern Iran were used. At first, using empirical equations permeability was calculated for the test well; then using data of three wells, intelligent models were constructed. A forth well (test well) from the field was used to evaluate the models. The results show that fuzzy logic result (with R2= 0.88) is the best method for prediction of permeability in the studied reservoir. Also between empirical equations, result of Wyllie-Rose equation is better than others. Finally we offer the constructed fuzzy model (as a best predictor) for permeability prediction in the studied reservoir. Manuscript profile

Open Access Article

20 - Sedimentological studies and Petrophysical interpretation: An approach to reservoir characterization of Sarvak formation in the Dalpari oil field
علی اصغر عنایتی

The Ilam and Sarvak Formations of Bangestan Grouop are the second important potential reservoirs after Asmari formation in the zagros basin. Integration of petrographical factors and Petrophysical parameters resulted in better understanding of reservoir qualities of More

The Ilam and Sarvak Formations of Bangestan Grouop are the second important potential reservoirs after Asmari formation in the zagros basin. Integration of petrographical factors and Petrophysical parameters resulted in better understanding of reservoir qualities of these formations. In this study , 250 thin sections were collected and subjected to microfacies and petrography studies. As a result eight microfacies from three sedimentary environments were identified: Lagoonal (L1 ,L2 ,L3),Barrier (B1 ,B2) and Open marine (O1 ,O2 ,O3) and in three different of digenetic environments such as marine, meteoric and burial. This Study shows Sarvak Formation is being formed on Carbonate Rimmed shelf platform. Petrophysical interpretations by using of IP software shows Sarvak reservoir is divided into 3 zones (4, 5, 6). This study reveals that zone 4 contains the best reservoir quality in compare with the others by having (17m) oil column. porosity (more than 8%) and water saturation less than(14%) in this field. There is also decreasing of water saturation in Pay zone 4, but no significant changes has been observed through out zones 5&6. In zone 4, shale volume increases in zones 5&6 (Vsh more than 25%). Crossplot K-Th and K-Pe reveals that Chlorite_Montmorilonite are the dominant clay minerals in this reservoir. Manuscript profile

Open Access Article

21 - Biomarker study of Asmari Reservoir oil in the oil fields situated in N.E. Dezful Embayment
علیرضا بنی اسد

Masjid-e-Solyman, Haft kel, Par-e-Siah and Naft Safid are productive oil fields which are located in mountain front of NE Dezful Embayment. In this research, in order to Geochemical correlation and Petroleum Systems determination of Asmari oils, a few oil samples were s More

Masjid-e-Solyman, Haft kel, Par-e-Siah and Naft Safid are productive oil fields which are located in mountain front of NE Dezful Embayment. In this research, in order to Geochemical correlation and Petroleum Systems determination of Asmari oils, a few oil samples were subjected to biomarker studies by GC and GC-MS techniques. Review of biomarkers fingerprints indicate two petroleum systems probably are active in studied oilfields. A major petroleum system that has controlled the hydrocarbon generation, migration and accumulation in all studied oilfields and a younger petroleum system, which has caused mixture of oils with another source in Masjed-Soleyman and Par-e-Siah oilfields, Biomarkers fingerprints, Steranes, Hopanes in addition to the main petroleum system. parameters, Pristane to Phytane ratios and also n- alkane's distributions among the studied oils, indicate that the Asamri oils were produced mainly from a marine and marine-carbonate source rock(s), which has been deposited in an anoxic conditions, with kerogen mainly of Type II with little contribution of terrestrial Kerogen (Type III) and oil samples has a maturity about early oil window without any severe biodegradation. 13C isotope values distribution, presence of Oleannane biomarker and slightly differences - mainly from lithological aspects and maturation levels of oils - of Masjid-Soleyman and Par-e-Siah Oils, reveal that, the mixed oils in these two reservoirs have been probably produced from two source rocks, a younger source rock namely Pabdeh Formation (Middle Eocene and Early Oligocene) with less importance of Kazhdumi Formation (Albian) which is the main source rock Manuscript profile

Open Access Article

22 - Fractures systematic analysis Asmari reservoir Formation in the Marun oil field (based on image logs interpretation results)
فارسی مدان arsimadan

20.1001.1.22518738.1394.5.9.1.3

In the oil buildings to investigate fractures in the reservoir rock fractures in stages of production and field development is very important and necessary. Now application of software repository in the realization of this issue will help to petroleum with the geologist More

In the oil buildings to investigate fractures in the reservoir rock fractures in stages of production and field development is very important and necessary. Now application of software repository in the realization of this issue will help to petroleum with the geologists.. Marun oil field is one of the largest oil fields in the South West Iran of the city of Ahvaz in the Northeast and the North embayment Dezful of geology in the eastern. Marun field is the most important Asmari reservoir. The aim of this study was to investigate systematically Asmari reservoir fractures and the development of fractures in the reservoir. For this purpose, using image logs, best and most complete method interpretation and results of 11 wells in fracture studying and 16 wells in in-situ stress direction studying. According to frequency of fractures (based on image logs interpretation results) in the southern and north-eastern limb of the field, The theory of tectonic folding and bending events later caused the possible activities during the north-south strike-slip faults affect the compression force has been created to strengthen. Most of image logs data in Marun field are fractures with extensions; N155E, N130E, N95E, N60E, N30E. Manuscript profile

Open Access Article

23 - Comparisons of intelligent systems and empirical equation results in permeability prediction: a case study in one of the southern Iranian carbonate reservoirs
Amir Mola jan Hoseyn Memarian

20.1001.1.22518738.1390.1.1.1.9

Prediction of permeability that is one of the most important parameters in oil and gas reservoirs is probably the most challenging issue geologists, petrophysicists, and reservoir engineers have to deal with. This parameter control fluid flow in production stage. The mo More

Prediction of permeability that is one of the most important parameters in oil and gas reservoirs is probably the most challenging issue geologists, petrophysicists, and reservoir engineers have to deal with. This parameter control fluid flow in production stage. The most reliable data of permeability are taken from laboratory analysis of cores. Since coring is a costly and time consuming operation, researchers have tried to predict this parameter from other methods. Empirical equation is one of these methods, but results of these equations are not satisfied for all lithology and reservoirs. So far, several studies have been carried out for the estimation of reservoir parameters using intelligent systems. These studies indicate the successful role of these methods such as fuzzy logic, neuro-fuzzy and genetic algorithms for reservoir characterization. In this study, we try to compare results of these two methods (empirical equations and intelligent systems) for permeability prediction in a carbonate reservoir. For this purpose, petrophysical and core data of four well in a carbonate reservoir in the Southern Iran were used. At first, using empirical equations permeability was calculated for the test well; then using data of three wells, intelligent models were constructed. A forth well (test well) from the field was used to evaluate the models. The results show that fuzzy logic result (with R2= 0.88) is the best method for prediction of permeability in the studied reservoir. Also between empirical equations, result of Wyllie-Rose equation is better than others. Finally we offer the constructed fuzzy model (as a best predictor) for permeability prediction in the studied reservoir. Manuscript profile

Open Access Article

24 - Comparisons of intelligent systems and empirical equation results in permeability prediction: a case study in one of the southern Iranian carbonate reservoirs
الهام عزیز ابادی فراهانی Kazemzadeh Ezatolah ELham Aziz Abadi Farahani

Prediction of permeability that is one of the most important parameters in oil and gas reservoirs is probably the most challenging issue geologists, petrophysicists, and reservoir engineers have to deal with. This parameter control fluid flow in production stage. The mo More

Prediction of permeability that is one of the most important parameters in oil and gas reservoirs is probably the most challenging issue geologists, petrophysicists, and reservoir engineers have to deal with. This parameter control fluid flow in production stage. The most reliable data of permeability are taken from laboratory analysis of cores. Since coring is a costly and time consuming operation, researchers have tried to predict this parameter from other methods. Empirical equation is one of these methods, but results of these equations are not satisfied for all lithology and reservoirs. So far, several studies have been carried out for the estimation of reservoir parameters using intelligent systems. These studies indicate the successful role of these methods such as fuzzy logic, neuro-fuzzy and genetic algorithms for reservoir characterization. In this study, we try to compare results of these two methods (empirical equations and intelligent systems) for permeability prediction in a carbonate reservoir. For this purpose, petrophysical and core data of four well in a carbonate reservoir in the Southern Iran were used. At first, using empirical equations permeability was calculated for the test well; then using data of three wells, intelligent models were constructed. A forth well (test well) from the field was used to evaluate the models. The results show that fuzzy logic result (with R2= 0.88) is the best method for prediction of permeability in the studied reservoir. Also between empirical equations, result of Wyllie-Rose equation is better than others. Finally we offer the constructed fuzzy model (as a best predictor) for permeability prediction in the studied reservoir. Manuscript profile

Open Access Article

25 - Sedimentological studies and Petrophysical interpretation: An approach to reservoir characterization of Sarvak formation in the Dalpari oil field
Abolhasan Ahan kar Abolhasan Ahan kar

20.1001.1.22518738.1390.1.1.3.1

The Ilam and Sarvak Formations of Bangestan Grouop are the second important potential reservoirs after Asmari formation in the zagros basin. Integration of petrographical factors and Petrophysical parameters resulted in better understanding of reservoir qualities of t More

The Ilam and Sarvak Formations of Bangestan Grouop are the second important potential reservoirs after Asmari formation in the zagros basin. Integration of petrographical factors and Petrophysical parameters resulted in better understanding of reservoir qualities of these formations. In this study , 250 thin sections were collected and subjected to microfacies and petrography studies. As a result eight microfacies from three sedimentary environments were identified: Lagoonal (L1 ,L2 ,L3),Barrier (B1 ,B2) and Open marine (O1 ,O2 ,O3) and in three different of digenetic environments such as marine, meteoric and burial. This Study shows Sarvak Formation is being formed on Carbonate Rimmed shelf platform. Petrophysical interpretations by using of IP software shows Sarvak reservoir is divided into 3 zones (4, 5, 6). This study reveals that zone 4 contains the best reservoir quality in compare with the others by having (17m) oil column. porosity (more than 8%) and water saturation less than(14%) in this field. There is also decreasing of water saturation in Pay zone 4, but no significant changes has been observed through out zones 5&6. In zone 4, shale volume increases in zones 5&6 (Vsh more than 25%). Crossplot K-Th and K-Pe reveals that Chlorite_Montmorilonite are the dominant clay minerals in this reservoir. Manuscript profile

Open Access Article

26 - Biomarker study of Asmari Reservoir oil in the oil fields situated in N.E. Dezful Embayment
Mahmud Memariani Ali reza Bani asad

20.1001.1.22518738.1390.1.1.4.2

Masjid-e-Solyman, Haft kel, Par-e-Siah and Naft Safid are productive oil fields which are located in mountain front of NE Dezful Embayment. In this research, in order to Geochemical correlation and Petroleum Systems determination of Asmari oils, a few oil samples were s More

Masjid-e-Solyman, Haft kel, Par-e-Siah and Naft Safid are productive oil fields which are located in mountain front of NE Dezful Embayment. In this research, in order to Geochemical correlation and Petroleum Systems determination of Asmari oils, a few oil samples were subjected to biomarker studies by GC and GC-MS techniques. Review of biomarkers fingerprints indicate two petroleum systems probably are active in studied oilfields. A major petroleum system that has controlled the hydrocarbon generation, migration and accumulation in all studied oilfields and a younger petroleum system, which has caused mixture of oils with another source in Masjed-Soleyman and Par-e-Siah oilfields, Biomarkers fingerprints, Steranes, Hopanes in addition to the main petroleum system. parameters, Pristane to Phytane ratios and also n- alkane's distributions among the studied oils, indicate that the Asamri oils were produced mainly from a marine and marine-carbonate source rock(s), which has been deposited in an anoxic conditions, with kerogen mainly of Type II with little contribution of terrestrial Kerogen (Type III) and oil samples has a maturity about early oil window without any severe biodegradation. 13C isotope values distribution, presence of Oleannane biomarker and slightly differences - mainly from lithological aspects and maturation levels of oils - of Masjid-Soleyman and Par-e-Siah Oils, reveal that, the mixed oils in these two reservoirs have been probably produced from two source rocks, a younger source rock namely Pabdeh Formation (Middle Eocene and Early Oligocene) with less importance of Kazhdumi Formation (Albian) which is the main source rock. Manuscript profile

Open Access Article

27 - Fractures systematic analysis Asmari reservoir Formation in the Marun oil field (based on image logs interpretation results)
Zahra Kamali Mohammad reza Mahdevar meysam farsi madan

In the oil buildings to investigate fractures in the reservoir rock fractures in stages of production and field development is very important and necessary. Now application of software repository in the realization of this issue will help to petroleum with the geologi More

In the oil buildings to investigate fractures in the reservoir rock fractures in stages of production and field development is very important and necessary. Now application of software repository in the realization of this issue will help to petroleum with the geologists.. Marun oil field is one of the largest oil fields in the South West Iran of the city of Ahvaz in the Northeast and the North embayment Dezful of geology in the eastern. Marun field is the most important Asmari reservoir. The aim of this study was to investigate systematically Asmari reservoir fractures and the development of fractures in the reservoir. For this purpose, using image logs, best and most complete method interpretation and results of 11 wells in fracture studying and 16 wells in in-situ stress direction studying. According to frequency of fractures (based on image logs interpretation results) in the southern and north-eastern limb of the field, The theory of tectonic folding and bending events later caused the possible activities during the north-south strike-slip faults affect the compression force has been created to strengthen. Most of image logs data in Marun field are fractures with extensions; N155E, N130E, N95E, N60E, N30E Manuscript profile

Open Access Article

28 - Fractures systematic analysis Asmari reservoir Formation in the Marun oil field (based on image logs interpretation results)
meysam farsi madan Mohammad reza Mahdevar Zahra Kamali

20.1001.1.22518738.1394.5.9.2.4

In the oil buildings to investigate fractures in the reservoir rock fractures in stages of production and field development is very important and necessary. Now application of software repository in the realization of this issue will help to petroleum with the geologi More

In the oil buildings to investigate fractures in the reservoir rock fractures in stages of production and field development is very important and necessary. Now application of software repository in the realization of this issue will help to petroleum with the geologists.. Marun oil field is one of the largest oil fields in the South West Iran of the city of Ahvaz in the Northeast and the North embayment Dezful of geology in the eastern. Marun field is the most important Asmari reservoir. The aim of this study was to investigate systematically Asmari reservoir fractures and the development of fractures in the reservoir. For this purpose, using image logs, best and most complete method interpretation and results of 11 wells in fracture studying and 16 wells in in-situ stress direction studying. According to frequency of fractures (based on image logs interpretation results) in the southern and north-eastern limb of the field, The theory of tectonic folding and bending events later caused the possible activities during the north-south strike-slip faults affect the compression force has been created to strengthen. Most of image logs data in Marun field are fractures with extensions; N155E, N130E, N95E, N60E, N30E. Manuscript profile

Open Access Article

29 - Three-dimensional geological modeling in two zones of eastern side of Ahvaz oil field
Razeyeh . Doosti Irani Maryam Payrovi Mohammad .rahim karimi Mehdi . Doosti Irani

20.1001.1.22518738.1394.5.9.3.5

The 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 More

The 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

30 - Electro-facies analysis of the Sarvak Formation (Middle Cretaceous) and compliance with sedimentary microfacies in an oil field, SW Iran.
zahra Eghbalkiani Taher Goli ALI HOSSEIN JALILIAN Rahym Kadghodaii

20.1001.1.22518738.1395.6.11.5.8

Electro-facies analysis is a sure method in clustering petrophysical logs analysis that can well indicates the changes of geologic charactereristics of the different lithostratigraphic units as well. Petrographic studies of 120 prepared thin sections of the upper parts More

Electro-facies analysis is a sure method in clustering petrophysical logs analysis that can well indicates the changes of geologic charactereristics of the different lithostratigraphic units as well. Petrographic studies of 120 prepared thin sections of the upper parts of the Sarvak Formation in studied oilfield, Southwestern Iran, has resulted in definition of 6 microfacies sedimentary types. These data suggested that the middle Creataceous sediments in the studied area were predominantly deposited in two subenviornments of patch organic barrier and lagoon corresponding to inner and shallow a homoclinal ramp. In addition, using petrophysical logs in the studied well, 10 electrical facies were determined. By analyzing the data petrophysical in Geolog software, 10 electerical facies were optimized and then their number was reduced to six. According to good adaptation of optimized electerical facies with sedimentary microfacies, we would generalized obtained dresults to all parts of the Sarvak Formation. Study of porosity changes in the electrical diagrams such as CGR corrected Gamma, and sonic curves in mentioned well, indicated a significant reduction in facies porosity of 1 to 6. In addition, the results showed that the reservoir quality reductionin studied microfacies is corresponded to Bioclastic Rudist debris floatstone/ Rudstone, Benthic foraminifera Rudist debris wackestone / packstone, Benthic Foraminifera peloid Grainstone/Packstone, with High diversity benthic foraminifera wackestone / packstone, Peloid bioclastic wackestone /packstone with Low diversity benthic Foraminifera and Mudestone/Wackestone, respectively. In this study, we concluded that comparison and correlation sedimentary facies with electric microfacies provide an efficient method to study the quality of the hydrocarbon reservoir system that especially can be used in other wells with no core. Manuscript profile

Open Access Article

31 - Genetic classification of the Persian Gulf Eastern part oil fields by infrared spectroscopy of asphaltene samples
Morteza Taherinezhad Morteza Asemani Ahmad reza Rabbani

20.1001.1.22518738.1395.6.12.5.0

Asphaltene 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 More

Asphaltene 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

32 - Origin of seeping hydrocarbon gases from onshore mud volcanoes in Makran coast of Iran
Mahin Farhadian Babadi Behzad Mehrabi Adriano Mazzini Elena Poludetkina Ata Shakeri

20.1001.1.22518738.1395.6.12.6.1

Mud volcanoes are geological structures formed as a result of gas emission, mud-fluid mixing and variably sized rock fragments in onshore and offshore settings. These structures are different morphologically which considered as significant marker of modern crustal movem More

Mud volcanoes are geological structures formed as a result of gas emission, mud-fluid mixing and variably sized rock fragments in onshore and offshore settings. These structures are different morphologically which considered as significant marker of modern crustal movement and neotectonic activity. Occurrence of numerous mud volcanoes on the Makran accretionary prisms in Iran and Pakistan are reported which caused by the convergence of the Arabian and the Eurasian plates. In this study, origin of discharged hydrocarbon gases from three active onshore mud volcanoes; Ain, Borborok and Sand Mirsuban in Makran coasts of Iran were examined. The released gases of all these mud volcanoes are dominantly methane with concentration between 97.24-99.18 vol. % and minor amount of ethane (0.04-1.2 vol.%), propane (0.001-0.194 vol.%), n-butane (226 ppmvol.%), iso-butane (5-363 ppmvol.%), n-pentane (37ppmvol.%), iso-pentane (1-66 ppmvol.%), hexane (1-78 ppmvol.%) and CO2 (0.07-0.4 vol.%). Carbon and hydrogen isotope ratio of methane and its heavier derivatives indicate thermogenic source for emitted gases of all investigated mud volcanoes and evidences of the absence of biodegradation. CO2 with carbon isotope ratio of -11.1 to -14.3‰ is organic in origin. Our research suggests the presence of hydrocarbon system and active source rock in Makran active tectonic area. Although the occurrence of an exploitable gas reservoir in this area has to be confirmed by geophysical measurements, geological survey and structural settings. Manuscript profile

Open Access Article

33 - Geochemical characterization and evaluation of the hydrocarbon potential of Gurpi in a number of fields Located in North West of Persian Gulf
MohhamadReza Kamali محمود معماریانی Ehsan Hosseni Arezoo Karami

20.1001.1.22518738.1396.7.13.2.6

The results obtained from Rock-Eval pyrolysis and measurement of TOC showe that Gourpi and Pabdeh formations in Binak well show that Source rock does not have the sufficient organic material to produce hydrocarbons. However,Gourpi and Pabdeh in formations Hendijan and More

The results obtained from Rock-Eval pyrolysis and measurement of TOC showe that Gourpi and Pabdeh formations in Binak well show that Source rock does not have the sufficient organic material to produce hydrocarbons. However,Gourpi and Pabdeh in formations Hendijan and Doroud wells support the organic material to produce hydrocarbons and are placed in a more appropriate stage in terms of production. Samply from Binak Lack Contamiaton and or staining Lokite Source rock Samples from Hendigan and Doroud wells show contamination and Staining to migration from other interuals. Source rock show type II taype II-III in Binak and which the samples are n ot fully matured (the end of diagenesis) and the Kerogen for Source rock type of in Hendijan and Doroud wells is II and II-III respectively traversing maturing pathway by reaching catagenesis stage and reaching at the beginning of oil generation window. In terms of the type of organic matter, most in studay wells are located in oil zone and the maximum production potential is associated with Doroud well Location so that it could serves as a production source rock. Although, the Hendijan well have high yield potential, due to failure to reach to oil generation window it fails in producing oil. Sedimentation in the Binak well is done quickly and in oxidized condition and OM preserved partially. The Hendijan and Doroud wells show medium sedimentation in restricted condition and quick sedimentation in oxidizing environment respectively indicating Marine depositinal environment Manuscript profile

Open Access Article

34 - Simulation of porosity and permeability reservoir parameters by using Co-Sequential Gaussian Simulation method in one of the oil field in the South West of Iran
Bahareh Fereidooni Mohammad Mokhtari

20.1001.1.22518738.1396.7.13.3.7

Three-dimensional study of petrophysical parameters of hydrocarbon reservoirs such as porosity and permeability is considered as an efficient and effective tool for comprehensive study of reservoirs as well as reservoir management. In this study, which was carried out o More

Three-dimensional study of petrophysical parameters of hydrocarbon reservoirs such as porosity and permeability is considered as an efficient and effective tool for comprehensive study of reservoirs as well as reservoir management. In this study, which was carried out on one of the oil fields in the southwest of Iran, the aim is to simulate the petrophysical parameters of effective porosity and permeability by using Co-Sequential Gaussian Simulation in part of Khatiyah reservoir. With this simulation, a three-dimensional model of petrophysical reservoir parameters can be presented which is important for simulating fluid flow and identifying areas that are prone with higher reservoir quality. For this purpose, effective porosity and permeability logs of seven wells with 3D seismic data and seismic inversion results have been used. After reservoir gridding and creating a structural model, up scaled petrophysical data has entered to model and its own cell. For three-dimensional distribution of effective porosity parameter, due to the correlation of effective porosity and acoustic impedance attribute of seismic inversion, 3D seismic data and up scaled effective porosity logs as the initial data and acoustic impedance attribute of seismic inversion as secondary data have entered in Sequential Gaussian Simulation. In order to simulate permeability, due to the good correlation between effective porosity simulation model and permeability log, simulated porosity as a secondary data and up scaled permeability and 3D seismic data as secondary data have been used. The results of validation indicate the accuracy of the present study and the efficiency of Sequential Gaussian Simulation method in effective porosity and permeability modeling in this reservoir. Manuscript profile

Open Access Article

35 - A case study of carbonate reservoir permeability determination using NMR log in one of the southwestern fields of Iran
Bahram Habibnia

20.1001.1.22518738.1396.7.13.4.8

Permeability is one of the most important parameters for characterization of hydrocarbon reservoirs that has a basic role in almost all of the petroleum engineering problems. Determination of reservoir permeability is usually done in core laboratories in a time consumin More

Permeability is one of the most important parameters for characterization of hydrocarbon reservoirs that has a basic role in almost all of the petroleum engineering problems. Determination of reservoir permeability is usually done in core laboratories in a time consuming process. In the well test, the obtained average permeability is related to the drainage area. Due to cost, these two methods are not performed in the all wells, whereas well logging tools are generally performed in all wells. With progress of well logging tools, some researchers tried to estimate permeability from special well logs such as NMR directly. The data obtained from NMR was used as lithology independent data to estimate the water saturation and porosity, and also for analysis of pore space. One of the important parameters obtained from NMR is the transversal relaxation time (T2). In this work, NMR log measurement in a carbonate field was used to estimate the permeability using Timur, SDR and regression models. The results of the methods were compared against core permeability. The results show that SDR method is more accurate with the accuracy of 44.1% and the error of 23.12%. Manuscript profile

Open Access Article

36 - Improve the detection of buried channel, using Artificial Neural Networks and seismic attributes
Alireza Ghazanfari Abdolrahim Javaherian Mojtaba Seddigh Arabani

20.1001.1.22518738.1396.7.14.2.8

Channels are one of the most important stratigraphic and morphological events. If channels place in a suitable position such as enclosed in impermeable place can make suitable oil and gas reservoir; So identifying channels are crucial. Different tools such as filters, s More

Channels are one of the most important stratigraphic and morphological events. If channels place in a suitable position such as enclosed in impermeable place can make suitable oil and gas reservoir; So identifying channels are crucial. Different tools such as filters, seismic attributes, artificial neural networks, and meta-attributes have played an important role in this regard. In this paper dip-steering cube, dip-steer median filter, dip-steer diffusion filter, and fault enhancement filter, have been used. Then, various seismic attributes such as similarity, texture, spectral decomposition, energy and polar dip have been defined and studied. Therefore, work on F3 real seismic data of Dutch part of the North sea for detecting channels has been started by detecting suitable attributes. For identifying the channel in data, it has been used from compilation and combination of seismic attributes using supervised ANN (multi-layer perceptron), and development of mata-attributes, then recombine meta-attributes created along the channel, and using different interpretation point, for eliminating the impact of facies and lithology changes along the channel. Among the advantages and the reasons for using this kind of neural network (supervised), which increases the effect of the neural network and improves the result, is the ability to train the network by specifying the channel and non-channel points used in this paper. Finally, using the above methods, the identification of the channel examined in the above seismic data has been improved, and the channel has been properly detected and extracted throughout its entire length. Manuscript profile

Open Access Article

37 - Facies, thickness variations and reservoir characterisation of Arab formation (Surmeh) in the Eastern part of the Persian Gulf
Ali reza Bashari

20.1001.1.22518738.1396.7.14.3.9

The Kimmerigian-Tithonian) Arab Zone are the prolific hydrocarbon bearing resrvoirs in the eastern part of the Persian Gulf,offshore,Iran.They were deposited in an arid climate which dominate during late Jurassic. The Berriasian to Thitonian Hith formation wich o More

The Kimmerigian-Tithonian) Arab Zone are the prolific hydrocarbon bearing resrvoirs in the eastern part of the Persian Gulf,offshore,Iran.They were deposited in an arid climate which dominate during late Jurassic. The Berriasian to Thitonian Hith formation wich overlies the Arab reservoir constitutes the cap rock,wich just to the east gradually pinches out and form a N-S feather adge. The study reveals that Arab zones form a massive to interbedded anhydrite with varying proportion of limestone and dolomite and generally have regressive units which was deposited on a broad carbonate platform .This formations are thick in center (Salman field) and mostly consist of intertidal pack/grainstones with high porosity/permeability,good cap rock and also close to the source rock,which has the most hydrocarbon potential, but towards east the layers getting thinner with unsuitable cap rock and are away from source rock ,so as a result Arab formation in this part of the Persian Gulf doesn,t seem to be attractive. This study reveals that there is still some undrilled structure within this area which could be attractive for further Exploration drilling. Manuscript profile

Open Access Article

38 - 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 Larki

20.1001.1.22518738.1396.7.14.4.0

The 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 More

The 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

39 - Biostratigraphy and microfacies of the Asmari Formation in Lar anticline (northeast of Gachsaran): biostratigraphical correlation
Meysam Barari Kharkeshi Ali Seyrafian Hossein Vaziri-Moghaddam Roohollah Shabafrooz

20.1001.1.22518738.1396.7.14.5.1

The Asmari Formation at the Lar anticline, located 77 km northeast of Gachsaran city, comprised 361 meters in thickness. In the present study, biostratigraphy and microfacies of the Asmari Formation at the Lar anticline (northeast of Gachsaran city) is investigated. Bas More

The Asmari Formation at the Lar anticline, located 77 km northeast of Gachsaran city, comprised 361 meters in thickness. In the present study, biostratigraphy and microfacies of the Asmari Formation at the Lar anticline (northeast of Gachsaran city) is investigated. Based on foraminiferal distribution, 25 genera and 21 species have been identified and four biozones: 1. Lepidocyclina – Operculina – Ditrupa assemblage zone, 2. Archaias asmaricus – Archaias hensoni – Miogypsinoides complanatus assemblage zone, 3. Indeterminate zone, 4. Borelis melo curdica – Borelis melo melo assemblage zone, representing Oligocene (Chattian) to Early Miocene (Aquitanian - Burdigalian) are introduced, respectively. 12 microfacies related to an open marine and lagoon (semi-closed and closed) environments of homoclinal ramp setting are present. Manuscript profile

Open Access Article

40 - Biostratigraphy and microfacies of the Asmari Formation in north flank of Khami anticline (north of Gachsaran)
Mona Rahim Abadi Hossein Vaziri-Moghaddam Ali Seyrafian farzad Sotohian

20.1001.1.22518738.1397.8.16.1.8

In the present study, biostratigraphy, microfacies and sedimentary environment of the Asmari Formation in north flank of the Khami anticline in the north of the Gachsaran province is investigated. The Asmari Formation at the study section with a thickness of 276 meters More

In the present study, biostratigraphy, microfacies and sedimentary environment of the Asmari Formation in north flank of the Khami anticline in the north of the Gachsaran province is investigated. The Asmari Formation at the study section with a thickness of 276 meters is a thin, medium and thick to massive limestone, nodular limestone, marl, marly limestone, dolomite and dolomitic limestone. In this study 166 thin sections are studied and 23 genera and 24 species of foraminifera have been identified and 3 biozones are introduced. 1- Archaias asmaricus-Archaias hensoni-Miogypsinoides complanatus Assemblage zone. (Chattian) 2- Indeterminate zone (Aqutanian) 3- Borelis melo curdica-Borelis melo melo Assemblage zone. (Burdigalian) Thus, the age of the Asmari Formation at the study area is Chattian to Burdigalian (Oligo-Miocene). Based on study of thin sections and by considering the sediment texture, distribution of skeletal and non-skeletal grains, 12 microfacies are recognized which were deposited in open marine, bar, semi-restricted and restricted lagoon. Four platform types for the Asmari Formation at the study area in comparison with the recent studies on Asmari Formation including: 1-Rupelian-lower Chattian: Distally steepend ramp, 2-middle Chattian-upper Chattian: open shelf, 3-Aqiutanian: homoclinal ramp, 4-lower Burdigalian: carbonate platform. Manuscript profile

Open Access Article

41 - Source rock characterization of the Fahlian, Gadvan, and Surmeh formations in giant Gachsaran oilfield
Majid Safaei-Farouji Hossain Rahimpour-Bonab Buyuk Ghorbani

10.61186/ispg.33873.11.22.26

20.1001.1.22518738.1400.11.22.1.1

The 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 More

The 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

42 - Evidence of transpressional tectonics in NW of central Iran sedimentary basins based on reflective data and geomorphic indices
Mohammad Mokhtari S.Ahmad Alavi Leila Mahshadnia

20.1001.1.22518738.1397.8.16.2.9

The depressed basins of northwest central Iran are located in the structural Step and between Soltanieh-Ipac-Koshk-e-Nosrat and Qom –Zefreh system (the Indes - Qom –Khurabad faults). The main process of deformation within the basin with extension and compression of spec More

The depressed basins of northwest central Iran are located in the structural Step and between Soltanieh-Ipac-Koshk-e-Nosrat and Qom –Zefreh system (the Indes - Qom –Khurabad faults). The main process of deformation within the basin with extension and compression of specific structures are comparable and verifiable using experimental models. The extensional structures include roll-over folds and normal faults, resulting in deep sedimentary basins during deposition of the lower and upper red formations. The younger structures, includes back-thrusts and for-thrusts, shortcut, and pop up structures represents the reversal of tectonic of primary extensional basin. These sedimentary basins have been created in relation to the growth faults and hanging wall blocks So In the presence of roll-over fold and antithetic and synthetic faults therefore are suitable for entrapment of hydrocarbons during migration. The active structural features have been identified using combination of geomorphic characteristic and seismic reflection data. Accordingly, none of the old normal faults in the Saveh- Qom and Aran basin show at the present any extensional movement and the fault activity of boundary faults and extensional folding are compressional. The active parts are: hanging wall of Saveh, restraining bending at the end of Indes fault that has stream Length-Gradient (SL) index and high value hypsometric index (Hi). The central part of Saveh-Qom and Aran basin, although show high Hi but the SL is low. This situation is due to the moderating effects of the thick lower and upper red formations and evaporative layer within the basin. In the Aran basin due to incomplete coverage of seismic lines the absence of normal faults cannot be definitively confirmed. However, the center of Aran basin as of Qom-Saveh formed push up which marks the compression of this basin and also activity of reverse and thrust faults. Based on the existing surface and subsurface data set, active deformation in this area now is transpression basin and the interior domains are in the uplift. Manuscript profile

Open Access Article

43 - Reconstruction of sedimentary environment, and depositional sequences based on Microfacies of the Qom Formation in the Kahak area (Southwest of Qom city)
Mahdiyeh Mahyad Hosyen Vaziri moghadam

20.1001.1.22518738.1397.8.15.3.8

In this study, sedimentary environment and depositional sequences were reconstructed based on distribution of microfacies in the sequence belong to the Qom Formation in the Kahak area. The formation was formed alternation of shale and limestone. The boundary between the More

In this study, sedimentary environment and depositional sequences were reconstructed based on distribution of microfacies in the sequence belong to the Qom Formation in the Kahak area. The formation was formed alternation of shale and limestone. The boundary between the Qom Formation and the volcanic rocks is unconformable. In addition, the Upper Red Formation in the Kahak area unconformably overlies the Qom Formation. In the study area, 6 microfacies, and 1 terrigenous facies (shale) for the Qom Formation were identified by study of these rock samples. The Qom Formation was deposited in an open-shelf carbonate platform in the study area. This platform can be divided into two environments that the environments consist of the inner shelf (restricted lagoon and semi-restricted lagoon) and middle shelf. Finally, two third-order sequences were identified based on distribution of microfacies in the Kahak area. Manuscript profile

Open Access Article

44 - Compilation of artificial neural networks and the thinned Fault likelihood auto-tracking algorithm, for identification, interpretation and extraction of faults
Alireza Ghazanfari Hoseyn Mohammadrezaei Hamidreza Ansari

20.1001.1.22518738.1397.8.15.5.0

Fault identification and investigating their evolution is of special importance in the exploration and development of hydrocarbon resources. Success in exploration and development of hydrocarbon fields, need to recognition of petroleum systems and in this regard one of More

Fault identification and investigating their evolution is of special importance in the exploration and development of hydrocarbon resources. Success in exploration and development of hydrocarbon fields, need to recognition of petroleum systems and in this regard one of the most important topics is identifying faults and their extension condition as a main fluid migration path, specially in deeper zones. Faults and fractures have crucial role in making high permeable and porous segments and cut reservoir and cap rock in the fluid migration path. In addition, for maximizing the production of hydrocarbon from reservoirs and also for reducing the risk of drilling, it is necessary to gain information about geometry and nature of faults of reservoirs. In this paper, the purpose is investigating the performance of combination of neural networks and Fault Likelihood auto-tracking algorithm for identification and interpretation of faults in seismic data. At first using the Dip-steering feature of software, the early filter for accurate identification of dip of structures in the data, have been designed and applied. Then with designing and applying the appropriate filters, the seismic data have been improved. After that proper seismic attributes for fault identification have been calculated from seismic data. With picking fault and non-fault points from data, a supervised neural network using the selected attributes was formed and after training the network, the appropriate output achieved. Then the output of neural network has been used as a input for Thinned Fault Likelihood auto-tracking algorithm. The output of this part contains a volume of tracked faults. Finally using sub-tools of TFL and optimal setting of parameters, 3D fault planes has been interpreted and extracted. Manuscript profile

Open Access Article

45 - Integrated different methods (Lorenz, Lucia, Amaefule) in rock types and flow units identification of lower Miocene Razak Formation at Sarkhun gas field, Zagros basin, SE Iran
Mohammad Hossein Saberi Milad Karampour.Hasanvand Seyed Ali Moallemi

20.1001.1.22518738.1397.8.15.6.1

One of the most important stages in the hydrocarbon reservoirs morphology is the identification of rocky type. In order to construct an efficient and correct model of a hydrocarbon reservoir, identification of rock types is one of the essential parameters in reservoir m More

One of the most important stages in the hydrocarbon reservoirs morphology is the identification of rocky type. In order to construct an efficient and correct model of a hydrocarbon reservoir, identification of rock types is one of the essential parameters in reservoir modeling. and its consequences are found in the identification of rock types. The aim of this study is to compare different methods of determining rocky type and understanding the hydraulic flow unit distributions in order to assess the quality of reservoir of Razak Formation with sandstone carbonate lithology, marl and anhydrite to San Oligocene to lower Miocene. In this research, the experimental results of porosity, permeability and capillary pressure curves for 84 samples with porous microscopic sections Related to a 46-meter drill bit in one of the important fields of southeast of Iran were analyzed. The petrographic studies were conducted to investigate the changes of the features in the reservoir section with Razak formation and resulted in the identification of eight microfeatures( The MF1 packstone and Wackstone are at a depth of 2829 meters- The MF2 is the grinstone packstone at a depth of 2844 meters-the MF3 is the wackstone mudstone at a depth 2856 meters-the MF4 is the grinstone at a depth 2859meters –the MF5 is the mudstone wackstone are at a depth2848 meters – the MF6 mudstone at a depth of 2838 meters the MF7is the wackstone mudstone at a depth 2840 meters- The MF8 is a wackstone with sandstone depth of 2831) meters- in open Marin lagoon and fluvial clastic systems. In order to determine the rocky species and assess the flow units based on the core analysis results, four petrophysical classes were identified using the Lucia method. The petrophysical category number 1 has the best reservoir quality and the fourth category has the weakest reservoir quality. Also, the flow units were identified and separated using Amalufee and Lorenz's methods. Based on the Amalufee method, in the reservoir section of the Razak Formation, seven flow units have been identified, the sixth and seventh stream units were the best and one was the weakest reservoir segments among the seven units of the flow. Also, based on the analysis of capillary curves, six rocky species were distinguished, based on which the rocky type number five and six have the best quality. Also, using Geology software cross-sections, it was revealed that the main part of this section is sandstone with clay. The presence of gas in the formation causes cross-sectional deformation of samples to the northwest cross-platform. Finally, with the combination of various data, it was found the fossil formation in the study area has five types of rock in which the number 4 rock has the best quality of reservoir and rock number 5 has the largest reservoir and the unit number six is the best. Manuscript profile

Open Access Article

46 - Analysis Correlation of Seismo-Tectonic in Bakharden-Quchan Zone with Geometry Disorders of Earthquakes
Javad Biglari abbas kangi abdolreza jafarian

20.1001.1.22518738.1398.9.17.1.7

The most seismic activities have observed around and along major fault systems of this zone in NE Iran that involving of an array active right lateral-strike slip faults have distributed by trending NW-SE. neotectonic activity and mechanism changing of faults to reverse More

The most seismic activities have observed around and along major fault systems of this zone in NE Iran that involving of an array active right lateral-strike slip faults have distributed by trending NW-SE. neotectonic activity and mechanism changing of faults to reverse trusting faults have caused to increase stress, shortening and increasing seismicity with high density of earthquakes in their ends bending. Structural relation faults between this zone and Binaloud through Meshkan thrusting-transfer zone which is major motion engine of Bakharden-Quchan zone to put it constantly under neotectonic stresses convergence of Arabia-Eurasia plates since last phase Alpine orogeny. In this paper Fractal analysis through box counting method has done and D values change between 0-2. If D closes to zero, faults an earthquakes are focusing in a point with high tension and if D closes to 2 is shown low tension, dispersal faults and earthquakes in whole of region. Both surface/volume fractal dimension distribution show higher seismicity activity in Central and Western parts of Kopeh Dagh in NE Iran. Manuscript profile

Open Access Article

47 - Investigation of main planktonic foraminifera bio-events at the base of the Coniacian and Santonian stages in the Surgah Formation, Maleh-Kuh and Sarkan wells, South west of Khoram Abad
Mohammad Hadadi Meysam Shafiee Ardestani Mohammad Vahidinia Mohammad Gharaee

20.1001.1.22518738.1398.9.17.2.8

In this study Surgah Formation at Maleh-Kuh and Sarkan section in south west of Khoram Abad have been studied based on bio-event models. Surgah Formation at Sarkan well no.1and Maleh-Kuh has 46 and 82-meter thickness respectively and was placed on the Sarvak Formation a More

In this study Surgah Formation at Maleh-Kuh and Sarkan section in south west of Khoram Abad have been studied based on bio-event models. Surgah Formation at Sarkan well no.1and Maleh-Kuh has 46 and 82-meter thickness respectively and was placed on the Sarvak Formation and under the Ilam Formation. In this study Surgah Formation were composed of shale, limy shale with glauconite and pyrite. In this section two Turonian-Coniacian and Coniacian-Santonian boundaries were recognized in Dicarinella concavata Interval Zone. Based of Heterohelix moremani and FODs Dicarinella concavata and Dicarinella primitiva were detected Turonian-Coniacian boundary. Finally based on LoDs Dicarinella primitiva and Marginotruncana marginata were distinguished Coniacian - Santonian boundary in this section. Manuscript profile

Open Access Article

48 - Modeling of Horizontal Extent of Pay zone Layer on the Basis of Petrophysical Parameters Variations Using Indicator Kriging Method in one of the Southwest Iranian Oil Fields
Farnaz Saberi Farhad Mohammad Torab Kioumars Taheri

20.1001.1.22518738.1398.9.17.3.9

Determining the position of the production zone is one of the best ways to reduce drilling costs as well as quick access to the reservoir and optimal production of hydrocarbon resources. The purpose of this study, is to estimate the porosity, water saturation and thickn More

Determining the position of the production zone is one of the best ways to reduce drilling costs as well as quick access to the reservoir and optimal production of hydrocarbon resources. The purpose of this study, is to estimate the porosity, water saturation and thickness of an oil field in Iran’s southwestern Basin , and ultimately to reach the production zone. Therefore, according to the data obtained from 76 wells of this field, variation of reservoir petrophysical parameters were modeled with variogram operation and using Geostatistical methods. By using ordinary Kriging method, the values of the parameters were estimated in the whole field. Subsequently, by using the indicator kriging method, the field boundaries were separated in order to obtain the exact area of the oil zone and the volume of oil in place and finally by considering the 80% probability level, The definite boundary of the presence of the production zone was determined in the block model and In this zone the volume of reservoir’s hydrocarbon was estimated about 147/5 million cubic foot. Manuscript profile

Open Access Article

49 - Interpretation of sedimentary environment and factors affecting reservoir quality in upper Sarvak Formation in one the oil fields of Abadan plain
Mohammad Hossein Saberi Bahman Zarenezhad الهام اسدی Nasim Rahmani

The 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 More

The 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

50 - 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 Rahmani

20.1001.1.22518738.1397.8.16.6.3

The 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 More

The 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

51 - An attempt to reservoir characterization of Burgan sand, in the northwest of the Persian Gulf toward Kuwait
Ali reza Bashari

20.1001.1.22518738.1398.9.18.6.4

The Sand tongues of the Albian Kazhdumi Formation is a major prodactive reservoir in North West part of the Persian Gulf towards Kuwait . High porosity and high permeability of these sandstones together with existence of shale either as source rock or cap rock in More

The Sand tongues of the Albian Kazhdumi Formation is a major prodactive reservoir in North West part of the Persian Gulf towards Kuwait . High porosity and high permeability of these sandstones together with existence of shale either as source rock or cap rock in this formation, have provided all conditions needed for hydrocarbon accumulation. A rapid sea level fall in ealry Albian initiated the deposition of Burgan clastic reservoirs over the Shuaiba Carbonates. The lower Burgan Formation was deposited in a lowstand systems tract represented by massive sandstone reservoirs. High frequency sealevel changes have resulted in deposition of shoreface sands and extensive marine shales within an overall fluvial setting. The middle part Burgan was deposited in a transgressive systems tract. The upper part witnessed a relative sealevel fall in a lowstand systems tract with deposition of sand prone facies in estuarine channels. The clastic cycle was terminated by initiation of Mauddud carbonate sedimentations in transgressive systems tract. A combined effect of allocyclic nesting of sequence stratigraphic packages and autocyclic ramp profile were the primary factors controlling the lithofacies association. This Formation has been informally subdivided into: Lower Interval (C) mainly shaly sands, middle Interval (B) clean sands “main reservoir” and upper Interval (A) interbedded shale & sands. Petrographic analysis shows that the reservoir consists of quartz-rich sands, (typically>70%) and feldspar poor (mainly <5%). Nine authigenetic minerals in the Burgan sands have been identified: quartz, calcite, siderite, pyrite, glauconite along with four groups of the clay minerals. XRD analysis of clay fraction indicates the presence of four clay mineral groups in the Burgan reservoirs : kaolin, illite , chlorite and expandible- lattice mixed –layer, illite/ smectite. Manuscript profile

Open Access Article

52 - Qom Formation, Microfacies, Depositional sequence, Maragh area.
Amrolah Safari Hossein Ghanbarloo Ebrahim Mohammadi

20.1001.1.22518738.1399.10.20.3.2

The Qom Formation is located at the Maragh area (20 kilometers southwest of Kashan). The formation with 216 m thickness contains shale and limestones. Volcanic rocks unconformably are covered by the Qom Formation. The upper boundary of the Qom Formation with the Upper R More

The Qom Formation is located at the Maragh area (20 kilometers southwest of Kashan). The formation with 216 m thickness contains shale and limestones. Volcanic rocks unconformably are covered by the Qom Formation. The upper boundary of the Qom Formation with the Upper Red Formation is also unconformable. Nine microfacies and terrigenous facies were identified based on the main components and sedimentological features. These microfacies and terrigenous facies were deposited on an open-shelf carbonate platform. Three environments were recognized in this carbonate platform. These environments include the inner shelf (restricted and semi-restricted lagoon), middle shelf, and outer shelf. In addition, three third-order and one incomplete depositional sequences were identified based on the vertical distribution of microfacies. Manuscript profile

Open Access Article

53 - Geochemical Study and Genetic Classification of Fahlian Reservoir Oil Using Infrared Spectroscopy in the Fields of Southwestern Iran
Mohammad Ali Sahmoradi Mohammad Hossein Saberi Bahman Zare nejad Ali Chehrazi

20.1001.1.22518738.1399.10.19.5.2

The first step in performing geochemical adaptations is to identify the molecular and hybrid structure of the oil. One way to match the use of infrared spectroscopy is to identify and compare the structure of oil samples. Infrared spectroscopy is a practical method with More

The first step in performing geochemical adaptations is to identify the molecular and hybrid structure of the oil. One way to match the use of infrared spectroscopy is to identify and compare the structure of oil samples. Infrared spectroscopy is a practical method with easy, low-cost interpretation and reliable results for determining the structure of organic compounds. Also, considering the significant growth of the tendency to develop fast, accurate and reliable analytical methods for industrial applications and also the discovery of new hydrocarbon resources in the sedimentary basin of Abadan plain such as Darkhoein and Yadavaran oil fields in recent years, indicates the need for more comprehensive studies. There is a sedimentary basin in this basin. Based on this, 15 samples of crude oil from Fahlian reservoir were selected and examined in the most important oil fields of this basin, namely Darkhoein (9 samples) and Yadavaran (6 samples) located in southwestern Iran. By dividing the samples by evaluating the crude oil, different analytical goals were achieved. Using infrared spectroscopy, the functional groups in the samples were determined and then the amount of these compounds in different samples was compared with each other. Based on the results of the mass spectrometer, the oils studied in this basin are divided into three families with different genetic characteristics. In this study, it was shown that infrared spectrometer is a fast, reliable and non-destructive analytical option and a complementary or even alternative method of chromatography and biomarkers analysis to perform various scientific and industrial purposes in the oil industry, including quality measurement, Quantity and geochemical evaluation of oil. Manuscript profile

Open Access Article

54 - Permeability estimation using petrophysical logs and artificial intelligence methods: A case study in the Asmari reservoir of Ahvaz oil field
Abouzar Mohsenipour Bahman Soleimani iman Zahmatkesh Iman Veisi

20.1001.1.22518738.1399.10.20.4.3

Permeability is one of the most important petrophysical parameters that play a key role in the discussion of production and development of hydrocarbon fields. In this study, first, the magnetic resonance log in Asmari reservoir was evaluated and permeability was calcula More

Permeability is one of the most important petrophysical parameters that play a key role in the discussion of production and development of hydrocarbon fields. In this study, first, the magnetic resonance log in Asmari reservoir was evaluated and permeability was calculated using two conventional methods, free fluid model (Coates) and Schlumberger model or mean T2 (SDR). Then, by constructing a simple model of artificial neural network and also combining it with Imperialist competition optimization (ANN-ICA) and particle swarm (ANN-PSO) algorithms, the permeability was estimated. Finally, the results were compared by comparing the estimated COATES permeability and SDR permeability with the actual value, and the estimation accuracy was compared in terms of total squared error and correlation coefficient. The results of this study showed an increase in the accuracy of permeability estimation using a combination of optimization algorithms with artificial neural network. The results of this method can be used as a powerful method to obtain other petrophysical parameters. Manuscript profile

Open Access Article

55 - 3D modeling of rock types using the integration of core, well logs and seismic data in one of the carbonate reservoirs of southwestern Iran.
Mahdi Kheirollahi Golnaz Jozanikohan Reza Mohebian Ali Moradzadeh

10.52547/ispg.38414.11.21.1

20.1001.1.22518738.1400.11.21.2.0

Rock typing is the process of assigning reservoir properties to geological facies, and an identified rock type has similar geological and reservoir properties. Due to the importance of identifying and separating rock types in hydrocarbon reservoirs, various methods have More

Rock typing is the process of assigning reservoir properties to geological facies, and an identified rock type has similar geological and reservoir properties. Due to the importance of identifying and separating rock types in hydrocarbon reservoirs, various methods have been proposed and developed today for the determination of rock types. One of the simplest methods is the porosity chart against permeability and cut-off determination, and one of the most important and practical of these methods is to determine rock types by flow zone indicator. In this study, we examine one of the most important hydrocarbon fields in the south of Iran where core, well and seismic data are available for the field studied so that by designing a new workflow and with use of the most important and efficient methods of rock typing, including FZI, porosity, Winland-Pitman index, FZI*, and logarithms of FZI and FZI* we have identified rock types in three dimensions and through the whole field. After the final validation, the correlation coefficient values were more than 83%, 57%, 70%, 70%, 73% and 78% for the methods used, indicating greater accuracy and efficiency of the FZI method for the rock types separation in this field. The partial comparison of the validation results after each method employment also confirms the highest accuracy belongs to the FZI method. As a result, by integrating this method with seismic attributes, the rock types have been separated in four different groups throughout the field in three dimensions. Manuscript profile

Open Access Article

56 - Permeability improvement calculated from Stoneley-FZI method in Kangan reservoir, one of Iran's gas fields
hossein rezaie yegane doost

10.61186/ispg.38526.11.22.39

20.1001.1.22518738.1400.11.22.2.2

Permeability 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 More

Permeability 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

57 - Investigating the role of microfacies, depositional conditions and diagenesis on the quality of the reservoir section, Ilam Formation (Santonian-Campanian) in one of the fields in southwestern Iran, Dezful embayment
Seyedeh Akram Jooybari Peyman Rezaei Majid Mehdipour

10.52547/ispg.39683.11.21.16

20.1001.1.22518738.1400.11.21.3.1

The Ilam formation is one of the important carbonate oil reservoirs of the Zagros and Dezful embayment basins. In order to identify the microfacies and depositional conditions and diagenesis processes, 100 microscopic thin sections from one well of this reservoir in on More

The Ilam formation is one of the important carbonate oil reservoirs of the Zagros and Dezful embayment basins. In order to identify the microfacies and depositional conditions and diagenesis processes, 100 microscopic thin sections from one well of this reservoir in one of the Dezful embayment oil fields were evaluated. Porosity and permeability data were used to check reservoir quality. The petrographic study led to the identification of 9 microfacies belonging to the facies belts of lagoon, barier, middle ramp and outer ramp, which were deposited in the homoclinal ramp environment. The most important diagenesis processes identified in Ilam reservoir include cementation, dissolution, fracture, micriteization, stylolitization, and dolomitization. Based on the qualitative classification of the reservoir and Lucia's petrophysical diagrams, the lagoon facies and the middle ramp have an average reservoir status, and the carbonate barier facies and the outer ramp have a weak reservoir status. The reservoir quality of the lagoon and middle ramp facies is related to the existence of interconnected and channel porosities. Due to strong cementation and the presence of unrelated porosity such as mold porosity, the carbonate barier facies has low permeability and has a poor reservoir status. In general, the Ilam Formation in the studied field is in a weak state in terms of reservoir, which can be important in addition to the facies controllers in relation to the lack of expansion of fracture and dolomitization and the excessive expansion of cementation in these facies. Therefore, the Ilam Formation in the studied field has a weak reservoir performance due to diagenetic processes, despite having more shallow sequences than deep ones. Manuscript profile

Open Access Article

58 - Investigation of petrographical and geochemical characteristics of carbonate deposits of the Jamal Formation in the Chah-Riseh section, northeast of Isfahan
Behrad Zebhi Kamand محمد علی صالحی Ezat Heydari Ali Bahrami

10.52547/ispg.39691.11.21.54

20.1001.1.22518738.1400.11.21.4.2

The Middle Permian Jamal Formation have been investigated for sedimentological and geochemical aspects in the Chah-Riseh section, northeast Isfahan. According to the field studies the Jamal Formation with 251 m thickness divided into eight lithostratigraphic unit. Lower More

The Middle Permian Jamal Formation have been investigated for sedimentological and geochemical aspects in the Chah-Riseh section, northeast Isfahan. According to the field studies the Jamal Formation with 251 m thickness divided into eight lithostratigraphic unit. Lower boundary of this formation with an unconformity is underlained by the Sardar Formation which belongs to the Carboniferous period and upper boundary with an unconformity reaches to the Lower Triassic Sorkh-Shale Formation. Facies and microfacies studies of the Jamal Formation led to the identification of two petrofacies and 14 carbonate microfacies. According to the recognized carbonate allochems, petrofacies and microfacies of the Jamal Formation and some evidence such as transitional microfacies changes, we can consider a depositional environment of a shallow mixed siliciclastic-carbonate ramp platform. Petrographically, four types of dolomites are recognized in the Jamal Formation. The dolomitization model for the type I dolomite is considered forming in tidal flat and burial dolomitization for types II, III and IV. Geochemical studies including major and trace elements analysis comprised of elements such as Ca, Mg, Sr, Mn and Fe. Using ratios of the elements and also by plotting some of these elements cross carbon and oxygen isotopes in various diagrams have been used in determining the original mineralogy of carbonate deposits and efficient diagenetic system on the Jamal Formation. The results indicate that the dominant diagenetic environment effected on the carbonate deposits of Jamal Formation was occurred in a semi-closed system and the original mineralogy was aragonite. Evaluation of major and trace elements contents of the four types dolomites, confirmed different characteristics of theses dolomite resembling crystal sizes in petrographic studies. Carbon and oxygen isotopes data of dolomites also defined their diagenetic situations. Manuscript profile

Open Access Article

59 - Integration of petrophysical and Seismic data: an Attempt to Geological model, Ilam reservoir oil field, Sirri District , in the Persian Gulf.
Alireza Bashari

10.52547/ispg.39981.11.21.98

20.1001.1.22518738.1400.11.21.6.4

Ilam Formation is deposited at the late Cretaceous (Santonian) in a neritic/pelagic environment. Following the Ilam deposition, a general deepening has occurred and the Gurpi formation (shaly layer) was deposited. Ilam has thickness variation between 75-110m and st More

Ilam Formation is deposited at the late Cretaceous (Santonian) in a neritic/pelagic environment. Following the Ilam deposition, a general deepening has occurred and the Gurpi formation (shaly layer) was deposited. Ilam has thickness variation between 75-110m and structure has created as a result of upward movement of deep seated salt. Ilam reservoir in this field is regarded as a secondary hydrocarbon potential, and since now, no oil has been produced from this horizon. petrophysical and Seismic interpretation has been done for the Ilam reservoir, the geological models (structural and property models) are generated, with both deterministic and stochastic approaches. The seismic attributes as secondary variables, improved the kriging and Sequential Gaussian Simulation (SGS) algorithm results for modeling of Ilam. This study reveals that Water Saturation is generally high, indicating that Ilam reservoir has low hydrocarbon potential, within the five reservoir potential zones, the zone 5 indicated a good original oil in place potential, especially in the western and central parts of the field. Manuscript profile

Open Access Article

60 - Investigating the reservoir quality of Sarvk formation using multi-resolution graph-based and comparing it with petrographic data in an oilfield of Dezful Embayment
Seyedeh Akram Jooybari Payman Rezaee Majid Mehdipour

20.1001.1.22518738.1401.12.23.2.1

Sarvak Formation is one of the important carbonate reservoirs in Dezful Embayment. In order to evaluate the reservoir quality of this formation in one of the Dezful Embayment fields, multi-resolution graph-based method was used and compared with petrographic findings. T More

Sarvak Formation is one of the important carbonate reservoirs in Dezful Embayment. In order to evaluate the reservoir quality of this formation in one of the Dezful Embayment fields, multi-resolution graph-based method was used and compared with petrographic findings. The findings showed that the Sarvak formation in the studied field consists of 8 microfacies belonging to the sub-environments of the lagoon, carbonate bar, middle ramp and outer ramp, which were deposited in a homoclinal ramp environment. The main diagenesis processes affecting this reservoir include cementation, dissolution, fracture, stylolitization, and dolomitization. The results of multi-resolution graph-based analysis led to the identification of 3 electrofacies, EF1 electrofacies had the weakest reservoir parameters and EF3 facies had the best reservoir status. The majority of EF1 microfacies are grainstone microfacies and the majority of EF3 microfacies correspond to wackstone and packstone microfacies. Based on this, it seems that the lagoon sub-environment has a better reservoir condition than other sub-environments, especially the carbonate bar, and this is an important sign of the different performance of diagenesis processes in these sub-environments. In a vertical trend, the highest volume of hydrocarbon column is in the EF3 electrofacies and the lowest is EF1. In general, it can be stated that the use of multi-resolution graph-based analysis and comparison with petrographic findings is a suitable solution for accurate evaluation of the reservoir quality of carbonate reservoirs. Manuscript profile

Open Access Article

61 - Isotopic and Geochemical comparison of Bangestan and Asmari Oils to determine origination
ashkan Zardashti Morteza Tabaei mahmood memariani

20.1001.1.22518738.1401.12.23.5.4

In order to analyze the geochemical characteristics, the oil samples of the Asmari reservoirs and the Bangistan group in the Kopal field were studied using various geochemical techniques such as asphalting technique, gas chromatography technique, gas chromatography-mass More

In order to analyze the geochemical characteristics, the oil samples of the Asmari reservoirs and the Bangistan group in the Kopal field were studied using various geochemical techniques such as asphalting technique, gas chromatography technique, gas chromatography-mass spectrometry technique and carbon isotope measurement technique, were subjected to analysis. the purpose of This research is a comparison of carbon isotope and geochemical properties of Asmara and Bangestan oils in Kopal field to determine their parent rock and origin. Considering the results of the testing technique and analysis of biomakers of the esteranes and terpanes family extracted from saturated cutting, it can be stated that the oils accumulated in the Asmari and Bangestan reservoirs of the Kopal field have the characteristics of oil. are paraffinic, which indicates the existence of light oil with good quality, mature, low viscosity and high sulfur. By placing the ratio of biomarker parameters against carbon 13 isotope and examining the general results of the graphs, it was found that the oil samples of Asmari reservoirs and Bangestan reservoirs in the studied field are from a common generative rock. have been found and have the same characteristics and only slightly differ in maturity, degree of fluidity, and the amount of migration processes between the source rock and the reservoir rock, and similarly, the transformation course of the source rock organic materials has occurred naturally in the Copal field. The values of carbon isotopes in the oils indicate the average maturity of the rocks producing the oils. The graph of the ratio of the aromatic carbon 13 isotope against the saturated carbon 13 isotope showed that both field oil samples The subject of study belongs to marine environments. Manuscript profile

Open Access Article

62 - Examination of climatic orbital changes and sedimentation rate in the Ilam Formation in the Kupal oilfield, Dezful Embayment
Forough Abasaghi Armin Omidpour

20.1001.1.22518738.1401.12.23.3.2

Carbonate successions are considered archives for recording the palaeoclimatic proxies and so they are suitable for understanding climatic patterns and identifying the Milankovitch cycles and cycles’s impacts on sea-level changes during Phanerozoic. In the current study More

Carbonate successions are considered archives for recording the palaeoclimatic proxies and so they are suitable for understanding climatic patterns and identifying the Milankovitch cycles and cycles’s impacts on sea-level changes during Phanerozoic. In the current study, the carbonate successions of the Ilam Formation (Santonian) and their spectral gamma-ray data were chosen to identify the cycles and influencing factors on the sedimentation in one of the oilfields in the Dezful Embayment, southwest of Zagros mountains. According to available evidence, all of Milankovitch cycles contributed to changes in climatic conditions simultaneously with development of the Ilam Formation, however, the long Eccentricity cycles were dominant and have played a greater role in this issue. The sedimentation rate was estimated at 4-5.5 cm/kyr on average in the Ilam Formation. Considering the sedimentation rate and number of identified long Eccentricity cycles, it could be said the deposition in the Ilam Formation lasted in 1.13-1.8 Ma. Our results indicate that the relative sea-level changes in the studied wells correspond to the eustatic sea level. The deposition process in the Ilam Formation was largely affected by the performance of long Eccentricity cycles, eustatic sea level, and tectonic events during the Upper Cretaceous. Manuscript profile

Open Access Article

63 - Reservoir characteristics prediction using the geostatistical model. Case study: Bangestan reservoir, Ziloi Field, SW Iran
Somaieh Khoram abadi Bahman Soleimani Hussin Sheikhzadeh

20.1001.1.22518738.1401.12.24.3.4

The 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 More

The 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

64 - Depositional Environmental Analysis of Shally Units of Pabdeh-Gurpi Formation and Clay Minerals Effect on Wellbore Stability, Aghajari Oil Field
بهمن سلیمانی Zahra Dehghani

20.1001.1.22518738.1401.12.23.6.5

Shally units are one of the most problematic parameters in the process of drilling oil reservoirs. The current study is related to the instability of the wellbore due to the presence of clay minerals bearing shally units of the Pabdeh-Gurpi formations in Aghajari oilfie More

Shally units are one of the most problematic parameters in the process of drilling oil reservoirs. The current study is related to the instability of the wellbore due to the presence of clay minerals bearing shally units of the Pabdeh-Gurpi formations in Aghajari oilfield. Investigation and identification of shales were done using the XRF laboratory and NGS logs. The results showed that the NGS method is sensitive and applicable to identify Illite mineral merely. According to Fe2O3 content, the upper part of the oxidant conditions, but towards the Gurpi, is dominated by reduction condition. The role of other elements in the formation of clay minerals was discussed. Based on the amount of iron, manganese and vanadium, the samples are classified as the Quinby_Hunt and Wilde class lll (non-sulfide resuscitation but Eh recovery and medium to low pH). The range of changes in the Th/U ratio (4-1.5) signified an environment with changes from sea to intermediate states. Manuscript profile

Open Access Article

65 - 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 gharaii

20.1001.1.22518738.1401.12.24.6.7

Zagros 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 More

Zagros 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

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