The South Pars Field, one of the largest gas and condensate resources in the Persian Gulf is located at the border of Iran and Qatar. The Dariyan Formation plays the role of a reservoir rock in this field, which is a sequence of limestone, shale and marl lithology. The most important processes affecting diagenetic facies are dissolution, cementation, compaction, and fracture development, while dissolution is the most important one for improving the reservoir quality of Dariyan Formation. Total porosity of Dariyan Formation is about 20 to 25%, while the effective porosity of the reservoir is considerably lower than total porosity due to blocked fractures. Consequently, the reservoir quality of Dariyan is poor. Open fractures are the main factors of high permeability. Porosity is a basic parameter determination of oil in place and characterization of rock fabrics. The neutron, density and sonic are the conventional porosity logs. The obtained porosity of these logs is not certainly equal to each other and real porosity of the rock because the logging tools do not measure the porosity. The tools measure physical reactions in well and then convert it to porosity. Porosity value is not only the output of these logs but also the pore type of reservoirs can be determined through these logs. Velocity deviation log, obtained from combination of neutron and sonic logs, is a tool from which some information can be obtained for determining the main pore types of carbonate rocks. This log curve is built using neutron-density and sonic logs, synthetically. First, velocity deviation log is built synthetically, and then the amount of log’s deviation represents the pore type. In this study, the results of velocity deviation log were compared to porosities from petrographic study to evaluate the performance of the method in pore type determination. The results show that thin section porosity shows a good agreement with velocity deviation log results. Therefore, velocity deviation log in conjunction with other logs is a useful tool for pore type determination in carbonate rocks. The data from two wells (Spo1, Spo2) of the Dariyan Formation, South Pars Gas Field was used. The Dariyan Formation in the studied wells is made of carbonates with lithology of mainly lime with shale interlayers.

In hydrocarbon reservoirs (especially in carbonate rocks)، the variation of pore type and size is influenced by diagenesis effects. Hence pore type distribution and capillary pressure in the reservoir rock is the main factor controlling fluid flow in porous media. In other words، the determination of pore type/size and capillary pressure has an important role in understanding petrophysical features، optimizing the number of wells in the field، and forecasting the recoverable hydrocarbon. In this paper، pore types in the mixed carbonate-siliciclastic Asmari formation is divided by velocity deviation log into three classes (positive، zero، and negative deviation) and eight subclasses. Six subclasses are related to carbonate part (interaparticle or interafossil، moldic or vuggy، microporosity، interparticle، intercrystalline، and fracture) and two subclasses are related to clastic part (intergranular and shale microporosity). After identifying pore types، pore size and pseudo capillary pressure are continuously determined in each subclasses throughout the well bore by using NMR log. Pore size and pseudo capillary pressure are compared by mercury injection capillary pressure curves. The results of this study show that intergranular porosity is the main factor for production in calstic intervals; however، fracture، interparticle، and intercrystalline porosities play an important role in carbonate intervals. The distributions of each four pore types are continuously determined along the well bore.

In this research, the Mishrif Formation was studied in Sirri Esfand field in order to investigate the pore system and reservoir zonation using velocity deviation log. The results show that there is a significant and consistent correlation between the variations of this log with the facies characteristics and core porosity and permeability values of reservoir rocks, which based on three reservoir zones were differentiated in the field. In these zones, variations in the quantitative and qualitative values of velocity deviation log can be related with pore system properties of the reservoir facies with respect to their primary texture and the effect of the diagenetic processes. Comparison of differentiated zones shows that zone-1 in upper part of the reservoir under the effectof sedimentary texture as well as the effect of diagenetic processes such as dissolution has high reservoir quality. Zone-3 in lower part of the formation, due to the mud-dominated texture of the facies has a lower reservoir quality. Zone-2 has an intermediate state in terms of reservoir quality.

In this study, the velocity deviation log was derived from routine wireline logs to determine the pore types of Kangan and Dalan carbonate formations in one of the central Persian Gulf fields. To achieve this purpose, core information from one well including porosity and permeability and petrography of thin sections along with wireline logs from 12 other wells were used. By using a velocity deviation log reconstruction based on density, neutron and acoustic logs, three velocity zones representing distinct porosity and one nonporous zone were identified. The three-dimensional model of velocity deviation log showed that K1 zone is mainly a dense and non-porous zone and, in some cases, it contains moldic and rarely intercrystaline porosity. This porosity was created due to sea-level fall during deposition of the upper part of this unit because of dissolution and dolomitization. K2 reservoir zone contains major intercrystaline and minor moldic porosities due to dolomitization in shallow sea-level conditions in most parts of this unit. Unit K3 mainly hosts dense and nonporous rocks, in cases moldic porosity and also randomly shows fractures in its lower part. K4 is more likely contain intercrystaline and interparticle porosities at the upper part which was deposited in a shallow environment. Moldic porosities were formed in lower parts in response to meteoric diagenetic environment. Fractures are also detected in some cases. The results of presented study show high correlation with other reservoir evaluations that prove the ability of velocity deviation modeling in predicting large-scale reservoir variations.

Purpose: To report a case of Joubert’ s syndrome with alternating skew deviation and lateral skew deviation. Case report: A 18-year-old girl was referred with the chief complaint of abnormal eye movements since infancy. Some degree of oculomotor apraxia was revealed as the girl had difficulties in initiating horizontal saccades and subsequent head thrust. Periodic alternating vertical misalignment of eyes was also evident, known as alternating skew deviation. After 3 to 5 seconds, the vertical divergence of the eyes reversed direction. Gaze to either side also resulted in hypertropia of abducting eye, known as lateral skew deviation. MRI demonstrated hypoplasia of superior cerebellar vermis along molar tooth signs associated with Joubert syndrome. Conclusion: This report shows that alternating skew deviation and lateral skew deviation can be manifestations of Joubert’ s syndrome.

Petrophysical rock type is a part of the reservoir that has the same properties such as geological and petrophysical characteristics. Therefore، the relationship between geological and petrophysical units can be useful for understanding the heterogeneity of the reservoir، especially in carbonates، which are highly variable from the pore type and pore throat size radius viewpoints due to the effect of diagenetic processes. The pore type and pore throat size radius as parameters which are relevant to the product of the geologic process (depositional and diagenesis) control the petrophysical properties of the reservoir. Accordingly، these two parameters are the best tools for communicating the geological and petrophysical characteristics of each petrophysical rock unit. In this paper، three methods including flow zone indicator، Winland R35، and discrete rock types (DRT) were used to determine the petrophysical rock type. The results show that the flow zone index outperforms the other methods، although the other two methods can have useful applications. To determine pore type and pore throat size radius in five flow units، which were identified by the flow zone indicator method، the velocity deviation log was used. Moreover، to determine the continuous distribution pore type the velocity deviation log was used. In addition، mercury injection data were employed to measure pore throat size radius. According to the results obtained from this study، the best flow units are in accordance with positive and zero velocity deviations، which have interconnected vuggy and intergranular which are the product of the dissolution (diagenesis) and depositional process. Finally، the results indicate that the reservoir quality of the Fahliyan Formation is affected by the two factors of diagenesis and sedimentation، but in general، diagenesis has the most contribution to determine the all reservoir quality of the formation.

Natural fractures analysis as a main controlling factor in fluid currents is very important in the reservoir characterization. This matter was studied using thin sections, cores, and FMI and velocity deviation logs in one of the fields in the southwestern of Iran. FMI initial data, which were input to Geoframe software, processed and interpreted. Velocity deviation logs and secondary porosity were also measured and compared. The results indicated that stylolites, pores, open and filled microfractures in the reservoir are present. The relative density of open fractures decreased to depth while filled fractures increased. The fractures are mainly longitudinal and latitudinal types with high angles to bedding surface. The main porosity system of the reservoir is inter particle and fractures types. According to the presence of oil staining in thin sections, it is revealed that the fractures are suitable conduits to transferring the fluid.

Evaluation of hydrocarbon saturation is very important in oil reservoirs calculations. Archie equations are the basic relations for evaluating rock saturation. The coefficients of these equations are determined by laboratory experiments. Archie presented these coefficients, which are constants for sandstone. However, since carbonate rocks show drastic variations in texture and pore type, Archie coefficients, which are more sensitive to pore type, should be determined for different types of carbonate rocks. Uncertainty in these coefficients causes many errors in saturation evaluation especially in the determination of the volume of oil in place. Cementation exponent is the main factor, which causes error in determining saturation. In this study Archie parameters (a and m) are determined in the laboratory for various petrofacies based on petrographic studies and CT-scan images. Due to high dependence of seismic wave velocity on pore shape in carbonate rocks, petrofacieses were also determined by using wave velocity deviation logs. Subsequently, Archie parameters were determined for each petrofacies. The results showed that cementation exponent increases with increasing velocity deviation values. It is concluded that correlation coefficient in different petrofacies obtained from velocity deviation logs is comparatively higher than the same for petrographic study. Considering the fact that petrophysical data are more accessible than the core-based petrography data, the method presented in this study seems to be a more useful approach in determining Archie coefficients.

All service and manufacturing businesses are resilient and strive for a more efficient and better end in today's world. Data mining is data-driven and necessitates significant data to analyze the pattern and train the model. Assume the data is incorrect and was not collected from reliable sources, causing the analysis to be skewed. We introduce a procedure in which the dataset is split into test and training datasets with a specific ratio to overcome this challenge. Process mining will find the traces of actions to streamline the process and aid data mining in producing a more efficient result. The most responsible domain is the healthcare industry. In this study, we used the activity data from the hospital and applied process mining algorithms such as alpha miner and fuzzy miner. Process mining is used to check for conformity in the event log and do performance analysis, and a pattern of accuracy is exhibited. Finally, we used process mining techniques to show the deviation flow and fix the process flow. This study showed that there was a variation in the flow by employing alpha and fuzzy miners in the hospital.