توجه: محتویات این صفحه به صورت خودکار پردازش شده و مقاله‌های نویسندگانی با تشابه اسمی، همگی در بخش یکسان نمایش داده می‌شوند.
۱Application Geostatistical 3D modeling in determination of apt regions oil fields (case study; Azadegan oil field)
اطلاعات انتشار: چهاردهمین همایش بین المللی نفت، گاز و پتروشیمی، سال
تعداد صفحات: ۱۰
Models play a central role in understanding and prdicting a reservoir key geological , gophysical , and engineering components . The aim of modeling is to provide one or more alternative 3D numerical models that aim to represent those geological , geophysical , reservoir enginnering aspects of the subsurface that matter for the study goal at hand. all needed data to construct 3D geological model include; geological data geophysical data and reservoir data any 3D modeling is performed on a grid composed of cells that have a certain dimensions. a grid–cell size considerably larger than the dimension of the smallest–scale data is thus considered to generate what is called the high –resolution 3Dgeocellular model. the dimensions of geocellular model depend on the study goals and the available data the procedure of this modeling was done sith using RMS software. in this software defines of geostatistical functions and relations that are using in modeling. workflow in this study is as following below; inputting of locations and their trajectory wells input of well picks for sarvak formation , input of interpreted petrophysical logs input of main UGC maps editing and QC of input data making of main reservoir surfaces. making of fault model making of structural model and 3D grid scale up of petrophysical logs inputting of acoustic impedance cubes into model for constraining of other parameters such as porosity for throughout of reservoir , data analysis and variography of each parameter, generating of stochastic model for each parameter. finally determinate of apt regions this field.<\div>

۲Condensate controlling with optimum flow rate determination and new equation of pressure drop of gas condensate reservoirs
اطلاعات انتشار: چهاردهمین همایش بین المللی نفت، گاز و پتروشیمی، سال
تعداد صفحات: ۱۳
Gas conden sate reservoir contains rich gases at the first condition of composition. The reservoir ha 100% of condensate in process of production while its pressure is far from dew point pressure. As the condensate in produced pressure is composed lower than what , the dew poit does and its saturation generally does not reach to the critical saturation level , a mass amount of this valuable liquid is practically lost. therefore beside gas recycling optimum flow rate determination seems to be necessary for maximum production of condensate . considering the related difficulties of pressure drop equation in optimum flow rate for gas condensate reservoir, there has not been presented any accurate and applicable method. in this paper pressure drop equations are presernted with adequate accuracy that will determine maximum flow rate in reservoir pressure beside the gas reservoir flow equation. also for the first time the flow of open reservoir in gas condensate and condensate radius estimation has been calculated with considering tubing head pressure.<\div>

۳Fitting the flow rate of different layers of a southern Iranian oil reservoir as the output of E 300 with fluid flow equation and neural network systems
اطلاعات انتشار: سومین کنگره ملی مهندسی نفت، سال
تعداد صفحات: ۱۱
In this study a sector of a southern Iranian layered reservoir is simulated with E300 simulator and then the oil flow rates of different layers is determined by the use of fluid flow equation in the base of PVT data of different fluid samples of reservoir. Two different neural networks (MBP and RBF) to fit the flow rates of different layers are applied, as the MBP is given sensible results. Finally for the other time steps of production, we are given a method that its only essential parameter is the average pressure of any layer<\div>

۴UTILIZING CONCEPTUAL MODELING IN THE STUDY OF ONE OF THE IRANIAN FRACTURED CARBONATE RESERVOIRS
نویسنده(ها): ،
اطلاعات انتشار: Journal of Petroleum Science and Technology، سوم،شماره۲، ۲۰۱۳، سال
تعداد صفحات: ۹
A typical Iranian carbonate matrix block surrounded by an open fracture was modeled in order to understand the fracture–matrix interaction and realize how to model the interaction best. The modeling was carried out by using a fine–scaled Eclipse model in the single porosity mode (the fractures were explicitly modeled). The model was extended to a stack of 6 matrix blocks to understand block–to–block interaction under both water and gas injection scenarios. The results and conclusions obtained from the single porosity single block and 6–block model were used in order to optimize the full field model. The simulation results showed that gas injection worked as a major recovery mechanism for medium and good rock types at all block heights and for poor rock type with block heights of more than 2 meters. The oil recovery results were in the same range for the single and six–stack block model، but the delay of oil recovery by gas gravity drainage is clearly seen in the six–stack block results indicating a period of at least 8–10 years required for reaching ultimate oil recovery for typical block heights. The water injection simulations showed that water imbibes drained the matrix block in a short time dependent on water front advancement in the fracture system surrounding the block. From the simulation results، it was concluded that the water imbibition process was a fast recovery mechanism for all block heights dependent on injection rate and fracture volume which had to be flooded to achieve full recovery of the block. The expected recovery factor of drained oil to initial oil in place after water injection was in the range of 15–35 % for poor to good rock types and different block sizes in the range of 1–5 meters. The results were highly influenced by wettability conditions in the reservoir.
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