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Hong-jun Yin - One of the best experts on this subject based on the ideXlab platform.
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Well Test Analysis for Fractured and Vuggy Carbonate Reservoirs of Well Drilling in Large Scale Cave
Energies, 2018Co-Authors: Cuiqiao Xing, Hong-jun Yin, Kexin LiuAbstract:A Well Test Analysis model for fractured and vuggy carbonate reservoir of Wells drilling in large scale cave considering Wellbore storage and skin factor is established in this paper. The Laplace transformation and Stehfest numerical inversion are applied to obtain the results of Wellbore pressure. Through the sensitivity Analysis of different parameters for the Well Test typical curves, it is found that the change of the Well Test curves is in accordance with the theoretical Analysis. With the increase of skin factor, the hump of Well Test typical curves is steeper. The storage ratio influences the depth and width of the concave in the pressure derivative curves. The cross flow coefficient mainly affects the position of the concave occurrence in the pressure derivative curves. The dimensionless reservoir radius mainly affects the middle and late stages of the log-log pressure type curves, and the later Well Test curves will be upturned for sealed boundary. The duration of the early stage of the log-log curves will become longer when drilling in large scale cave. The effective Well radius is increased to a certain extent, which is in full agreement with the conclusions in this paper. The size of the caves has the same effect on the Well Test typical curves as Wellbore storage coefficient. Due to acidification, fracturing, and other reasons, the boundary of the cave will collapse. Therefore, considering the Wellbore storage coefficient and skin effect is very important during Well Testing. However, the existing models for Well Testing of fractured and vuggy carbonate reservoir often ignore the Wellbore storage coefficient and skin effect. For fractured and vuggy carbonate reservoirs of Well drilling in large scale cave, the existing models are not applicable. Since the previous models are mostly based on the triple-porosity medium and the equivalent continuum. The Well Test model for Well drilling in large scale cave of fracture-cavity carbonate reservoirs with Wellbore storage coefficient and skin factor in this work has significant application value for oil field.
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Well Test Analysis on pressure of viscoelastic polymer solution with variable rheological parameters
Natural Science, 2010Co-Authors: Hong-jun Yin, Wei-li Yang, Siyuan Meng, Ming CaiAbstract:According to the behavior that the polymer solution has both the characteristics of viscosity and elastic properties, the transient flow mathe- matical model considered the viscoelasticity of the polymer solution has been established. The model, in which the variation of the rheological parameters during the seepage flow has been also taken into consideration, has been solved using finite-difference method. The type curves have been plotted. The influence of some properties of polymer solution including the viscocity, the elastic properties and the rheological parameters has been analyzed. Compared with the curves of the power-law fluid, it is shown that the pressure derivative curve considering the elasticity of the polymer solution upwarps less at the radial flow regime. Besides, it will come down as the variation of the rheological parameters, which is quite different from the case regarding them as constants. Therefore, in Well Test Analysis on pressure of polymer solution, it’s necessary to consider the elasticity and the variation of the rheological parameters.
Manouchehr Haghighi - One of the best experts on this subject based on the ideXlab platform.
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the effects of production rate and initial pressure difference pi pdew in Well Test Analysis of gas condensate reservoirs
Petroleum Science and Technology, 2011Co-Authors: G. H. Montazeri, Z. Ziabakhsh, Peyman Pourafshari, Seyed-hamed Tabatabaie, Manouchehr HaghighiAbstract:Abstract The theoretical basis for the Analysis of Well Test data presented in this study is the use of a pseudopressure function to linearize the flow of gas condensate in porous media. In this article different techniques to analyze gas condensate Well Tests using single-phase pseudopressure and two-phase pseudopressure are considered. The main objective of this work was to examine the available methods for Well Test Analysis of gas condensate reservoirs and investigate the effect of production rate and initial pressure difference (pi – pdew ) on these methods. Sensitivities of the two-phase pseudopressure methods and single-phase method are presented. However, at higher endpoint relative permeability, a lower prediction from single-phase pseudopressure Analysis is obtained. A lower difference between pi and pdew causes larger condensate bank size and larger Region 2 and therefore better prediction of Raghavan's approach.
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The Effects of Production Rate and Initial Pressure Difference (pi – pdew ) in Well Test Analysis of Gas Condensate Reservoirs
Petroleum Science and Technology, 2011Co-Authors: G. H. Montazeri, Z. Ziabakhsh, Peyman Pourafshari, Seyed-hamed Tabatabaie, Manouchehr HaghighiAbstract:Abstract The theoretical basis for the Analysis of Well Test data presented in this study is the use of a pseudopressure function to linearize the flow of gas condensate in porous media. In this article different techniques to analyze gas condensate Well Tests using single-phase pseudopressure and two-phase pseudopressure are considered. The main objective of this work was to examine the available methods for Well Test Analysis of gas condensate reservoirs and investigate the effect of production rate and initial pressure difference (pi – pdew ) on these methods. Sensitivities of the two-phase pseudopressure methods and single-phase method are presented. However, at higher endpoint relative permeability, a lower prediction from single-phase pseudopressure Analysis is obtained. A lower difference between pi and pdew causes larger condensate bank size and larger Region 2 and therefore better prediction of Raghavan's approach.
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The Effects of Richness, Relative Permeability Curves, and Skin in Well Test Analysis of Gas Condensate Reservoirs
Petroleum Science and Technology, 2010Co-Authors: G. H. Montazeri, Z. Ziabakhsh, Manouchehr Haghighi, Abdolnabi HashemiAbstract:Abstract Gas condensate reservoirs have more complicated performance than other categories because possessing intermediate compositions leads to more complex thermodynamic and phase behavior. When the Well bottom hole flowing pressure falls below the dew point, condensate liquid builds up around the Wellbore, causing a reduction in gas permeability and Well productivity. Well Test Analysis is now commonly used to identify and quantify near-Wellbore effects, reservoir behavior quantifying the skin and reservoir boundaries. Finding all this information from Well Tests in gas condensate reservoirs, however, is challenging. The present article demonstrates the effect of the richness, relative permeability curves, and skin in Well Test Analysis of gas condensate reservoirs.
G. H. Montazeri - One of the best experts on this subject based on the ideXlab platform.
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the effects of production rate and initial pressure difference pi pdew in Well Test Analysis of gas condensate reservoirs
Petroleum Science and Technology, 2011Co-Authors: G. H. Montazeri, Z. Ziabakhsh, Peyman Pourafshari, Seyed-hamed Tabatabaie, Manouchehr HaghighiAbstract:Abstract The theoretical basis for the Analysis of Well Test data presented in this study is the use of a pseudopressure function to linearize the flow of gas condensate in porous media. In this article different techniques to analyze gas condensate Well Tests using single-phase pseudopressure and two-phase pseudopressure are considered. The main objective of this work was to examine the available methods for Well Test Analysis of gas condensate reservoirs and investigate the effect of production rate and initial pressure difference (pi – pdew ) on these methods. Sensitivities of the two-phase pseudopressure methods and single-phase method are presented. However, at higher endpoint relative permeability, a lower prediction from single-phase pseudopressure Analysis is obtained. A lower difference between pi and pdew causes larger condensate bank size and larger Region 2 and therefore better prediction of Raghavan's approach.
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The Effects of Production Rate and Initial Pressure Difference (pi – pdew ) in Well Test Analysis of Gas Condensate Reservoirs
Petroleum Science and Technology, 2011Co-Authors: G. H. Montazeri, Z. Ziabakhsh, Peyman Pourafshari, Seyed-hamed Tabatabaie, Manouchehr HaghighiAbstract:Abstract The theoretical basis for the Analysis of Well Test data presented in this study is the use of a pseudopressure function to linearize the flow of gas condensate in porous media. In this article different techniques to analyze gas condensate Well Tests using single-phase pseudopressure and two-phase pseudopressure are considered. The main objective of this work was to examine the available methods for Well Test Analysis of gas condensate reservoirs and investigate the effect of production rate and initial pressure difference (pi – pdew ) on these methods. Sensitivities of the two-phase pseudopressure methods and single-phase method are presented. However, at higher endpoint relative permeability, a lower prediction from single-phase pseudopressure Analysis is obtained. A lower difference between pi and pdew causes larger condensate bank size and larger Region 2 and therefore better prediction of Raghavan's approach.
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The Effects of Richness, Relative Permeability Curves, and Skin in Well Test Analysis of Gas Condensate Reservoirs
Petroleum Science and Technology, 2010Co-Authors: G. H. Montazeri, Z. Ziabakhsh, Manouchehr Haghighi, Abdolnabi HashemiAbstract:Abstract Gas condensate reservoirs have more complicated performance than other categories because possessing intermediate compositions leads to more complex thermodynamic and phase behavior. When the Well bottom hole flowing pressure falls below the dew point, condensate liquid builds up around the Wellbore, causing a reduction in gas permeability and Well productivity. Well Test Analysis is now commonly used to identify and quantify near-Wellbore effects, reservoir behavior quantifying the skin and reservoir boundaries. Finding all this information from Well Tests in gas condensate reservoirs, however, is challenging. The present article demonstrates the effect of the richness, relative permeability curves, and skin in Well Test Analysis of gas condensate reservoirs.
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Implementation of Ensemble Kalman Filter (EnKF) Technique in Well-Test Analysis of Gas Condensate Reservoirs
1st International Petroleum Conference and Exhibition Shiraz 2009, 2009Co-Authors: G. H. Montazeri, S.m. Behrouz, H. JamaliAbstract:In this paper the Ensemble Kalman Filtering technique (EnKF) is implemented to remove noise from Well Testing data of a gas condensate reservoir and estimate some important parameters such as critical condensate saturation, irreducible water saturation and distribution index which can be used in drawing relative permeability curves. In order to use EnKF, we developed a MATLAB computer program which dynamically interfaces with ECLIPSE300 numerical reservoir simulator. The conventional approches for interpretation of transient data in gas condensate reservoirs can be criticized in several ways. Because of complex nature of flow in such reservoirs, many simplifying assumptions have been made in order to find analytical solutions for diffusivity equation which is theoritical foundation for most of Well Test Analysis techniques , but these assumptions cause a great deal of error in final results. In addition to this, the available methodologies for Well Testing in such reservoirs are sensitive to measurment errors and flactuation in Test data, consequently, any inaccurate mesuarment can be really misleading. Therefore, we used EnKF technique to cover the deficiencies appear in previous Analysis methods. Furthermore, extracting relative permeability curves is the unique advantage of this technique.
Fariborz Rashidi - One of the best experts on this subject based on the ideXlab platform.
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Volatile oil Well Test Analysis: application of two-phase pseudo-pressure approach
Journal of Petroleum Exploration and Production Technology, 2019Co-Authors: Hamid Baniasadi, Fariborz RashidiAbstract:This study investigates flow behavior in the volatile oil reservoirs with two‐phase flow around the Wellbore and the application of two-phase pseudo-pressure function for Well Test Analysis in such volatile oil reservoirs. To this end, flow behavior and saturation profile of the volatile oil reservoirs with flowing bottom-hole pressure below the bubble point pressure are investigated using a synthetic reservoir model. Subsequently, Well Test behavior of this reservoir in drawdown and buildup Tests are examined. Finally, the application of two-phase pseudo‐pressure concept is examined for analyzing Well Test data of the volatile oil reservoir. It is shown that two-phase flow near the Wellbore causes a composite behavior in Well Test data with decreasing mobility during drawdowns and increasing mobility during buildups. Moreover, employing normalized two-phase pseudo-pressure function introduced in this study is found to be a suitable method for Well Test Analysis in volatile oil reservoirs. Using the aforementioned method, effective permeability and Wellbore skin are estimated by eliminating the effect of gas saturation on the Well Test results.
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Effect of components composition of condensate reservoirs on Well Test Analysis: An experimental design approach
Journal of Natural Gas Science and Engineering, 2014Co-Authors: Arash Azamifard, Seyed Hamidreza Yousefi, Fariborz RashidiAbstract:Gas condensate is a challenging fluid in reservoir due to difficulties arising from condensate dropout around the Well. Condensate blockage complicates simulating the behavior of this fluid especially in Well Testing. The common approach in gas condensate Well Testing is using gas single-phase pseudo-pressure. In this study, statistical approach is applied to Well Test Analysis in order to investigate the effect of fluid composition on reservoir behavior. Mixture design controls the number of otherwise numerous Well Testing of fluids to a limited number. The output data of Well Testings are then used for multivariable regression to create proxy models of reservoir and fluid properties including initial pressure of reservoir, gas permeability in condensate zone and maximum liquid dropout of fluids. Results show that proposed model efficiently simulates mentioned properties with high R-squared values. Results also show that the intensity of condensate formation in the reservoir is a strong function of rich components composition in the reservoir. 2014 Published by Elsevier B.V.
Kexin Liu - One of the best experts on this subject based on the ideXlab platform.
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Well Test Analysis for Fractured and Vuggy Carbonate Reservoirs of Well Drilling in Large Scale Cave
Energies, 2018Co-Authors: Cuiqiao Xing, Hong-jun Yin, Kexin LiuAbstract:A Well Test Analysis model for fractured and vuggy carbonate reservoir of Wells drilling in large scale cave considering Wellbore storage and skin factor is established in this paper. The Laplace transformation and Stehfest numerical inversion are applied to obtain the results of Wellbore pressure. Through the sensitivity Analysis of different parameters for the Well Test typical curves, it is found that the change of the Well Test curves is in accordance with the theoretical Analysis. With the increase of skin factor, the hump of Well Test typical curves is steeper. The storage ratio influences the depth and width of the concave in the pressure derivative curves. The cross flow coefficient mainly affects the position of the concave occurrence in the pressure derivative curves. The dimensionless reservoir radius mainly affects the middle and late stages of the log-log pressure type curves, and the later Well Test curves will be upturned for sealed boundary. The duration of the early stage of the log-log curves will become longer when drilling in large scale cave. The effective Well radius is increased to a certain extent, which is in full agreement with the conclusions in this paper. The size of the caves has the same effect on the Well Test typical curves as Wellbore storage coefficient. Due to acidification, fracturing, and other reasons, the boundary of the cave will collapse. Therefore, considering the Wellbore storage coefficient and skin effect is very important during Well Testing. However, the existing models for Well Testing of fractured and vuggy carbonate reservoir often ignore the Wellbore storage coefficient and skin effect. For fractured and vuggy carbonate reservoirs of Well drilling in large scale cave, the existing models are not applicable. Since the previous models are mostly based on the triple-porosity medium and the equivalent continuum. The Well Test model for Well drilling in large scale cave of fracture-cavity carbonate reservoirs with Wellbore storage coefficient and skin factor in this work has significant application value for oil field.
