The Experts below are selected from a list of 258 Experts worldwide ranked by ideXlab platform

Ovadia Shoham - One of the best experts on this subject based on the ideXlab platform.

  • A Unified Model for Predicting Flowing Temperature Distribution in Wellbores and Pipelines
    Spe Production Engineering, 1992
    Co-Authors: I.n. Alves, Francisco J S Alhanati, Ovadia Shoham
    Abstract:

    This paper presents a general and unified equation for Flowing Temperature prediction that is applicable for the entire range of inclination angles. The equation degenerates into Ramey's equations for ideal gas or incompressible liquid and into the Coulter and Bardon equation, with the appropriate assumptions. This work also proposes an approximate method for calculating the Joule- Thomson coefficient for black-oil models

  • A Unified Model for Predicting Flowing Temperature Distribution in Wellbores and Pipelines
    SPE Production Engineering, 1992
    Co-Authors: I.n. Alves, Francisco J S Alhanati, Ovadia Shoham
    Abstract:

    Summary This paper presents a general and unified equation for Flowing Temperature prediction that is applicable for the entire range of inclination angles. The equation degenerates into Ramey's equations for ideal gas or incompressible liquid and into the Coulter and Bardon equation, with the appropriate assumptions. This work also proposes an approximate method for calculating the Joule-Thomson coefficient for black-oil models. Introduction Flowing Temperature distribution often is predicted with different methods for pipelines and wellbores. The Ramey method usually is used for predicting wellbore Temperature distribution. This method rigorously incorporates the complex process of transient heat transfer between the wellbore and the reservoir. Ramey's method, however, is limited to either ideal gas or incompressible liquid flow. The Coulter and Bardon equation commonly is used for pipeline Temperature prediction. A more rigorous thermodynamic behavior of the Flowing fluid is taken into account, incorporating the Joule-Thomson coefficient. Although the Coulter and Bardon equation originally was derived for gas flow, it also is used for single-phase liquid or two-phase flow. This equation is limited, however, by the assumptions of steady-state heat transfer with a constant-Temperature environment and horizontal flow.

Mofazzal Hossain - One of the best experts on this subject based on the ideXlab platform.

  • a practical method for the evaluation of the joule thomson effects to predict Flowing Temperature profile in gas producing wells
    Journal of Natural Gas Science and Engineering, 2015
    Co-Authors: N. Tarom, Mofazzal Hossain
    Abstract:

    Abstract Accurate evaluation of Joule Thomson Coefficient (JTC) is important for the prediction of Flowing Temperature profile in a gas producing well. The evaluation of JTC requires the determination of derivative of gas compressibility factor with respect to change in Temperature at constant pressure (i.e. (∂Z/∂T)p). This may be determined using an appropriate Equations of States (EOS) for a given gas mixture where compositions details are known. In many cases, the details of gas compositions and its associated properties are not known, especially at the appraisal stage. In this study, a simplified practical method has been developed to predict the JTC. This paper presents details of the mathematical model based on which the proposed method is developed. The terms Z and (∂Z/∂T)p have been predicted for a number of gas mixtures using proposed method, and compared the results with those obtained using Peng–Robinson Equation of State (PR EOS) and HYSYS software to provide the accuracy of this work for evaluation of compressibility factor for gas mixtures. The results showed close agreement between two methods. The model is applied to represent gas field in order to predict the Temperature profile for gas production wells. A sample case study has been carried out to investigate the Flowing Temperature profile along a gas producing well. It is demonstrated that the proposed method can be reliably used for evaluation of well following Temperature profile along gas producing wellbores.

N. Tarom - One of the best experts on this subject based on the ideXlab platform.

  • A new practical method to evaluate the Joule–Thomson coefficient for natural gases
    Journal of Petroleum Exploration and Production Technology, 2018
    Co-Authors: N. Tarom, Md. Mofazzal Hossain, Azar Rohi
    Abstract:

    The Joule–Thomson (JT) phenomenon, the study of fluid Temperature changes for a given pressure change at constant enthalpy, has great technological and scientific importance for designing, maintenance and prediction of hydrocarbon production. The phenomenon serves vital role in many facets of hydrocarbon production, especially associated with reservoir management such as interpretation of Temperature logs of production and injection well, identification of water and gas entry locations in multilayer production scenarios, modelling of thermal response of hydrocarbon reservoirs and prediction of wellbore Flowing Temperature profile. The purpose of this study is to develop a new method for the evaluation of JT coefficient, as an essential parameter required to account the Joule–Thomson effects while predicting the Flowing Temperature profile for gas production wells. To do this, a new correction factor, C _NM, has been developed through numerical analysis and proposed a practical method to predict C _NM which can simplify the prediction of Flowing Temperature for gas production wells while accounting the Joule–Thomson effect. The developed correlation and methodology were validated through an exhaustive survey which has been conducted with 20 different gas mixture samples. For each sample, the model has been run for a wide range of Temperature and pressure conditions, and the model was rigorously verified by comparison of the results estimated throughout the study with the results obtained from HYSYS and Peng–Robinson equation of state. It is observed that model is very simple and robust yet can accurately predict the Joule–Thomson effect.

  • a new practical method to evaluate the joule thomson coefficient for natural gases
    Journal of Petroleum Exploration and Production Technology, 2018
    Co-Authors: N. Tarom, Md. Mofazzal Hossain, Azar Rohi
    Abstract:

    The Joule–Thomson (JT) phenomenon, the study of fluid Temperature changes for a given pressure change at constant enthalpy, has great technological and scientific importance for designing, maintenance and prediction of hydrocarbon production. The phenomenon serves vital role in many facets of hydrocarbon production, especially associated with reservoir management such as interpretation of Temperature logs of production and injection well, identification of water and gas entry locations in multilayer production scenarios, modelling of thermal response of hydrocarbon reservoirs and prediction of wellbore Flowing Temperature profile. The purpose of this study is to develop a new method for the evaluation of JT coefficient, as an essential parameter required to account the Joule–Thomson effects while predicting the Flowing Temperature profile for gas production wells. To do this, a new correction factor, C NM, has been developed through numerical analysis and proposed a practical method to predict C NM which can simplify the prediction of Flowing Temperature for gas production wells while accounting the Joule–Thomson effect. The developed correlation and methodology were validated through an exhaustive survey which has been conducted with 20 different gas mixture samples. For each sample, the model has been run for a wide range of Temperature and pressure conditions, and the model was rigorously verified by comparison of the results estimated throughout the study with the results obtained from HYSYS and Peng–Robinson equation of state. It is observed that model is very simple and robust yet can accurately predict the Joule–Thomson effect.

  • a practical method for the evaluation of the joule thomson effects to predict Flowing Temperature profile in gas producing wells
    Journal of Natural Gas Science and Engineering, 2015
    Co-Authors: N. Tarom, Mofazzal Hossain
    Abstract:

    Abstract Accurate evaluation of Joule Thomson Coefficient (JTC) is important for the prediction of Flowing Temperature profile in a gas producing well. The evaluation of JTC requires the determination of derivative of gas compressibility factor with respect to change in Temperature at constant pressure (i.e. (∂Z/∂T)p). This may be determined using an appropriate Equations of States (EOS) for a given gas mixture where compositions details are known. In many cases, the details of gas compositions and its associated properties are not known, especially at the appraisal stage. In this study, a simplified practical method has been developed to predict the JTC. This paper presents details of the mathematical model based on which the proposed method is developed. The terms Z and (∂Z/∂T)p have been predicted for a number of gas mixtures using proposed method, and compared the results with those obtained using Peng–Robinson Equation of State (PR EOS) and HYSYS software to provide the accuracy of this work for evaluation of compressibility factor for gas mixtures. The results showed close agreement between two methods. The model is applied to represent gas field in order to predict the Temperature profile for gas production wells. A sample case study has been carried out to investigate the Flowing Temperature profile along a gas producing well. It is demonstrated that the proposed method can be reliably used for evaluation of well following Temperature profile along gas producing wellbores.

I.n. Alves - One of the best experts on this subject based on the ideXlab platform.

  • A Unified Model for Predicting Flowing Temperature Distribution in Wellbores and Pipelines
    Spe Production Engineering, 1992
    Co-Authors: I.n. Alves, Francisco J S Alhanati, Ovadia Shoham
    Abstract:

    This paper presents a general and unified equation for Flowing Temperature prediction that is applicable for the entire range of inclination angles. The equation degenerates into Ramey's equations for ideal gas or incompressible liquid and into the Coulter and Bardon equation, with the appropriate assumptions. This work also proposes an approximate method for calculating the Joule- Thomson coefficient for black-oil models

  • A Unified Model for Predicting Flowing Temperature Distribution in Wellbores and Pipelines
    SPE Production Engineering, 1992
    Co-Authors: I.n. Alves, Francisco J S Alhanati, Ovadia Shoham
    Abstract:

    Summary This paper presents a general and unified equation for Flowing Temperature prediction that is applicable for the entire range of inclination angles. The equation degenerates into Ramey's equations for ideal gas or incompressible liquid and into the Coulter and Bardon equation, with the appropriate assumptions. This work also proposes an approximate method for calculating the Joule-Thomson coefficient for black-oil models. Introduction Flowing Temperature distribution often is predicted with different methods for pipelines and wellbores. The Ramey method usually is used for predicting wellbore Temperature distribution. This method rigorously incorporates the complex process of transient heat transfer between the wellbore and the reservoir. Ramey's method, however, is limited to either ideal gas or incompressible liquid flow. The Coulter and Bardon equation commonly is used for pipeline Temperature prediction. A more rigorous thermodynamic behavior of the Flowing fluid is taken into account, incorporating the Joule-Thomson coefficient. Although the Coulter and Bardon equation originally was derived for gas flow, it also is used for single-phase liquid or two-phase flow. This equation is limited, however, by the assumptions of steady-state heat transfer with a constant-Temperature environment and horizontal flow.

Francisco J S Alhanati - One of the best experts on this subject based on the ideXlab platform.

  • A Unified Model for Predicting Flowing Temperature Distribution in Wellbores and Pipelines
    Spe Production Engineering, 1992
    Co-Authors: I.n. Alves, Francisco J S Alhanati, Ovadia Shoham
    Abstract:

    This paper presents a general and unified equation for Flowing Temperature prediction that is applicable for the entire range of inclination angles. The equation degenerates into Ramey's equations for ideal gas or incompressible liquid and into the Coulter and Bardon equation, with the appropriate assumptions. This work also proposes an approximate method for calculating the Joule- Thomson coefficient for black-oil models

  • A Unified Model for Predicting Flowing Temperature Distribution in Wellbores and Pipelines
    SPE Production Engineering, 1992
    Co-Authors: I.n. Alves, Francisco J S Alhanati, Ovadia Shoham
    Abstract:

    Summary This paper presents a general and unified equation for Flowing Temperature prediction that is applicable for the entire range of inclination angles. The equation degenerates into Ramey's equations for ideal gas or incompressible liquid and into the Coulter and Bardon equation, with the appropriate assumptions. This work also proposes an approximate method for calculating the Joule-Thomson coefficient for black-oil models. Introduction Flowing Temperature distribution often is predicted with different methods for pipelines and wellbores. The Ramey method usually is used for predicting wellbore Temperature distribution. This method rigorously incorporates the complex process of transient heat transfer between the wellbore and the reservoir. Ramey's method, however, is limited to either ideal gas or incompressible liquid flow. The Coulter and Bardon equation commonly is used for pipeline Temperature prediction. A more rigorous thermodynamic behavior of the Flowing fluid is taken into account, incorporating the Joule-Thomson coefficient. Although the Coulter and Bardon equation originally was derived for gas flow, it also is used for single-phase liquid or two-phase flow. This equation is limited, however, by the assumptions of steady-state heat transfer with a constant-Temperature environment and horizontal flow.