Radial Composite Reservoir

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Deane G Shank - One of the best experts on this subject based on the ideXlab platform.

  • a new model for a fractured well in a Radial Composite Reservoir
    Spe Formation Evaluation, 1993
    Co-Authors: Weichun Chu, Deane G Shank
    Abstract:

    A flow problem was identified by using a pressure-derivative technique to analyze several hundred pressure-falloff tests from the Big Horn basin. To handle the problem, a new analytic model was developed to allow direct analysis of fractured wells with either finite conductivity or uniform flux in a Radial, Composite Reservoir. In this paper, the authors demonstrate that this simple model further explains the buildup-pressure behavior of a fractured well producing below dewpoint pressure in a gas-condensate Reservoir.

Matilde Montealegremadero - One of the best experts on this subject based on the ideXlab platform.

  • pressure and pressure derivative analysis for a well in a Radial Composite Reservoir with a non newtonian newtonian interface
    Ciencia Tecnologia y Futuro, 2010
    Co-Authors: Freddy Humberto Escobar, Javierandres Martinez, Matilde Montealegremadero
    Abstract:

    In many activities of the oil industry, engineers have to deal with completion and stimulation treatment fluids such as polymer solutions and some heavy crude oils which obey a non-Newtonian power-law behavior. When it is required to conduct a treatment with a non-Newtonian fluid in an oil-bearing formation, this comes in contact with conventional oil which possesses a Newtonian nature. This implies the definition of two media with entirely different mobilities. If a pressure test is run in such a system, the interpretation of data from such a test through the use of conventional straight-line method may be erroneous and may not provide a way for verification of the results obtained. In this work, the signature of the pressure derivative curve is investigated to understand and ease the interpretation of the well test data in Reservoirs with non-Newtonian power-law fluids. Specifically, the Tiab's Direct Synthesis (TDS) technique is implemented using some characteristics features found on the pressure and pressure derivative curves. Hence, new equations are introduced to estimate permeability, non-Newtonian bank radius and skin factor. Permeability can be verified. The proposed methodology was successfully verified by its application to an example reported in the literature and a synthetic case.

Weichun Chu - One of the best experts on this subject based on the ideXlab platform.

  • a new model for a fractured well in a Radial Composite Reservoir
    Spe Formation Evaluation, 1993
    Co-Authors: Weichun Chu, Deane G Shank
    Abstract:

    A flow problem was identified by using a pressure-derivative technique to analyze several hundred pressure-falloff tests from the Big Horn basin. To handle the problem, a new analytic model was developed to allow direct analysis of fractured wells with either finite conductivity or uniform flux in a Radial, Composite Reservoir. In this paper, the authors demonstrate that this simple model further explains the buildup-pressure behavior of a fractured well producing below dewpoint pressure in a gas-condensate Reservoir.

Wilson, Benton Wade - One of the best experts on this subject based on the ideXlab platform.

  • Modeling of performance behavior in gas condensate Reservoirs using a variable mobility concept
    Texas A&M University, 2004
    Co-Authors: Wilson, Benton Wade
    Abstract:

    The proposed work provides a concept for predicting well performance behavior in a gas condensate Reservoir using an empirical model for gas mobility. The proposed model predicts the behavior of the gas permeability (or mobility) function in the Reservoir as condensate evolves and the gas permeability is reduced in the near-well region due to the "condensate bank". The proposed model is based on observations of simulated Reservoir performance and predicts the behavior of the gas permeability over time and Radial distance. This model is given by: The proposed concept has potential applications in the development of a pressure-time-radius solution for gas condensate Reservoirs experiencing this type of mobility behavior. We recognize that the proposed concept (i.e., a Radially-varying gas permeability) is oversimplified, in particular, it ignores the diffusive effects of the condensate (i.e., the viscosity-compressibility behavior). However, we have effectively validated the proposed model using literature results derived from numerical simulation. This new solution is presented graphically in the form of "type curves." We propose that the "time" form of this solution be used for applications in well test analysis. Previous developments used for the analysis of well test data from gas condensate Reservoirs consider the Radial Composite Reservoir model, which utilizes a "step change" in permeability at some Radial distance away from the wellbore. Using our proposed solution we can visualize the effect of the varying gas permeability in time and radius (a suite of (dimensionless) radius and time format plots are provided). In short, we can visualize the evolution of the condensate zone as it evolves in time and Radial distance. A limitation is the simplified form of the kg profile as a function of radius and time - as well as the dependence/appropriateness of the α-parameter. While we suspect that the α-parameter represents the influence of both fluid and rock properties, we do not examine how such properties can be used to calculate the α-parameter

Freddy Humberto Escobar - One of the best experts on this subject based on the ideXlab platform.

  • pressure and pressure derivative analysis for a well in a Radial Composite Reservoir with a non newtonian newtonian interface
    Ciencia Tecnologia y Futuro, 2010
    Co-Authors: Freddy Humberto Escobar, Javierandres Martinez, Matilde Montealegremadero
    Abstract:

    In many activities of the oil industry, engineers have to deal with completion and stimulation treatment fluids such as polymer solutions and some heavy crude oils which obey a non-Newtonian power-law behavior. When it is required to conduct a treatment with a non-Newtonian fluid in an oil-bearing formation, this comes in contact with conventional oil which possesses a Newtonian nature. This implies the definition of two media with entirely different mobilities. If a pressure test is run in such a system, the interpretation of data from such a test through the use of conventional straight-line method may be erroneous and may not provide a way for verification of the results obtained. In this work, the signature of the pressure derivative curve is investigated to understand and ease the interpretation of the well test data in Reservoirs with non-Newtonian power-law fluids. Specifically, the Tiab's Direct Synthesis (TDS) technique is implemented using some characteristics features found on the pressure and pressure derivative curves. Hence, new equations are introduced to estimate permeability, non-Newtonian bank radius and skin factor. Permeability can be verified. The proposed methodology was successfully verified by its application to an example reported in the literature and a synthetic case.