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Salam Al-rbeawi - One of the best experts on this subject based on the ideXlab platform.

  • Pseudo-steady state Inflow Performance relationship of reservoirs undergoing multiphase flow and different wellbore conditions
    Journal of Natural Gas Science and Engineering, 2019
    Co-Authors: Salam Al-rbeawi
    Abstract:

    Abstract This paper introduces an integrated approach for the Inflow Performance relationship of reservoirs that undergo multiphase flow conditions and drained by vertical wells with different wellbore conditions. The main objective is eliminating uncertainties that govern predicting reservoir Performance by assuming single phase flow in the porous media. The proposed approach includes developing several models for multiphase flow conditions using PVT data and relative permeability curves. These models are assembled with the Inflow Performance relationship to substantially approaching the realistic reservoir pressure/flow rate trend with time. Three tasks are conducted in this study. The first is developing three models for the three reservoir fluid compressibility functions [ f ( C o ) ] , [ f ( C g ) ] , and [ f ( w ) ] that consider the changes in comperssibilities with reservoir pressure. These functions are dependent on reservoir fluids properties that are in turn functions of reservoir pressure. While the second involves developing five models of reservoir fluid mobilities using relative permeability curves and the three functions of reservoir fluid comperssibilities. In this task the change in reservoir fluid saturations and the three saturations are calculated and used to calculate relative permeabilities at different reservoir pressures. Multiphase flow reservoir pressure function [ f ( P ) m p ] is estimated in third task and used to predict the Inflow Performance relationships for different wellbore inner boundary conditions i.e. constant Sandface flow rate and constant wellbore pressure. The models in the three tasks are obtained by multi-regression analysis of PVT data and relative permeability curves. The outcomes of this study are: 1) Developing models for reservoir fluid motilities and comperssibilities using PVT data and relative permeabilities curves by multi-regression analysis. 2) Considering the impact of multiphase flow in the porous media by generating multiphase flow pressure function [ f ( P ) m p ] . 3) Predicting Inflow Performance relationships for multiphase flow for different wellbore inner boundary conditions. The study has pointed out: 1) Productivity index of multiphase flow is less than the index for single phase flow. 2) There are no significant differences in the Inflow Performance relationships of single and multiphase flow for the two inner wellbore boundary conditions, however, constant Sandface flow rate may have better Inflow Performance relationship than constant wellbore pressure. 3) Most of the models generated by multi-regression analysis exhibits high accuracy (high R-squared value). 4) The proposed models may not have similar trendlines for different reservoirs.

  • Transient and Pseudo-Steady-State Inflow Performance Relationships for Multiphase Flow in Fractured Unconventional Reservoirs
    Transport in Porous Media, 2019
    Co-Authors: Salam Al-rbeawi
    Abstract:

    The objective of this paper is developing new methodology for constructing the Inflow Performance relationships (IPRs) of unconventional reservoirs experiencing multiphase flow. The motivation is eliminating the uncertainties of using single-phase flow IPRs and approaching realistic representation and simulation to reservoir pressure–flow rate relationships throughout the entire life of production. Several analytical models for the pressure drop and decline rate as wells productivity index of two wellbore conditions, constant Sandface flow rate and constant wellbore pressure, are presented in this study. Several deterministic models are also proposed in this study for multiphase reservoir total mobility and compressibility using multi-regression analysis of PVT data and relative permeability curves of different reservoir fluids. These deterministic models are coupled with the analytical models of pressure drop, decline rate, and productivity index to construct the pressure–flow rate relationships (IPRs) during transient and pseudo-steady-state production time. Transient IPRs are generated for early-time hydraulic fracture linear flow regime and intermediate-time bilinear and trilinear flow regimes, while steady-state IPRs are generated for pseudo-steady-state flow regime in case of constant Sandface flow rate and boundary-dominated flow regime in case of constant wellbore pressure. The outcomes of this study are as follows: (1) introducing the impact of multiphase flow to the IPRs of unconventional reservoirs; (2) developing deterministic models for reservoir total mobility and compressibility using multi-regression analysis of PVT data and relative permeability curves; (3) developing analytical models for different flow regimes that could be developed during the entire production life of reservoirs; (4) predicting transient and steady-state IPRs of multiphase flow for different wellbore conditions. The study has pointed out: (1) Multiphase flow conditions have significant impact on reservoir IPRs. (2) Multiphase reservoir total mobility and compressibility exhibit significant change with reservoir pressure. (3) Constant Sandface flow rate may demonstrate IPR better than constant wellbore pressure. (4) Late production time is not affected by multiphase flow conditions similar to transient state flow at early and intermediate production time.

Claudio Alimonti - One of the best experts on this subject based on the ideXlab platform.

  • using transient Inflow Performance relationships to model the dynamic interaction between reservoir and wellbore during pressure testing
    Journal of Energy Resources Technology-transactions of The Asme, 2008
    Co-Authors: Aldo Costantini, Gioia Falcone, G F Hewitt, Claudio Alimonti
    Abstract:

    The fundamental understanding of the dynamic interactions between multiphase flow in the reservoir and that in the wellbore remains surprisingly weak. The classical way of dealing with these interactions is via Inflow Performance relationships (IPRs), where the Inflow from the reservoir is related to the pressure at the bottom of the well, which is a function of the multiphase flow behavior in the well. A steady-state IPRs are normally adopted, but their use may be erroneous when transient multiphase flow conditions occur. The transient multiphase flow in the wellbore causes problems in well test interpretation when the well is shut-in at the surface and the bottomhole pressure is measured. The pressure buildup (PBU) data recorded during a test can be dominated by transient wellbore effects (e.g., phase change, flow reversal, and re-entry of the denser phase into the producing zone), making it difficult to distinguish between true reservoir features and transient wellbore artifacts. This paper introduces a method to derive the transient IPRs at bottomhole conditions in order to link the wellbore to the reservoir during PBU. A commercial numerical simulator was used to build a simplified reservoir model (single well, radial coordinates, homogeneous rock properties) using published data from a gas condensate field in the North Sea. In order to exclude wellbore effects from the investigation of the transient Inflow from the reservoir, the simulation of the wellbore was omitted from the model. Rather than the traditional flow rate at surface conditions, bottomhole pressure was imposed to constrain the simulation. This procedure allowed the flow rate at the sand face to be different from zero during the early times of the PBU, even if the surface flow rate is equal to zero. As a result, a transient IPR at bottomhole conditions was obtained for the given field case and for a specific set of time intervals, time steps, and bottomhole pressure. In order to validate the above simulation approach, a preliminary evaluation of the required experimental setup was carried out. The setup would allow the investigation of the dynamic interaction between the reservoir, the near-wellbore region, and the well, represented by a pressured vessel, a cylindrical porous medium, and a vertical pipe, respectively.

  • using transient Inflow Performance relationships to model the dynamic interaction between reservoir and wellbore during pressure testing
    ASME 2007 26th International Conference on Offshore Mechanics and Arctic Engineering, 2007
    Co-Authors: Aldo Costantini, Gioia Falcone, G F Hewitt, Claudio Alimonti
    Abstract:

    The fundamental understanding of the dynamic interactions between multiphase flow in the reservoir and that in the wellbore remains surprisingly weak. The classical way of dealing with these interactions is via Inflow Performance relationships (IPR’s), where the Inflow from the reservoir is related to the pressure at the bottom of the well, which is a function of the multiphase flow behaviour in the well. Steady-state IPR’s are normally adopted, but their use may be erroneous when transient multiphase flow conditions occur. Transient multiphase flow in the wellbore causes problems in well test interpretation when the well is shut-in at surface and the bottomhole pressure is measured. Pressure build-up (PBU) data recorded during a test can be dominated by transient wellbore effects (e.g. phase change, flow reversal and re-entry of the denser phase into the producing zone), making it difficult to distinguish between true reservoir features and transient wellbore artefacts. This paper introduces a method to derive the transient IPR’s at bottomhole conditions in order to link the wellbore to the reservoir during PBU. A commercial numerical simulator was used to build a simplified reservoir model (single well, radial co-ordinates, homogeneous rock properties) using published data from a gas condensate field in the North Sea. In order to exclude wellbore effects from the investigation of the transient Inflow from the reservoir, the simulation of the wellbore was omitted from the model. Rather than the traditional flow rate at surface conditions, bottomhole pressure was imposed to constrain the simulation. This procedure allowed the flow rate at the sand face to be different from zero during the early times of the PBU, even if the surface flow rate is equal to zero. As a result, a transient IPR at bottomhole conditions was obtained for the given field case and for a specific set of time intervals, time steps and bottomhole pressure. In order to validate the above simulation approach, a preliminary evaluation of the required experimental set-up was carried out. The set-up would allow the investigation of the dynamic interaction between the reservoir, the near-wellbore region and the well, represented by a pressured vessel, a cylindrical porous medium and a vertical pipe, respectively.Copyright © 2007 by ASME

Sara L Moya - One of the best experts on this subject based on the ideXlab platform.

  • Inflow Performance relationships in geothermal and petroleum reservoir engineering: A review of the state of the art
    Geothermics, 2008
    Co-Authors: Alfonso Aragón, Sara L Moya, Alfonso Garcia-gutierrez
    Abstract:

    Abstract The different Inflow Performance relationships (IPRs) that have been proposed in geothermal and petroleum reservoir engineering are reviewed. The applicability of these relationships to well production tests is analyzed, and the geothermal IPRs for pure water, for the binary H 2 O–CO 2 and ternary H 2 O–CO 2 –NaCl mixtures (with different salinities) are presented. The method to determine the maximum flow rate for a well is described. Two representative IPRs for petroleum systems and two for geothermal systems that consider the fluid as a ternary mixture H 2 O–CO 2 –NaCl (for salinities less than 5%, and between 5% and 20%) are compared. It is concluded that IPRs may be used to determine the maximum flowrate of a well at any time during its productive life.

  • prediction of mass deliverability from a single wellhead measurement and geothermal Inflow Performance reference curves
    Geothermics, 1998
    Co-Authors: Sara L Moya, Eduardo R Iglesias, Alfonso Aragón, E Santoyo
    Abstract:

    We propose a method to estimate mass deliverability curves for geothermal wells from a single wellhead measurement of pressure, mass flowrate and enthalpy (P, W, h)wh and the known reservoir pressure. This method takes advantage of dimensionless Geothermal Inflow Performance Relationships (dimensionless GIPRs), which we introduced in earlier papers. One advantage of the proposed method is that it would significantly shorten flow tests needed to obtain deliverability curves. Shorter flow tests would lessen costs and greatly reduce the volume of disposal fluids, with obvious ecological advantages; in some cases they could be the only economic option. We tested our method with data from a commercial geothermal well. The resulting estimated deliverability curves are well within the errors of the method used to measure the input wellhead parameters, which suggests that our method could be generally applicable. Further studies, already underway, are necessary to confirm this.

  • Applicability of geothermal Inflow Performance reference curves to CO2-bearing reservoirs
    Geothermics, 1998
    Co-Authors: Eduardo R Iglesias, Sara L Moya
    Abstract:

    Abstract Vogel's hugely successful Inflow Performance Reference curve ( IPR ) has been used for many years by the petroleum industry to estimate well deliverabilities. In 1990 we developed the first Geothermal Inflow Performance Reference curves ( GIPRs ), for two-phase Inflow of pure water. Recently we followed up with a revised set of GIPRs for pure water and a second set that accounts for effects of CO 2 on the deliverability of geothermal reservoirs. These curves relate (a) dimensionless mass flowrate with dimensionless flowing pressure and (b) dimensionless thermal power with dimensionless flowrate, both at the feedpoint. In this work we explore the applicability of the reference curve (a) to data from a CO 2 -bearing geothermal reservoir. We find that there is excellent agreement between predicted and observed Inflow Performance in this case. These results suggest that our curve (a) should also be applicable to other CO 2 -bearing geothermal reservoirs.

E Santoyo - One of the best experts on this subject based on the ideXlab platform.

  • prediction of mass deliverability from a single wellhead measurement and geothermal Inflow Performance reference curves
    Geothermics, 1998
    Co-Authors: Sara L Moya, Eduardo R Iglesias, Alfonso Aragón, E Santoyo
    Abstract:

    We propose a method to estimate mass deliverability curves for geothermal wells from a single wellhead measurement of pressure, mass flowrate and enthalpy (P, W, h)wh and the known reservoir pressure. This method takes advantage of dimensionless Geothermal Inflow Performance Relationships (dimensionless GIPRs), which we introduced in earlier papers. One advantage of the proposed method is that it would significantly shorten flow tests needed to obtain deliverability curves. Shorter flow tests would lessen costs and greatly reduce the volume of disposal fluids, with obvious ecological advantages; in some cases they could be the only economic option. We tested our method with data from a commercial geothermal well. The resulting estimated deliverability curves are well within the errors of the method used to measure the input wellhead parameters, which suggests that our method could be generally applicable. Further studies, already underway, are necessary to confirm this.

Aldo Costantini - One of the best experts on this subject based on the ideXlab platform.

  • using transient Inflow Performance relationships to model the dynamic interaction between reservoir and wellbore during pressure testing
    Journal of Energy Resources Technology-transactions of The Asme, 2008
    Co-Authors: Aldo Costantini, Gioia Falcone, G F Hewitt, Claudio Alimonti
    Abstract:

    The fundamental understanding of the dynamic interactions between multiphase flow in the reservoir and that in the wellbore remains surprisingly weak. The classical way of dealing with these interactions is via Inflow Performance relationships (IPRs), where the Inflow from the reservoir is related to the pressure at the bottom of the well, which is a function of the multiphase flow behavior in the well. A steady-state IPRs are normally adopted, but their use may be erroneous when transient multiphase flow conditions occur. The transient multiphase flow in the wellbore causes problems in well test interpretation when the well is shut-in at the surface and the bottomhole pressure is measured. The pressure buildup (PBU) data recorded during a test can be dominated by transient wellbore effects (e.g., phase change, flow reversal, and re-entry of the denser phase into the producing zone), making it difficult to distinguish between true reservoir features and transient wellbore artifacts. This paper introduces a method to derive the transient IPRs at bottomhole conditions in order to link the wellbore to the reservoir during PBU. A commercial numerical simulator was used to build a simplified reservoir model (single well, radial coordinates, homogeneous rock properties) using published data from a gas condensate field in the North Sea. In order to exclude wellbore effects from the investigation of the transient Inflow from the reservoir, the simulation of the wellbore was omitted from the model. Rather than the traditional flow rate at surface conditions, bottomhole pressure was imposed to constrain the simulation. This procedure allowed the flow rate at the sand face to be different from zero during the early times of the PBU, even if the surface flow rate is equal to zero. As a result, a transient IPR at bottomhole conditions was obtained for the given field case and for a specific set of time intervals, time steps, and bottomhole pressure. In order to validate the above simulation approach, a preliminary evaluation of the required experimental setup was carried out. The setup would allow the investigation of the dynamic interaction between the reservoir, the near-wellbore region, and the well, represented by a pressured vessel, a cylindrical porous medium, and a vertical pipe, respectively.

  • using transient Inflow Performance relationships to model the dynamic interaction between reservoir and wellbore during pressure testing
    ASME 2007 26th International Conference on Offshore Mechanics and Arctic Engineering, 2007
    Co-Authors: Aldo Costantini, Gioia Falcone, G F Hewitt, Claudio Alimonti
    Abstract:

    The fundamental understanding of the dynamic interactions between multiphase flow in the reservoir and that in the wellbore remains surprisingly weak. The classical way of dealing with these interactions is via Inflow Performance relationships (IPR’s), where the Inflow from the reservoir is related to the pressure at the bottom of the well, which is a function of the multiphase flow behaviour in the well. Steady-state IPR’s are normally adopted, but their use may be erroneous when transient multiphase flow conditions occur. Transient multiphase flow in the wellbore causes problems in well test interpretation when the well is shut-in at surface and the bottomhole pressure is measured. Pressure build-up (PBU) data recorded during a test can be dominated by transient wellbore effects (e.g. phase change, flow reversal and re-entry of the denser phase into the producing zone), making it difficult to distinguish between true reservoir features and transient wellbore artefacts. This paper introduces a method to derive the transient IPR’s at bottomhole conditions in order to link the wellbore to the reservoir during PBU. A commercial numerical simulator was used to build a simplified reservoir model (single well, radial co-ordinates, homogeneous rock properties) using published data from a gas condensate field in the North Sea. In order to exclude wellbore effects from the investigation of the transient Inflow from the reservoir, the simulation of the wellbore was omitted from the model. Rather than the traditional flow rate at surface conditions, bottomhole pressure was imposed to constrain the simulation. This procedure allowed the flow rate at the sand face to be different from zero during the early times of the PBU, even if the surface flow rate is equal to zero. As a result, a transient IPR at bottomhole conditions was obtained for the given field case and for a specific set of time intervals, time steps and bottomhole pressure. In order to validate the above simulation approach, a preliminary evaluation of the required experimental set-up was carried out. The set-up would allow the investigation of the dynamic interaction between the reservoir, the near-wellbore region and the well, represented by a pressured vessel, a cylindrical porous medium and a vertical pipe, respectively.Copyright © 2007 by ASME