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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, G F Hewitt, Gioia Falcone, 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, G F Hewitt, Gioia Falcone, 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

Gioia Falcone - One of the best experts on this subject based on the ideXlab platform.

  • Numerical Modeling of Fully-Transient Flow in the Near-Wellbore Region During Liquid Loading in Gas Wells
    Latin American and Caribbean Petroleum Engineering Conference, 2009
    Co-Authors: He Zhang, Gioia Falcone, Peter P. Valko, Catalin Teodoriu
    Abstract:

    In oil and gas field operations, the dynamic interactions between reservoir and wellbore cannot be ignored, especially during transient flow in the near-wellbore region. A particular instance of transient flow in the near-wellbore region is the intermittent response of a reservoir that is typical of liquid loading in gas wells. Despite the high level of attention that the industry has devoted to the alleviation of liquid loading, the fundamental understanding of the associated phenomena is still surprisingly weak. This applies not only to the flows in the wells, but also to the ways in which these flows interact with those in the reservoir. The classical way of dealing with these interactions, Inflow Performance Relationships (IPRs), relate the Inflow from the reservoir to the pressure at the bottom of the well, which is related to the multiphase flow behavior in the tubing. These Relationships are usually based on steady-state or pseudo steady-state assumptions. However, such IPRs may be inadequate when a transition from an acceptable liquid loading regime to an unacceptable occurs over a relatively small range of production rates and, hence, over a relatively short time. The most satisfactory solution would be to couple a transient model for the reservoir to a transient model for the well. This paper presents the results of a numerical modeling effort focused on the identification of the transient pressure profile in the near-wellbore region during fully transient flow conditions. The preliminary results, obtained for a single-phase (gas) situation and for a three-phase (oil-water-gas) situation, show a "U-shaped" pressure profile along the reservoir radius. The existence of a similar pressure profile could be the explanation for the reinjection of the heavier phase into the reservoir during liquid unloading in gas wells.

  • 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, G F Hewitt, Gioia Falcone, 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, G F Hewitt, Gioia Falcone, 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

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, G F Hewitt, Gioia Falcone, 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, G F Hewitt, Gioia Falcone, 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

G F Hewitt - 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, G F Hewitt, Gioia Falcone, 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, G F Hewitt, Gioia Falcone, 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

Fuad H. Qasem - One of the best experts on this subject based on the ideXlab platform.

  • Inflow Performance Relationships for layered solution-gas drive reservoir
    International Journal of Petroleum Engineering, 2016
    Co-Authors: Fuad H. Qasem, Adel Malallah, Ibrahim Sami Nashawi, Muhammad Irfan Mir
    Abstract:

    Inflow Performance relationship (IPR) is a very important tool to forecast well Performance. Existing IPR models are idealistic since they are developed for homogeneous reservoirs; therefore, they are inappropriate for layered systems. Consequently, there is a need for IPR models that efficiently describe layered reservoir Performance. This study investigates the effects of reservoir heterogeneity on IPR for layered solution-gas drive reservoirs. Multiphase flow in both two and multilayer reservoirs was simulated. Both fluid cross flow and no fluid cross flow among layers were considered. A stochastic simulation algorithm was used to generate various permeability realisations among layers. Three geostatistical models using uniform, Gaussian, and bimodal probability distributions were used to grasp optimum match between real reservoir behaviour and simulated data. The generated data were scrutinised to develop two accurate IPR equations. The first equation describes the well behaviour under current flowing conditions, whereas the second equation can be used to forecast future well Performance.

  • Modeling Inflow Performance Relationships for Wells Producing from Multi-Layer Solution-Gas Drive Reservoirs
    North Africa Technical Conference and Exhibition, 2013
    Co-Authors: Fuad H. Qasem, Adel Malallah, Ibrahim Sami Nashawi
    Abstract:

    Optimum field development strategy requires good knowledge of anticipated well Performance and future flowing condition variation. This practice involves continuous monitoring of surface facility network, wells, and reservoir. Thus, it is crucial for the petroleum engineer to possess the appropriate tools to efficiently forecast well behavior, design artificial lift equipment and stimulation treatments, forecast production, and improve the entire production system optimization. Inflow Performance relationship (IPR) is one of the vital tools required to monitor well Performance. Currently used Inflow Performance relationship models are idealistic in nature, mainly developed for homogeneous reservoirs, and not suitable for multi-layer systems with different permeabilities. Consequently, the available IPR Relationships do not provide accurate Performance of such reservoirs. Thus, there is an urgent need for new realistic IPR models that describe the actual reservoir Inflow Performance behavior more efficiently than t he available models. This study investigates the effects of reservoir heterogeneity on IPR curves for wells producing from multi-layer solutiongas drive reservoirs. To achieve the desired objectives a stochastic simulation algorithm known as simulated annealing was used to generate various permeability realizations among the stacked layers. The generated data were then thoroughly scrutinized and two simple yet accurate empirical IPR models were developed for heterogeneous two and multi-layer solutiongas drive reservoirs. Introduction In reservoir studies, Inflow Performance Relationship (IPR) of a well is an essential tool to assess the well Performance. It indicates the production behavior of a well and it will assist in determining the feasibility of producing a well. The IPR curve visualizes the relationship between the well’s producing bottomhole pressures and its corresponding production rates under a given reservoir condition. The shape of the curve is influenced by many factors such as the reservoir fluid composition, the existence of well zones, and the behavior of the fluid phases under reservoir flowing conditions. Gilbert introduced IPR curves in 1954 and through the years, these curves had several modifications. In 1968, Vogel introduced a mathematical dimensionless model for wells producing in bounded solution-gas drive reservoirs where the average reservoir pressure is less than the bubble-point pressure. Standing (1970, 1971) introduced a modified version of Vogel’s curve to characterize a well Performance for damaged wells and different depletion stages. In 1973, Fetkovich showed that the Performance curve for an oil well can be expressed by a more general equation similar to that used for a gas well. His developed equation was found to be valid for tests conducted for a variety of reservoir conditions even when the flowing pressures were well above the bubble-point pressure. Through time, IPR curves have been utilized in different applications in the petroleum industry. Weiss et al. (1981) employed a method of individual zone productivity combined with IPR testing to characterize two prolific offshore oil fields. Later, Brown (1982) combined well-Inflow Performance with tubing intake curves to prepare pressure/flow rate diagrams in order to properly select the best artificial lift method. Chu and Evans (1983) used a computer-based analysis to find the optimum production design for a naturally flowing water drive wells. They developed a group of graphs that are derived based on the Performance of IPR, vertical lift, choke, horizontal flow, and the surface equipments thermodynamics. To eliminate the need for conventional multipoint tests, Mishra and Caudle (1984) developed a new method to calculate the IPR curves for stabilized non-Darcy flow in unfractured gas reservoirs. On the other hand, other studies developed dimensionless IPR curves for fractured gas wells with positive, negative or zero skin effect

  • Modeling Inflow Performance Relationships for Wells Producing From Two-Layer Solution-Gas Drive Reservoirs Without Cross-Flow
    Petroleum Science and Technology, 2012
    Co-Authors: Fuad H. Qasem, Ibrahim Sami Nashawi, Adel Malallah
    Abstract:

    Abstract Continuous monitoring and accurate anticipation of the present and future Performance of the flowing wells and reservoirs constitute the cornerstone elements in the design of optimum field development strategy. It is crucial for the petroleum engineer to possess the appropriate tools that assist in efficiently predicting well behavior, designing artificial lift equipment, forecasting production, and optimizing the entire production system. Inflow Performance relationship (IPR) is one of the vital tools required to monitor well Performance. Existing Inflow Performance relationship models are idealistic and mainly designed for homogeneous reservoirs. However, most reservoirs around the world are heterogeneous and composed of layers of different permeabilities. Hence, there is an urgent need for new realistic IPR models that describe the actual reservoir Inflow Performance behavior more efficiently than the available models. The authors investigate the effects of reservoir heterogeneity on IPR curve...