Production Optimization in ESP Completions with Intelligent Well Technology by Using Downhole Chokes to Optimize ESP Performance

Vachon, Guy; Furui, Kenji

doi:10.2118/93621-ms

Cited by 6 publications

(4 citation statements)

References 2 publications

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“…A recent study (Vachon and Furui 2005) has shown that pumpassisted production could be achieved from both zones by use of a downhole SESP and a downhole choke. An alternative is a DESP completion and commingled production.…”

Section: Multiple Production Zonesmentioning

confidence: 99%

Analysis of Possible Applications of Dual ESPs—A Reservoir-Engineering Perspective

Davies

Narayanasamy

Kristensen

et al. 2008

SPE Production &Amp; Operations

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Relatively few field installations of a dual-electric submersiblepump (DESP) completion have been reported. In general, the purpose of the second pump was either to increase the pumping capacity, or to act as a backup to improve the reliability of the pumping system. However, DESPs potentially can address a much wider range of reservoir management challenges. This paper will analyze the performance of a DESP in a range of reservoir scenarios. It will show how DESP performance can be modeled by use of commercially available, coupled, well-performance and reservoir-simulation tools.Four DESP applications were analyzed. Where possible, the robustness of the numerical-modeling results will be compared with analytical predictions. DESPs gave improved oil production and recovery in reservoirs with strong aquifer support and became progressively more attractive in a layered-reservoir scenario as the pressure difference between the production zones increased. However, while DESPs had no significant advantages in a long, horizontal well placed in a homogeneous reservoir, they can increase recovery in a tilted, layered reservoir. A slim, deepwater well completed with a lower-capacity downhole pump and a larger (multiwell) seabed booster pump was shown to be a potentially attractive solution for some reservoir developments.This work provides a comparison of the drivers for the choice of a single electric submersible pump (SESP) and a DESP in the scenarios studied. It illustrates a modeling methodology and provides DESP-selection guidelines, thus aiding the increased application of this technology. MethodologyThe studies were carried out with the help of a two-phase (oil and water) simulation of a 3D reservoir model using the Eclipse TM 100 package. Wellflo TM was used to model the vertical-lift performance for the produced fluids through the wellbore and the pump performance under the various reservoir conditions. The results obtained were transferred to the Eclipse TM models in the form of vertical-flow-performance (VFP) tables. A detailed description of the model used as input for comparison of the Eclipse TM , the Wellflo TM and the analytical solutions is listed in Tables 1 and 2. Simulation results using the Eclipse TM and Wellflo TM programs were compared with appropriate analytical solutions where possible (see Appendix).

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Section: Multiple Production Zonesmentioning

confidence: 99%

Analysis of Possible Applications of Dual ESPs—A Reservoir-Engineering Perspective

Davies

Narayanasamy

Kristensen

et al. 2008

SPE Production &Amp; Operations

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show abstract

“…(Olijnik et al, 1996, Anderson, 2005, Vachon and Furui, 2005, Ali and Shafiq, 2008, Ansah et al, 2009, Soegiyono et al, 2010, Al-Mohanna et al, 2011. Related procedures and equipment are available for gas lifted wells with I-completions (Cedeno and Ortiz, 2007, Vasper, 2008, Iyamu et al, 2008, Stephenson et al, 2010.…”

mentioning

confidence: 99%

“…They describe how the ICV may be used to shut-in zones to avoid cross-flow when the AL is halted. (Vachon and Furui, 2005) optimized an ESP installed in I-well completions with ICVs. The ICV can be operated to reduce the drawdown by applying an extra pressure drop across the sand face.…”

mentioning

confidence: 99%

“…An accurate estimate of the reservoir's pressure decline, and the associated well outflow performance, must be available at the ESP system's design stage to ensure that a sufficient level of flow rate control is available during the ESP system's run life. As far as the ESP design is concerned, our paper will use some elements similar to the study by (Vachon and Furui, 2005), while concentrating more on the role of ON/OFF ICVs, the wellhead choke, and zonal shut-ins at the late production period.…”

mentioning

confidence: 99%

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Role of Artificial Lift in Wells With a Downhole, Flow Control Completion

Gasbarri

Muradov²,

Davies³

2013

SPE Offshore Europe Oil and Gas Conference and Exhibition

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Several hundred of Intelligent wells well that combine downhole flow control and monitoring have been installed over the last decade in a wide range of reservoir production scenarios. Numerous publications have reported the successful use of the technology to reduce the number of well interventions, improve sweep efficiency, reduce risk, mitigate production problems, etc. A number of zonal inflow and outflow control methodologies have been proposed to meet a wide range of different well objectives as well as different production or injection conditions. Research still continues in the areas of simple reactive or predefined passive control methods employed by Intelligent wells. This is even more true if it is planned to use proactive control which requires optimisation of a complex multivariable problem.Efficient downhole flow control comes at the cost of adding an additional pressure loss. Such losses can be significant, jeopardizing the well productivity and sometimes carrying the risk of a reduced well performance of the intelligent well when compared to the corresponding conventional well. Installing artificial lift can compensate for this reduced well performance; not only extending the well life, but also adding additional well control flexibility. However, it also poses two extra problems: how to (a) optimally design the artificial lift equipment and (b) avoid interference between the I-well's control of the zonal inflow and control of the artificial lift.This paper sets out how to(1) Add control flexibility to downhole flow control by artificial lift and (2) Design an electric submersible pump that operates flexibly with down hole, multi-zone inflow control actions.Improved active and passive downhole flow control will be discussed in a rigorous, mathematical manner that allows the conclusion that the combination of artificial lift and downhole flow control provides greater zonal flow control flexibility and reduces the inflow imbalance. Also, two conceptual, electric submersible pump design options, employing (1) a variable wellhead choke and (2) a variable pump operating frequency, are proposed and illustrated. Both of these proposed pump design options could cope with the changing well inflow performance created by downhole flow control devices in situations where the standard pump design workflow was ineffective.

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Heightened the petroleum productivity of an eruptive well by an electric submersible pump with a free gas separator

Biloa,

Kingni,

Dongmo

et al. 2023

Int J Energ Water Res

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Production Optimization in ESP Completions with Intelligent Well Technology by Using Downhole Chokes to Optimize ESP Performance

Cited by 6 publications

References 2 publications

Analysis of Possible Applications of Dual ESPs—A Reservoir-Engineering Perspective

Analysis of Possible Applications of Dual ESPs—A Reservoir-Engineering Perspective

Role of Artificial Lift in Wells With a Downhole, Flow Control Completion

Heightened the petroleum productivity of an eruptive well by an electric submersible pump with a free gas separator

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