High GLR ESP Technologies Comparison, Field Test Results (Russian)

Bedrin, V.G.; Хасанов, М. К.; Khabibullin, Rinat; Krasnov, Vitaly; Pashali, A.A.; Litvinenko, Konstantin; Elichev, V.; Prado, Mauricio

doi:10.2118/117414-ru

Cited by 6 publications

(3 citation statements)

References 1 publication

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“…The design methods used to increase the gas-handling capability of ESP are divided into three main categories that are represented in the subsequent flow chart (see Figure 13) along with their types. The main concepts behind these three gas-handling design methods are described by Wilson [112] and Bedrin [113] as:…”

Section: Design Methods To Increase Two-phase Flow-handling Ability Omentioning

confidence: 99%

Research Progress and Prospects of Multi-Stage Centrifugal Pump Capability for Handling Gas–Liquid Multiphase Flow: Comparison and Empirical Model Validation

et al. 2021

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The working capability of multi-stage pumps, such as electrical submersible pumps (ESPs) handling multiphase flow, has always been a big challenge for petroleum industries. The major problem is associated with the agglomeration of gas bubbles inside ESP-impellers, causing pump performance degradation ranging from mild to severe deterioration (surging/gas pockets). Previous literature showed that the two-phase performance of ESPs is greatly affected by gas involvement, rotational speed, bubble size, and fluid viscosity. Thus, it is necessary to understand which parameter is actually accountable for performance degradation and different flow patterns in ESP, and how it can be controlled. The present study is mainly focused on (1) the main parameters that impede two-phase performance of different ESPs; (2) comparison of existing empirical models (established for two-phase performance prediction and surging initiation) with our single-stage centrifugal pump results to determine their validity and working-range; (3) gas-handling techniques applied to enhance the multiphase performance of ESPs. Firstly, it aims at understanding the internal flow mechanism in different ESP designs, followed by test studies based on empirical models, visualization techniques, bubble-size measurements, and viscosity analysis. The CFD-based (computational fluid dynamics) numerical analysis concerning multiphase flow is described as well. Furthermore, gas-handling design methods are discussed that are helpful in developing the petroleum industry by enhancing the multiphase performance of ESPs.

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Section: Design Methods To Increase Two-phase Flow-handling Ability Omentioning

confidence: 99%

Research Progress and Prospects of Multi-Stage Centrifugal Pump Capability for Handling Gas–Liquid Multiphase Flow: Comparison and Empirical Model Validation

et al. 2021

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“…Using upstream modules allows stable operation with a gas content at the reception to 0.5 [2]. There are technologies that extend the ESP operating range when there is a significant amount of free gas in the stream.…”

Section: An Estimate Of the Separation Coefficient And The Maximum Almentioning

confidence: 99%

“…Well production optimization should not affect oil recovery factor (ORF). [2] provides an overview of the limit values of free gas in the flow conditions and for different types of pumps. In this article we consider the case of the well at reservoir pressure exceeding the bubble point pressure (undersaturated oil, gas cap is missing), and without the underlying water, i.e.…”

Section: Introductionmentioning

confidence: 99%

Express Method to Estimate Target Bottomhole Pressure in Pumping Oil Well

Хасанов

Khabibullin²,

Musabirov

et al. 2014

All Days

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Most of the oil wells in Western Siberia using electric submersible pumps (ESPs). Selection of the optimal mode of operation for wells equipped with ESP and selection of proper ESP technologies capable to maintain this mode highly important for effective oil production.For many fields in Western Siberia the lowest bottom-hole pressure achievable is an optimal well operating mode. It gives maximum flow rate of fluid and oil. However, reducing pressure below bubble point leads to liberation of large amount of free gas in flow. It cause one of the major constraints to reduce the bottom hole pressure -artificial lift technologies limitations for working with a high content of free gas in the flow. That increase significance of the accounting of free gas presence in the flow while analyzing oil production systems, designing downhole equipment, calculating target bottomhole pressure.Despite the fact that modern software can calculate the characteristics of multiphase flow and take into account the presence of free gas in the well and downhole equipment its influence often underestimated by engineers. Probably due to the complexities of quick multiphase flow calculations and lack of intuitive results, visualization tools which could help for decision-making.In this paper we propose a set of simple graphical tools (pallet and graphs), and methods for calculating the gas fraction in the well and downhole equipment, target bottomhole pressure, applicability limits of technologies. Tools proposed aims to provide quick operational decisions for production analysis and artificial lift design. The paper discusses the experience of using the tools developed on real fields.

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Challenges of Using Electrical Submersible Pump (ESP) in High Free Gas Applications

2010

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One of the limitations of achieving full potential in pumped wells is the presence of excessive free gas at pump intake. Presence of free gas at pump intake affects the pump performance negatively, reducing the liquid rates and the pressure added by the pump. This performance reduction may sometimes be quite severe, resulting in unstable pump operation, significant production losses, lower reliability and increased operating costs due to premature equipment failure. Currently some operators need to produce wells under challenging operational conditions with very high free gas ratios. ESP in wells with a high free gas liquid ratio that requires the use of special gas handling technologies is becoming more and more common. Recent advances in ESP gas handling technologies expand the use of ESPs to more gassy applications in the industry. This paper presents the methods used, the results and learnings from the application of ESPs with various gas handling technologies based on real field data. Present natural flow conditions were simulated to determine the operating envelope for each well. ESPs were evaluated for the selected design ranges governed by the drawdown (bubble point) constraints. The operating envelopes for each selected well were established over its life cycle with various free gas volumes and water cuts. The paper confirms that ESP can operate successfully with the pump intake gas fraction up to 75% through use of appropriate gas handling technologies and challenging the norms.

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High GLR ESP Technologies Comparison, Field Test Results (Russian)

Cited by 6 publications

References 1 publication

Research Progress and Prospects of Multi-Stage Centrifugal Pump Capability for Handling Gas–Liquid Multiphase Flow: Comparison and Empirical Model Validation

Research Progress and Prospects of Multi-Stage Centrifugal Pump Capability for Handling Gas–Liquid Multiphase Flow: Comparison and Empirical Model Validation

Express Method to Estimate Target Bottomhole Pressure in Pumping Oil Well

Challenges of Using Electrical Submersible Pump (ESP) in High Free Gas Applications

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