Chapter 6 Artificial Lift

Bellarby, Jonathan

doi:10.1016/s0376-7361(08)00206-9

Cited by 7 publications

(5 citation statements)

References 84 publications

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“…Evidently, the general notion that the maximum liquid production rate correlates with the deepest possible injection point is not always correct, especially for highly deviated wells such as A-1 in the current example (Nagoo and Vangolen 2020;Bellarby 2009;Guo et al 2007;Beggs 2003). Based on these results, injection depth is considered an important parameter in a gas-lift system because it affects the hydraulics of segment A.…”

Section: Theoretical Validationmentioning

confidence: 83%

“…Its wide applicability and competitive advantage over other artificial lift methods are attributed to several factors. These factors include its versatility in terms of terrain, well trajectory, relatively low operating costs and the ease of valve replacement (BenAmara 2016;Bellarby 2009;Vázquez-Román and Palafox-Hernández 2005;Alarcón et al 2002;Chia and Hussain 1999;Winkler 1987). Aside from its well-known applications in well clean-up, ramping up production and resuscitating dead wells, gas-lift can potentially be used to extend the stable production limit of an oil well, hence increasing its operating envelop and production lifetime as well as improving project economics (Yadua et al 2020).…”

Section: Introductionmentioning

confidence: 99%

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Performance of a gas-lifted oil production well at steady state

Yadua¹,

Lawal²,

Eyitayo³

et al. 2021

J Petrol Explor Prod Technol

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Although gas-lift is an established technology for improving the performances of oil production wells, the simplicity, robustness and accuracy of gas-lift models remain to be fully resolved. As an improvement on the traditional practice, this paper proposes a new approach for modelling the performance of gas-lifted wells at steady-state conditions. The conceptual framework splits the wellbore into two segments. The segments are of unique characteristics, yet they are hydraulically connected. While one segment is controlled primarily by the upstream reservoir-sandface conditions, the dynamics of the second segment are dominated by the lift-gas. This work results in a new four-phase model and an accompanying workflow for analysing the steady-state performance of a gas-lifted well. Using examples from fields operating under diverse conditions in the Niger Delta and North Sea, the new model is validated against a commercial wellbore performance simulator and actual field results. The new model yields average absolute deviation (AAD) of 2.7 and 5.4% against the commercial simulator and field results, respectively. Notwithstanding its relative simplicity, the range of AAD recorded for the new model and workflow attests to its robustness and applicability in practice. In addition to its simple mathematical form, a competitive feature of the proposed model relative to the commercial simulator and most other models is that it accounts for the four phases (gas, oil, water and solid particulates) typically encountered in mature oil production wells and brown fields.

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Section: Theoretical Validationmentioning

confidence: 83%

Section: Introductionmentioning

confidence: 99%

Performance of a gas-lifted oil production well at steady state

Yadua¹,

Lawal²,

Eyitayo³

et al. 2021

J Petrol Explor Prod Technol

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“…The fluid outlet pressure at the wellhead and the gas injection rate will be analysed. Reservoir pressure is the key to ensuring reservoir production [6]. When a well is put into production, the flow gradually drops with the pressure.…”

Section: Nodal and Sensitivity Analysesmentioning

confidence: 99%

“…Producing at lower rates is not economical. With regard to the static pressure of the reservoir, the gas-lift method is the most appropriate for well X [6,18]. Continuous gaslift is an artificial-lift method that consists of injecting gas through the producing well to lower gravity pressure losses in order to reduce the pressure at the bottom of the well [19].…”

Section: Introductionmentioning

confidence: 99%

“…

the pressure if the quantity of gas is high enough. Gas-lift is the most common well activation method, especially in offshores, with the principle of reducing hydrostatic pressure by injecting gas into the well [6,7]. The gaslift promotes the optimisation of production when the effluent no longer has enough energy to reach the surface under the conditions set by the process [8 -10].The reasons for using gas-lift are multiple, such as cleaning a well (crossover), restarting the well, and lightening the production string [11 -13].

…”

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confidence: 99%

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Design of continuous gas-lift for a dead well and step-up of its productivity

Matateyou

Njeudjang

Dongmo

et al. 2022

PVJ

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The present paper aims to design a continuous gas-lift system in order to activate the dead well X and optimise the recovery of hydrocarbons by gas injection. The data taken into account are those of the reservoir and the well. All the simulation operations and the well diagram are carried out with the PIPESIM 2017 2.0 software. Moreover, the nodal analysis of the dead well X is carried out by finding the injection pressure of the gas in the well. The number of valves to be installed, the optimal injection heights and the flow rates received by each valve are also included in the gas-lift device. Then the evaluation of the system performance as well as the sensitivity analysis are carried out to make it possible to fix the optimal flow rate of production. The results obtained show that for a continuous gas injection of 3 million standard ft3 per day (MMscf/d) per valve into the well with a wellhead pressure of 2,500 psi and an optimal flow rate of 2,718 standard barrels per day (STB/d), a profitability of USD 182,887,219 is obtained. In this field, this design can be applied to all wells having a production tube of 2.5 inches inside diameter. On the other hand, wells with different diameters will require a new evaluation.

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