Use of Foam to Deliquify Gas Wells

Lea, James F.; Nickens, Henry V.; Wells, Mike R.

doi:10.1016/b978-075068280-0.50009-3

Cited by 6 publications

(2 citation statements)

References 8 publications

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“…Foam can be considered as a particular type of gas and liquid emulsion, where gas bubbles are separated from each other in foam by a liquid film. Surface-active agents (surfactants) generally are employed to reduce the surface tension of the liquid to enable more gas-liquid dispersion (Lea, et al, 2008). Therefore, the foam transports a certain amount of liquid held in its bulk.…”

Section: Table 1 Comparison Between Pigging and Foamingmentioning

confidence: 99%

Experimental results of pipeline dewatering through surfactant injection

Dall’Acqua

Benucci

Corvaro

et al. 2017

Journal of Petroleum Science and Engineering

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Liquid loading is a common problem affecting hydrocarbon production both in well and pipeline. Pipelines transporting hydrocarbons from the wells to the downstream facilities often come across a hilly terrain, which could be considered the main reason of liquid loading phenomenon. Currently the main technique used to solve the problem is the mechanical pigging. Nevertheless, this technique is not free of risks, in fact when the mechanical pigging is possible, operators and engineers have to deal with several issues. This paper presents an alternative method to deliquify pipelines, by using foamer injection. Even if in its preliminary stage, this research work represents a breakthrough since the feasibility of the method can allow an easier, safer and cheaper solution of the water accumulation in pipelines.The effectiveness of pipeline deliquification treatments by foaming injection is difficult to predict a priori, due to a high number of variables affecting the foam formation and transport within the pipeline. In this paper the issues related to the application of this method are described and some preliminary results on foam formation conditions, obtained on an experimental test bench are presented.

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Section: Table 1 Comparison Between Pigging and Foamingmentioning

confidence: 99%

Experimental results of pipeline dewatering through surfactant injection

Dall’Acqua

Benucci

Corvaro

et al. 2017

Journal of Petroleum Science and Engineering

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“…The droplet model reckons that droplet morphology is the main form of producing liquid in the wellbore, which assumes that the minimum gas flow required for removing the fluid from the well is to carry the largest diameter droplet out of the wellbore continuously. Typical droplet models, Turner model [9], the Coleman model [10] and Lea model [11], etc. The liquid film model considers that the liquid film is the main form of producing liquid and its reverse flow is the main factor leading to the loading.…”

Section: Introductionmentioning

confidence: 99%

Drainage Research of Different Tube Depth in Horizontal Gas Well

Wang¹,

Ma²,

Luo³

et al. 2022

Preprint

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As the structure of horizontal gas wells is more complicated than that of vertical wells, the form of the liquid-carrying in different sections does not well agree. This makes it problematic to apply the widely used liquid-carrying theory of vertical gas wells in horizontal gas wells. Since the theory focused on the critical gas flow rate, it cannot quantify how much liquid it can remove. Simultaneously, it ignores the fact that the liquid-carrying ability of gas flow is limited and the producing liquid has a certain amount of flowing energy. In this study, the gas-liquid flow law of horizontal gas wells and wellhead drainage stability in different tubing depths were firstly studied. Then, the stability of gas drainage for different tubing depths was analyzed and confirmed. Given the disadvantages of the typical theory of critical gas flow, the mathematical model of different tubing depths for gas drainage is established for horizontal gas wells. The innovative model could take the energy of gas flow and liquid flow into account, and quantify the liquid volume which was removed. By verifying the model with the experiments, the result showed that the relative error of the model is generally less than 10%. It shows the research could provide a scientific basis for the analysis and liquid-carrying capacity for horizontal gas wells.

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