LiquidLoading 00088523
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This paper presents a comparison among these three different technologies applied to a low-pressure gas condensate well with big bore completion. At the early stage of production, a gas well with a big bore completion will allow high production rates (> 100 MMscfd). As reservoir pressure declines, liquid hydrocarbons and water precipitate may cause liquid loading in the wellbore. Thus, it will require more effort to unload the well. Installing a velocity string will increase the gas velocity, which will prevent liquid loading. The optimum length, diameter and position will be determined based on calculated minimum gas velocity. Gas re-injection will be based on injection rate, and period, as well as method, through tubing or annular.
Introduction The idea of comparing application of these three technologies toe well with big bore completion came from the situation in Arun field, on the northern coast of Aceh Province in North Sumatra, Indonesia,
SPE 88523
Liquid Unloading in a Big Bore Completion: A Comparison Among Gas Lift, Intermittent Production, and Installation of Velocity String
Fitrah Arachman, Kalwant Singh, James K. Forrest, Monas O. Purba, Schlumberger
This paper was selected for presentation by an SPE Program Committee following review of information contained in a proposal submitted by the author(s). Contents of the paper, as presented, have not been reviewed by the Society of Petroleum Engineers and are subject to correction by the author(s). The material, as presented, does not necessarily reflect any position of the Society of Petroleum Engineers, its officers, or members. Papers presented at SPE meetings are subject to publication review by Editorial Committees of the Society of Petroleum Engineers. Electronic reproduction, distribution, or storage of any part of this paper for commercial purposes without the written consent of the Society of Petroleum Engineers is prohibited. Permission to reproduce in print is restricted to a proposal of not more than 300 words; illustrations may not be copied. The proposal must contain conspicuous acknowledgment of where and by whom the paper was presented. Write Librarian, SPE, P.O. Box 833836, Richardson, TX 75083-3836, U.S.A., fax 01-972-952-9435.
A depleted gas reservoir is a gas reservoir that is in its late production period with declining pressure and gas production rates. This period is usually indicated by low wellhead pressure, and increases in liquid production. With low reservoir pressure, or low bottom-hole pressure, wells that produce liquid along with the gas might have a problem of liquid accumulation in the wellbore. These liquids include water and hydrocarbon liquid such as condensate. The liquid production can cause serious problems for the well if there is inadequate energy to lift the liquid from the well-bore. The problem can be attributed to a low gas producing rate resulting from low bottom-hole pressure or low gas relative permeability for given conditions. Liquid loading may also exist in gas wells with high liquid-gas ratio. In this type of gas well, a high liquid hold up in the tubing contributes to higher pressure drop, and liquid accumulation in the bottom of the well even if the bottom hole pressure is not low.
Copyright 2004, Society of Petroleum Engineers Inc.
This paper was prepared for presentation at the SPE Asia Pacific Oil and Gas Conference and Exhibition held in Perth, Australia, 18–20 October 2004.
Abstract Liquid loading is a serious problem in low-pressure gas wells. Liquid accumulation in gas wells with inadequate energy to lift the liquid from the wellbore can cause a well to die prematurely.
This study focuses on showing the best solution to obtain optimum gas recovery from both a technical and economical viewpoint. This study uses published information from the Arun field as an example, but it is applicable to any lowpressure gas condensate field with a big bore completion.
Liquid Loading and Unloading Mechanism Many papers have been published discussing the problem of liquid loading in gas wells (Duggan, 1961; Turner et al., 1969; Illobi et al., 1981; Lea et al., 1983 Coleman et al., 1991): how it is caused, how to prevent it, and how to deal with it.
as shown in Fig. 1. This field began production in 1977, with average reservoir pressure and temperature of 7115 psia and 352 oF respectively, as shown in Table 1, and produces gas and condensate through big bore completion wells1. Currently, the reservoir pressure has been depleted to as low as 700 psia1, reservoir pressure depletion is expected to continue, and the abandonment pressure may be on the order of 300 to 350 psia. At current stage, liquid loading is a more serious issue.
Various technologies are available to prevent liquid loading in gas wells. They include gas lift, intermittent production, and the installation of a velocity string. Each has applications and limitations for certain well and production conditions. Installation cost and operating cost are also important considerations in choosing the appropriate technology.
Introduction The idea of comparing application of these three technologies toe well with big bore completion came from the situation in Arun field, on the northern coast of Aceh Province in North Sumatra, Indonesia,
SPE 88523
Liquid Unloading in a Big Bore Completion: A Comparison Among Gas Lift, Intermittent Production, and Installation of Velocity String
Fitrah Arachman, Kalwant Singh, James K. Forrest, Monas O. Purba, Schlumberger
This paper was selected for presentation by an SPE Program Committee following review of information contained in a proposal submitted by the author(s). Contents of the paper, as presented, have not been reviewed by the Society of Petroleum Engineers and are subject to correction by the author(s). The material, as presented, does not necessarily reflect any position of the Society of Petroleum Engineers, its officers, or members. Papers presented at SPE meetings are subject to publication review by Editorial Committees of the Society of Petroleum Engineers. Electronic reproduction, distribution, or storage of any part of this paper for commercial purposes without the written consent of the Society of Petroleum Engineers is prohibited. Permission to reproduce in print is restricted to a proposal of not more than 300 words; illustrations may not be copied. The proposal must contain conspicuous acknowledgment of where and by whom the paper was presented. Write Librarian, SPE, P.O. Box 833836, Richardson, TX 75083-3836, U.S.A., fax 01-972-952-9435.
A depleted gas reservoir is a gas reservoir that is in its late production period with declining pressure and gas production rates. This period is usually indicated by low wellhead pressure, and increases in liquid production. With low reservoir pressure, or low bottom-hole pressure, wells that produce liquid along with the gas might have a problem of liquid accumulation in the wellbore. These liquids include water and hydrocarbon liquid such as condensate. The liquid production can cause serious problems for the well if there is inadequate energy to lift the liquid from the well-bore. The problem can be attributed to a low gas producing rate resulting from low bottom-hole pressure or low gas relative permeability for given conditions. Liquid loading may also exist in gas wells with high liquid-gas ratio. In this type of gas well, a high liquid hold up in the tubing contributes to higher pressure drop, and liquid accumulation in the bottom of the well even if the bottom hole pressure is not low.
Copyright 2004, Society of Petroleum Engineers Inc.
This paper was prepared for presentation at the SPE Asia Pacific Oil and Gas Conference and Exhibition held in Perth, Australia, 18–20 October 2004.
Abstract Liquid loading is a serious problem in low-pressure gas wells. Liquid accumulation in gas wells with inadequate energy to lift the liquid from the wellbore can cause a well to die prematurely.
This study focuses on showing the best solution to obtain optimum gas recovery from both a technical and economical viewpoint. This study uses published information from the Arun field as an example, but it is applicable to any lowpressure gas condensate field with a big bore completion.
Liquid Loading and Unloading Mechanism Many papers have been published discussing the problem of liquid loading in gas wells (Duggan, 1961; Turner et al., 1969; Illobi et al., 1981; Lea et al., 1983 Coleman et al., 1991): how it is caused, how to prevent it, and how to deal with it.
as shown in Fig. 1. This field began production in 1977, with average reservoir pressure and temperature of 7115 psia and 352 oF respectively, as shown in Table 1, and produces gas and condensate through big bore completion wells1. Currently, the reservoir pressure has been depleted to as low as 700 psia1, reservoir pressure depletion is expected to continue, and the abandonment pressure may be on the order of 300 to 350 psia. At current stage, liquid loading is a more serious issue.
Various technologies are available to prevent liquid loading in gas wells. They include gas lift, intermittent production, and the installation of a velocity string. Each has applications and limitations for certain well and production conditions. Installation cost and operating cost are also important considerations in choosing the appropriate technology.