Production Optimization Using a Dynamic Gas-Lift Simulator, History Case

Munoz, Efren A.; Quintero, Nylian

doi:10.2118/54636-ms

Cited by 3 publications

(1 citation statement)

References 2 publications

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“…To settle this problem, Lee et al (1993) developed a numerical optimization scheme based on the Lagrange multiplier method. Munoz and Quintero (1999) simulated a dynamic gas lift to generate a reliable performance curve. Gutierrez et al (2007) optimized oil production by using a genetic algorithm.…”

Section: Introductionmentioning

confidence: 99%

The Economic Optimization of a Continuous Gas Lift System Considering Lift and Cycle Efficiency in a Mature Oil Field

Huh¹,

Park

Kang

et al. 2010

Energy Sources, Part A: Recovery, Utilization, and Environmenta

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This article presents a numerical approach for the profit maximization by allocating an optimal injected gas in a continuous gas lift system. A performance curve of gas lift was designed that takes into account both lift and cycle efficiency. Piecewise cubic hermit interpolating polynomial is performed as a tool of interpolation to achieve a minimum error and a quantitative evaluation. A robust economic function and simulate annealing are integrated to determine the independence of decision variables and lift-gas rate, which yields a maximum profit. The model applied for a mature oil field reveals that the volume of injected gas reduces significantly by 63% and the revenue increases up to 13% compared with a conventional production optimization. The developed model will be applicable enough to enhance the profit in continuous gas life system.

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Section: Introductionmentioning

confidence: 99%

The Economic Optimization of a Continuous Gas Lift System Considering Lift and Cycle Efficiency in a Mature Oil Field

Huh¹,

Park

Kang

et al. 2010

Energy Sources, Part A: Recovery, Utilization, and Environmenta

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Analytical Study on Gas Lift Optimization and Prediction of Production Life of Wells in Platform C, B-1 Field

Yusof

Karim

2015

Icipeg 2014

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Velocity String Drainage Technology for Horizontal Gas Wells in Changbei

Cai

Huang

et al. 2022

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The Changbei gas field is dominated by wells with large horizontal displacement, which have exhibited high gas production performance at an early stage of development. With the decrease in reservoir pressure, the liquid loading in the gas well is relatively high and gas production rapidly decreases. Therefore, suitable drainage measures are required to maintain stable gas production. Based on the characteristics of the unconnected oil jacket of gas wells in Changbei, a velocity string was used for drainage. A critical liquid-carrying model was established to determine the location of liquid loading in horizontal gas wells in Changbei. First, the coefficients of the liquid-carrying model were determined through theoretical analysis of the characteristics of the gas well formation. Then, the depth setting of the velocity string was analyzed. The critical liquid-carrying model was employed to calculate the liquid-carrying flow rate of each section; the calculated flow rates were compared with the actual flow rates to determine whether fluid accumulation occurred in each section of the gas well. Thereafter, with the help of the oil and casing position, the suitable setting position of the velocity string was determined. The formation fluid was driven from the tubing into the casing owing to the increase in the overflow area, based on the principle of reducer fluid mechanics. The fluid velocity in the larger overflow cross-section decreased, thereby reducing the drainage capacity of the gas well and resulting in liquid loading. Finally, a timing analysis was performed. After the formation pressure decreased, the well production and flow rate changes were analyzed by placing two velocity strings of different sizes at different wellhead pressures in the gas well with fluid accumulation. The results indicated that although the velocity string was set at a position suitable for fluid drainage, fluid accumulation still occurred after a production period, thus necessitating replacement deliquification.

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Production Optimization Using a Dynamic Gas-Lift Simulator, History Case

Abstract: This paper was prepared for presentation at the 1999 SPE Western Regional Meeting held in Anchorage, Alaska, 26–28 May 1999.

Cited by 3 publications

References 2 publications

The Economic Optimization of a Continuous Gas Lift System Considering Lift and Cycle Efficiency in a Mature Oil Field

The Economic Optimization of a Continuous Gas Lift System Considering Lift and Cycle Efficiency in a Mature Oil Field

Analytical Study on Gas Lift Optimization and Prediction of Production Life of Wells in Platform C, B-1 Field

Velocity String Drainage Technology for Horizontal Gas Wells in Changbei

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