Productivity for Horizontal Wells in Low-Permeability Reservoir with Oil/Water Two-Phase Flow

Zhao, Yulong; Zhang, Liehui; He, Zhanxiang; Zhang, Bo-Ning

doi:10.1155/2014/364678

Cited by 3 publications

(2 citation statements)

References 29 publications

(41 reference statements)

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“…It is due to the interaction between the solid phase (rock) and fluid (oil, gas, water). The different fluid saturations just affect the TPG, not the main cause of the existence of this phenomenon (Dong et al 2019;Miller and Low 1963;Zhao et al 2014).…”

Section: Introductionmentioning

confidence: 99%

Tight gas production model considering TPG as a function of pore pressure, permeability and water saturation

Zafar

et al. 2020

Pet. Sci.

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Threshold pressure gradient has great importance in efficient tight gas field development as well as for research and laboratory experiments. This experimental study is carried out to investigate the threshold pressure gradient in detail. Experiments are carried out with and without back pressure so that the effect of pore pressure on threshold pressure gradient may be observed. The trend of increasing or decreasing the threshold pressure gradient is totally opposite in the cases of considering and not considering the pore pressure. The results demonstrate that the pore pressure of tight gas reservoirs has great influence on threshold pressure gradient. The effects of other parameters like permeability and water saturation, in the presence of pore pressure, on threshold pressure gradient are also examined which show that the threshold pressure gradient increases with either a decrease in permeability or an increase in water saturation. Two new correlations of threshold pressure gradient on the basis of pore pressure and permeability, and pore pressure and water saturation, are also introduced. Based on these equations, new models for tight gas production are proposed. The gas slip correction factor is also considered during derivation of this proposed tight gas production models. Inflow performance relationship curves based on these proposed models show that production rates and absolute open flow potential are always be overestimated while ignoring the threshold pressure gradients.

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Section: Introductionmentioning

confidence: 99%

Tight gas production model considering TPG as a function of pore pressure, permeability and water saturation

Zafar

et al. 2020

Pet. Sci.

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“…The original formation pressure is 50 MPa. Tight oil reservoirs have obvious threshold pressure gradient characters [1][2][3] and rock compressibility stress sensitivity characters [4][5][6][7]. The formation water is going to salt out and solution gas is going to get out from the oil if formation pressure decreases fast.…”

Section: Introductionmentioning

confidence: 99%

Study on Reasonable Energy Supplement Time of Tight Sandstone Oil Reservoirs with Rock Compressibility Stress Sensitivity

Tian¹,

Xianhong²,

Ji³

et al. 2018

Geofluids

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A-HBR field is a tight sandstone oil reservoir with a threshold pressure gradient and a rock compressibility stress sensitivity. However, no existing approach could predict reasonable energy supplement time considering both of them. Therefore, in this paper, rock compressibility stress sensitivity experiments are conducted. Then, a new approach is presented. This approach considers the correlation of rock compressibility and formation pressure. And the formation pressure is different from the development time and distance to oil well. The study suggests that the energy supplement time is later when the original rock compressibility is larger. The energy supplement time is earlier when the rock compressibility is more severe. A-HBR field’s reasonable energy supplement time is 83 days when considering the effect of rock compressibility stress sensitivity. It is much earlier than that when not considering the effect of rock compressibility stress sensitivity.

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A Composite Transient Model for Multi-Fractured Horizontal Well in Tight Gas Reservoirs Based on Multi-Factor Effect

Cao

et al. 2018

SPE Europec Featured at 80th EAGE Conference and Exhibition

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In low-permeability tight reservoirs, the natural gas transient flow is affected by multi-factor including stress-sensitivity, threshold pressure gradient, or both. This paper aims to synthetically study transient pressure response as well as transient rate behavior of a multi-fractured horizontal well in tight gas reservoirs. With the new mathematics model, the flow characteristics coupled with such multi-factor can be described. The new composite seepage model of a line-sink incorporating both stress-sensitive permeability and threshold pressure gradient was established. Employing fractures discretization and superposition principle yielded the final model of a multi-fractured horizontal well. The model was semi-analytically solved by Pedrosa's transformation, perturbation theory, and integration transformation method. Not only pressure transient analysis, but also rate transient analysis are separately performed with relevant parameters. A total of six flow periods can be divided according to the same standard of time stages for pressure type curves and rate type curves. It is found that stress-sensitivity results in upward tendencies in both of pressure and rate derivative curves reflecting larger pressure drop during intermediate and late flow regimes; threshold pressure gradient leads to more difficult fluid flow acting a steeper upwarping on pressure curve and downwarping on production rate curve. Finally the variation trend of the corresponding curve will be more apparent under the combined impact of stress-sensitivity and threshold pressure gradient. The research of this paper can provide some insights into well dynamic forecasting during exploiting such reservoirs, and contribute to establish the theoretical basic for transient analysis efficiently.

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Productivity for Horizontal Wells in Low-Permeability Reservoir with Oil/Water Two-Phase Flow

Cited by 3 publications

References 29 publications

Tight gas production model considering TPG as a function of pore pressure, permeability and water saturation

Tight gas production model considering TPG as a function of pore pressure, permeability and water saturation

Study on Reasonable Energy Supplement Time of Tight Sandstone Oil Reservoirs with Rock Compressibility Stress Sensitivity

A Composite Transient Model for Multi-Fractured Horizontal Well in Tight Gas Reservoirs Based on Multi-Factor Effect

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