Pressure Drop Calculation Models of Wellbore Fluid in Perforated Completion Horizontal Wells

Li, Hua; Lü, Yan; Peng, Xiaodong; Lv, Xindong; Wang, Laichao

doi:10.18280/ijht.340110

Cited by 8 publications

(2 citation statements)

References 16 publications

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“…Using experimental measurements, the researchers studied how inflow impacted pressure drop in relation to both mixing and acceleration, discovering mixing pressure drop to be approximately 10% of friction pressure drop. In the same line of research, Li et al [6] investigated total pressure drop for two-phase liquid and gas using the three factors of mixing, acceleration and friction. The outcome of their tests indicated that the pressure drop for mixing and acceleration comprises less than one-seventh (approx.…”

Section: Fig 1 Schematic Of the Horizontal Near-wellbore Region And Vertical Cylindrical Perforation Tunnelmentioning

confidence: 99%

Statistical and Numerical Investigation of Gas/Liquid Flow in the Near Wellbore Region

Abobaker

Elasnoose

Rahman

et al. 2020

Proceeding of 5th Thermal and Fluids Engineering Conference (TFEC)

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Horizontal wells are considered a relatively advanced method of drilling that maximize the reservoir productivity index because of having higher contact area between the formation and the wellbore. The reservoir productivity index relies on the properties of the reservoir flow, which itself is highly dependent on wellbore geometry, completion technique, and specific reservoir parameters. Multiphase flow model through horizontal near-wellbore region has been conducted to analyze the effects of skin zone diameter (damaged region) and the influence of perforation distribution on enhanced oil recovery. Statistical analysis was coupled with numerical simulation in order to expand the investigation on fluid flow at near wellbore region. The statistical analysis is used to investigate the effect of several parameters such as, the skin zone diameter penetration space, angle and depth as well as the perforation diameter on the injection build-up pressure and the time needed for reaching steady-state flow condition. Design Expert Software (DoE) version 11 package has been used to determine the numerical simulation runs using the ANOVA analysis with Box-Behnken Design "BBD" model. Forty-one numerical runs have been generated using DoE to achieve the whole statistical analysis. ANSYS-Fluent software 18.1 has been used to carry out the numerical simulation in the porous media tunnel by applying the volume of fluid method (VOF). The numerical and statistical analysis showed a clear view of the effect of each investigated parameter on the injection build-up pressure and time required for reaching the steady-state. In addition, two correlations have been obtained from the statistical analysis and numerical simulation in which can be used to predict the injection build-up pressure and the required time to reach steady state for different scenarios. This study will be very helpful in choosing the optimal perforation distribution and understanding the multiphase flow behavior in horizontal near wellbore region.

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Section: Fig 1 Schematic Of the Horizontal Near-wellbore Region And Vertical Cylindrical Perforation Tunnelmentioning

confidence: 99%

Statistical and Numerical Investigation of Gas/Liquid Flow in the Near Wellbore Region

Abobaker

Elasnoose

Rahman

et al. 2020

Proceeding of 5th Thermal and Fluids Engineering Conference (TFEC)

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“…In addition, the OBM showcases excellent filtration property as its filtrate volume is only 3.4-5.6 mL under hightemperature (150 C) and high-pressure (3.5 MPa). The hightemperature and high-pressure condition are usually encountered when drilling deep formation [14,15]. To better characterize the flat rheology of the proposed flat-rheology oil-based drilling fluid (FR-OBM), the author compares the rheological properties of the FR-OBM (1.8 g/cm 3 ) and those of the conventional OBM.…”

Section: Evaluation Of Rheological and Filtration Propertiesmentioning

confidence: 99%

Flat-rheology oil-based drilling fluid for deepwater drilling

Zhao¹,

Qiu²,

Xu³

et al. 2017

IJHT

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In offshore deepwater drilling, the temperature is rather low near the seabed. The resulting thickening of conventional oil-based drilling fluid causes increase in equivalent circulating density. When the density surpasses the formation fracture pressure gradient, a series of problems, including lost circulation, may occur, causing huge economic losses. A desirable drilling fluid is desperately needed to solve the rheology-related problems. In view of this, this paper analyzes how oil-based drilling fluid acquires the flat-rheology characteristics, and selects preferred additives, e.g. base oil, emulsifier, organic clay and weighting materials, based on their effects on the rheological properties of drilling fluid. On this basis, the author successfully synthetizes a rheology modifier and develops a flat-rheology oil-based drilling fluid. The performance of the proposed drilling fluid is experimentally evaluated. The results indicate that the variations of the yield point, 10-min gel and θ6 reading of the proposed drilling fluid are controlled within 25% in the temperature range of 4-75 ℃ when the density is below 2.1 g/cm 3 . Besides, the proposed drilling fluid boasts good shale inhibition and filtration performance as well as strong contamination resistance to NaCl, CaCl2 and drill cuttings. In this way, this paper provides a desirable solution to rheology-related problems in deepwater drilling.

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CFD simulation of flow interference between multi-stage fractures along a horizontal wellbore

Zhao

2023

Geoenergy Science and Engineering

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Pressure Drop Calculation Models of Wellbore Fluid in Perforated Completion Horizontal Wells

Cited by 8 publications

References 16 publications

Statistical and Numerical Investigation of Gas/Liquid Flow in the Near Wellbore Region

Statistical and Numerical Investigation of Gas/Liquid Flow in the Near Wellbore Region

Flat-rheology oil-based drilling fluid for deepwater drilling

CFD simulation of flow interference between multi-stage fractures along a horizontal wellbore

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