Numerical Study on Effects of Drilling Mud Rheological Properties on the Transport of Drilling Cuttings

GhasemiKafrudi, Esmaeil; Hashemabadi, Seyed Hassan

doi:10.1115/1.4031450

Cited by 21 publications

(5 citation statements)

References 26 publications

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“…Although experiments have shown that the rolling effect of a small amount of sand can reduce the friction between packers and boreholes, it is very easy to bring an additional local drag due to the accumulation of downhole sand. Therefore, before the completion string enters the horizontal well, the drilling fluid performance needs to be adjusted to meet the requirement of carrying cuttings [38][39][40], and the drilling fluid lubricity should be improved to reduce the friction coefficient between the completion string and the wellbore. In addition, it is necessary to use enhanced operation parameters when pumping on and circulating the drilling fluid at the bottom of the well, such as high flow rate of the drilling fluid and the rotation speed of the drill string [41,42].…”

Section: Decisionsmentioning

confidence: 99%

Experimental Study on the Local Drag of Completion String with Packers in Horizontal Wells

et al. 2020

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The multistage stimulation technology of horizontal wells has brought huge benefits to the development of oil and gas fields. However, the completion string with packers often encounters stuck due to the large drag in the horizontal section, causing huge economic losses. The local drag of the completion string with packers in the horizontal section is very complicated, and it has not been fully understood by theoretical calculations. A local drag experiment is designed to simulate the influence of microsteps and cuttings on the local drag of the completion string with packers in the inclined and horizontal sections. An obvious increase of the local drag of the packer is found at microsteps of the horizontal section, and the local drag is greatly affected by the amount of sand. In addition, the string with packers will vibrate during the tripping process in the deviated section, and the local drag is different when different amounts of sand are in the hole, but the change law is similar. The experimental results show that the friction coefficients of the packers with different materials in the horizontal section vary greatly, resulting in different local drags. It indicates that the local drag of the completion string not only depends on the microsteps and sand quantity in the wellbore, but also on the material difference of the packers. Only if microsteps and cuttings are removed can the completion string be tripped into horizontal wells smoothly.

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Section: Decisionsmentioning

confidence: 99%

Experimental Study on the Local Drag of Completion String with Packers in Horizontal Wells

et al. 2020

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“…Duan et al (2008) [5] regressed an empirical formula of cuttings bed height based on experimental results. Shadizadeh and Zoveidavianpoor (2012) [6] and GhasemiKafrudi and Hashemabadi (2016) [7] found that a high-viscosity fluid carries cuttings more effectively than a low-viscosity fluid. Yu et al (2007) [8] found that the height of the cuttings bed sharply increases upon a certain drill pipe eccentricity; the torque also increases at this point, resulting in an increased likelihood that the drill will stick.…”

Section: Introductionmentioning

confidence: 99%

Investigation: Cutting Transport Mechanism in Inclined Well Section under Pulsed Drilling Fluid Action

Zhu

Shen

2021

Energies

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Due to gravity, drilling cuttings are easily accumulated in an inclined well section, ultimately forming a cuttings bed, which places the drill pipe under strong friction torque. In severe cases, this can cause dragging, stuck drills, and broken drill tools. Because conventional drilling fluids are difficult to prevent the formation of cuttings in inclined well sections, a method of carrying cuttings with the pulsed drilling fluid to improve wellbore cleanness is proposed. Experiments and numerical simulations are conducted to investigate the effects of cuttings bed transport velocity, cuttings size, cuttings height, drill pipe rotation speed, cuttings bed mass, and roughness height. The optimal pulse parameters are determined per their respective impact on cuttings transport concerning varied periods, amplitudes, and duty cycles of the pulsed drilling fluid. Compared to cuttings transport under the conventional drilling fluid flow rate, the pulsed drilling fluid produces the turbulent dissipation rate, increases cuttings transport velocity, and thus improves the wellbore clearance rate.

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“…GhasemiKafrudi and Hashemabadi numerically studied hydrodynamics of drilling fluid (Herschel–Bulkley) with cuttings by the mixture multiphase model. They developed a numerical code to calculate the velocity and pressure profiles in annuli.…”

Section: Introductionmentioning

confidence: 99%

Temperature and pressure effects of drilling fluid on cutting transport using CFD simulations

Akbari

Hashemabadi

2017

Asia-Pacific J Chem Eng

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Simulation of liquid–solid flow in annulus of oil wells is of a great importance to predict the two‐phase flow field in wellbore accurately. In this paper, direct effects of drilling fluid rheological properties by Herschel–Bulkley model on cuttings transportation, pressure drop, and other parameters of two‐phase flow are numerically investigated at different temperatures and pressures. Recent studies have not addressed these effects. Thus, a 3D form of a steady‐state and isothermal model is used to simulate the two‐phase flow in various temperatures and pressures of drilling fluid, flow rates, and drilling pipe rotations. The governing equations created a system of coupled partial differential equations solved using the iterative finite volume method. The comparisons between the results of the model and experimental data and also analytical relation showed that the model can accurately predict two‐phase flow in the annulus. The results indicated that the elevation of temperature and reduction of pressure contributes to a decrease in the cuttings transportation. For drilling fluid velocity of 0.75 m/s, the cuttings transportation has been decreased 2.08% by increasing temperature from 70°C to 90°C in 0.1 MPa, whereas in pressure of 10 MPa, about 1.63% reduction on the transportation of cuttings yielded. © 2017 Curtin University and John Wiley & Sons, Ltd.

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Numerical Study on Effects of Drilling Mud Rheological Properties on the Transport of Drilling Cuttings

Cited by 21 publications

References 26 publications

Experimental Study on the Local Drag of Completion String with Packers in Horizontal Wells

Experimental Study on the Local Drag of Completion String with Packers in Horizontal Wells

Investigation: Cutting Transport Mechanism in Inclined Well Section under Pulsed Drilling Fluid Action

Temperature and pressure effects of drilling fluid on cutting transport using CFD simulations

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