Modeling and Experimental Study of Newtonian Fluid Flow in Annulus

Sorgun, Mehmet; Özbayoğlu, A. Murat; Aydin, İsmail

doi:10.1115/1.4002243

Cited by 19 publications

(9 citation statements)

References 10 publications

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“…From the equation of momentum, [40,41], for a one-directional flow in a slit (11) where P is the pressure, x is the flow direction, T is the stress tensor, y is the distance from the wall (membrane surface), and u is the velocity of the fluid. From Eq.…”

Section: Flow Pressure Dropmentioning

confidence: 99%

Auto Generative Capacitive Mixing for Power Conversion of Sea and River Water by the Use of Membranes

Burheim

Sales²,

Schaetzle³

et al. 2012

Journal of Energy Resources Technology

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The chemical potential (free energy) of mixing two aqueous solutions can be extracted via an auto generative capacitive mixing (AGCM) cell using anionic and cationic exchange membranes together with porotis carbon electrodes. Alternately, feeding sea and river water through the unit allows for the system to spontaneously deliver charge and discharge the capacitive electrodes so that dc electric work is supplied. Having a stack of eight cells coupled in parallel demonstrated the viability of this technology. An average power density of 0.055 W m~^ was obtained during the peak of the different cycles, though reasonable optimization suggests an expectation of 0.26 W m^'^ at 6.2 A m~^. It was found that 83 ± 8% of the theoretical driving potential was obtained during the operating process. By studying the polarization curves during charging and discharging cycles, it was found that optimizing the feed fluid flow is currently among the most beneficial paths to make AGCM a viable salinity difference power source. Another parallel route for increasing the efficiency is lowering the internal ohmic resistances of the cell by design modifications.

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Section: Flow Pressure Dropmentioning

confidence: 99%

Auto Generative Capacitive Mixing for Power Conversion of Sea and River Water by the Use of Membranes

Burheim

Sales²,

Schaetzle³

et al. 2012

Journal of Energy Resources Technology

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“…Pereira et al (2007) considered the effect of inner pipe rotation in their CFD analysis in which they used Cross rheological model. More recently, Sorgun et al (2010) and Sorgun (2011) Theory Fredrickson and Bird (1958) were among pioneers to seek analytical solution to the fluid flow problem in annulus. Their final solution, however, was valid only for integer values of the inverse of power-law index.…”

Section: Introductionmentioning

confidence: 99%

Computational Modeling of Drilling Fluids Dynamics in Casing Drilling

et al. 2012

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Casing drilling is used as an alternative to conventional drilling with drillpipe in order to reduce non-productive time. The smaller annular space in casing drilling elevates the annular pressure loss considerably at similar flow rates in conventional drilling. Consequently, the Equivalent Circulating Density (ECD) is more affected by annular drilling fluid dynamics in casing drilling than the conventional drilling. The higher ECD experienced in casing drilling brings concerns about exceeding fracture gradient which can lead to induced lost circulation. However, several field observations demonstrate successful application of casing drilling in combating lost circulation and strengthening the wellbore.Smearing effect theory backed by smaller cuttings at the shale shaker, eccentric casing wear, and discrepancy between analytical and field measurements are three main evidences for potential significant eccentricity in casing drilling operations. This paper demonstrates the inherent eccentricity of casing drilling as one of the parameters that controls the annular pressure losses. Eccentricity reduces the velocity in the narrow section of annulus. Similarly, it reduces the annular pressure losses considerably. In addition, controlling the fluid rheological properties as well as the flow rate are recommended to manage the casing drilling hydraulics. This comprehensive study of pressure loss and velocity profile at various annular sizes can help analyzing several field observations and designing the hydraulics of drilling operations.

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“…In inclined and horizontal wellbores, the drillstring settles on the low side of the wellbore forming eccentric annulus that changes the flow pattern significantly. Without the drillstring rotation, eccentricity can reduce the annular pressure drop significantly [2] and sometimes by as much as 60% [3]. In addition, as the drillstring rotates, due to its extensive length, it moves from one end to the other end of the wellbore, producing wobbling motion and eccentricity fluctua tions that create very complicated flow patterns in the annulus.…”

Section: Introductionmentioning

confidence: 97%

Annular Frictional Pressure Losses During Drilling—Predicting the Effect of Drillstring Rotation

Saasen

2014

Journal of Energy Resources Technology

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Controlling the annular frictional pressure losses is important in order to drill safely with overpressure without fracturing the for mation. To predict these pressure losses, however, is not straight forward. First of all, the pressure losses depend on the annulus eccentricity. Moving the drillstring to the wall generates a wider flow channel in part of the annulus which reduces the frictional pressure losses significantly. The drillstring motion itself also affects the pressure loss significantly. The drillstring rotation, even for fairly small rotation rates, creates unstable flow and sometimes turbulence in the annulus even without axial flow.Transversal motion o f the drillstring creates vortices that destabi lize the flow. Consequently, the annular frictional pressure loss is increased even though the drilling fluid becomes thinner because of added shear rate. Naturally, the rheological properties of the drilling fluid play an important role. These rheological properties include more properties than the viscosity as measured by API procedures. It is impossible to use the same frictional pressure loss model for water based and oil based drilling fluids even if their viscosity profile is equal because o f the different ways these fluids build viscosity. Water based drilling fluids are normally constructed as a polymer solution while the oil based are combi nations o f emulsions and dispersions. Furthermore, within both water based and oil based drilling fluids there are functional dif ferences. These differences may be sufficiently large to require different models for two water based drilling fluids built with dif ferent types of polymers. In addition to these phenomena washouts and tool joints will create localised pressure losses. These local ised pressure losses will again be coupled with the rheological properties of the drilling fluids. In this paper, all the above men tioned phenomena and their consequences for annular pressure losses will be discussed in detail. North Sea field data is used as an example. It is not straightforward to build general annular pressure loss models. This argument is based on flow stability analysis and the consequences o f using drilling fluids with differ ent rheological properties. These different rheological properties include shear dependent viscosity, elongational viscosity and other viscoelastic properties.

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Modeling and Experimental Study of Newtonian Fluid Flow in Annulus

Cited by 19 publications

References 10 publications

Auto Generative Capacitive Mixing for Power Conversion of Sea and River Water by the Use of Membranes

Auto Generative Capacitive Mixing for Power Conversion of Sea and River Water by the Use of Membranes

Computational Modeling of Drilling Fluids Dynamics in Casing Drilling

Annular Frictional Pressure Losses During Drilling—Predicting the Effect of Drillstring Rotation

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