Positive frictional pressure gradient in vertical gas-high viscosity oil slug flow

2016 ◽  
Vol 59 ◽  
pp. 50-61 ◽  
Author(s):  
A. Al-Sarkhi ◽  
E. Pereyra ◽  
C. Sarica ◽  
F. Alruhaimani
Keyword(s):  
Pressure Gradient ◽  
Slug Flow ◽  
High Viscosity ◽  
High Viscosity Oil

scholarly journals Prospects of High Viscosity Oil Flow Rate in Horizontal Wells

2021 ◽  
Author(s):  
Sudad H Al-Obaidi ◽  
Galkin AP ◽  
Patkin AA
Keyword(s):  
Fluid Flow ◽  
Pressure Gradient ◽  
Flow Rate ◽  
Pore Space ◽  
Analytical Formula ◽  
High Viscosity ◽  
Pressure Gradients ◽  
Oil Flow ◽  
Molecular Components ◽  
High Viscosity Oil

The non-Newtonian nature of fluid flow represents one of the most important features of the development of high-viscosity oil (HVO) deposits .The deviation from the linear law of the fluid flow is associated, first of all, with the formation of a strong spatial structure due to the presence of high-molecular components and dissolved gases in the composition. The stress required to destroy the formed structure is called the shear stress of the ultimate destruction of the structure. In this regard, in order to ensure the flow of HVO through the pore space, it is necessary to create certain values of pressure gradients above the dynamic shear pressure gradient (DSPG). With increasing pressure gradients above the DSPG, the oil structure begins to collapse, and after overcoming the critical value of the pressure gradient of the ultimate destruction of the structure (PGUDS), flow begins to be described by the Newtonianlaw. The article considers the influence of various factors on the oil flow rate of a horizontal well (HW) that exploits the HVO Deposit. At the same time, numerical experiments were carried out on a hydrodynamic model for the non-Newtonian oil flow regime (in the presence of DSPG) and the results obtained were compared with calculations of the oil flow rate using an analytical formula.

scholarly journals High Viscosity Land Based Oil Flow Model

2021 ◽  
Vol 2021 (1) ◽  
Author(s):  
Daniel Mendelsohn ◽  
Eric Comerma ◽  
Matt Bernardo ◽  
Jeremy Fontenault ◽  
Sitara Baboolal
Keyword(s):  
Shear Stress ◽  
Pressure Gradient ◽  
Flow Model ◽  
High Viscosity ◽  
Surface Boundary ◽  
Viscous Oil ◽  
Oil Flow ◽  
Downslope Flow ◽  
High Viscosity Oil ◽  
Highly Viscous Oil

ABSTRACT Highly viscous oil does not behave the same as other regular liquid hydrocarbon mixtures. To evaluate the effects of a potential land-based blowout on the surrounding environment, RPS implemented a multi-step approach to simulate the trajectory and fate of high viscosity oil downslope flow. If spilled on land, initially warm oil cools and tends to gel, implying a non-Newtonian flow. To predict the behavior of high viscosity oil as it flows downslope, spreads and cools, RPS developed a new unique land-based spill model. The behavior of highly viscous crude oil has many similarities to volcanic lava flows, particularly the stark changes in oil viscosity and shear stress as the fluid cools. This study describes a “lava” flow numerical model developed to simulate the response of high viscosity oils. The viscous flow model is based on the lava model of Griffiths (2000) which simulates the unconfined motion of a Bingham fluid down a plane of constant slope. The model allows all physical and chemical parameters to vary continuously downslope. The lateral flow is assumed to cease when the cross-slope pressure gradient is balanced by the basal-yield stress also giving the height of the flow (H) on the center line of the flow as a function of shear stress. For oil flow motion the downslope pressure gradient must be greater than the oil shear stress and hence there is a critical height, based on the local oil shear stress and slope, below which there will be no downslope motion. An atmospheric heat transfer equation was applied to the oil surface as the surface boundary condition. The model was applied to a hypothetical on land release of highly viscous oil in a one-dimensional, downslope form, where the ground slope was assumed constant along the flow path. As the oil progresses downslope, its temperature was updated each time step in each cell and used to calculate new oil properties for density, specific heat, viscosity, and shear stress. The model results provide information about the rate and total distance travelled and time for the downslope flow to stop.

Experimental Analysis and Model Evaluation of High-Liquid-Viscosity Two-Phase Upward Vertical Pipe Flow

SPE Journal ◽  
2016 ◽  
Vol 22 (03) ◽  
pp. 712-735 ◽  
Author(s):  
F.. Al-Ruhaimani ◽  
E.. Pereyra ◽  
C.. Sarica ◽  
E. M. Al-Safran ◽  
C. F. Torres
Keyword(s):  
Pressure Gradient ◽  
Production System ◽  
Two Phase Flow ◽  
High Viscosity ◽  
Mechanistic Models ◽  
Phase Flow ◽  
Liquid Viscosity ◽  
Vertical Pipe ◽  
Two Phase ◽  
High Viscosity Oil

Summary Understanding the behavior of two-phase flow is a key parameter for a proper oil/gas-production-system design. Mechanistic models have been developed and tuned to model the entire production system. Most existing two-phase-flow models are derived from experimental data with low-viscosity liquids (μL < 20 mPa·s). However, behavior of two-phase flow is expected to be significantly different for high-viscosity oil. The effect of high liquid viscosity on two-phase flow is still not well-studied in vertical pipes. In this study, the effect of high oil viscosity on upward two-phase gas/oil-flow behavior in vertical pipes was studied experimentally and theoretically. A total of 149 air/high-viscosity-oil and 21 air/water experiments were conducted in a vertical pipe with an inner diameter (ID) of 50.8 mm. Six different oil viscosities—586, 401, 287, 213, 162, and 127 mPa·s—were considered. The superficial-liquid and -gas velocities were varied from 0.05 to 0.7 m/s and from 0.5 to 5 m/s, respectively. Flow pattern, pressure gradient, and average liquid holdup were measured and analyzed in this study. The experimental results were used to evaluate different flow-pattern maps, mechanistic models, and correlations for two-phase flow. Significant discrepancies between experimental and predicted results for pressure gradient were observed.

Pipe Inclination Effects on Slug Flow Characteristics of High Viscosity Oil-Gas Two-Phase Flow for Near Horizontal Pipes

2017 ◽  
Author(s):  
Samet Ekinci ◽  
T. B. Aydin ◽  
C. Sarica ◽  
E. Pereyra ◽  
T. Kim
Keyword(s):  
Slug Flow ◽  
Two Phase Flow ◽  
Flow Characteristics ◽  
High Viscosity ◽  
Phase Flow ◽  
Two Phase ◽  
Horizontal Pipes ◽  
High Viscosity Oil ◽  
Oil Gas ◽  
Pipe Inclination

An experimental study of the inclination angle (±2° from horizontal) effects on high viscosity oil and gas two-phase flow has been conducted, and the available multiphase flow models/correlations have been evaluated using the acquired data. The effect of pipe inclination on the slug flow characteristics of highly viscous oil-gas two-phase flow was studied based on 1,040 data points covering a wide range of experimental conditions and liquid viscosities in a 50.8-mm-ID pipe at 2° downward and upward inclinations from horizontal. The oil viscosity ranged from 155 cP to 587 cP. Superficial liquid and gas velocities varied from 0.1 m/s to 0.8 m/s and from 0.1 m/s to 5 m/s, respectively. The basic two-phase flow parameters and slug flow characteristics have been analyzed and compared with the past studies conducted for near horizontal pipes.

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