Stable hyperbolic singularities for three-phase flow models in oil reservoir simulation

1992 ◽  
Vol 28 (2) ◽  
pp. 135-159 ◽  
Author(s):  
Heloisa Bauzer Mederios
Keyword(s):  
Reservoir Simulation ◽  
Oil Reservoir ◽  
Phase Flow ◽  
Flow Models ◽  
Three Phase ◽  
Three Phase Flow ◽  
Oil Reservoir Simulation

Development of Transient Mechanistic Three-Phase Flow Model for Wellbores

SPE Journal ◽  
2016 ◽  
Vol 22 (01) ◽  
pp. 374-388 ◽  
Author(s):  
Mahdy Shirdel ◽  
Kamy Sepehrnoori
Keyword(s):  
Multiphase Flow ◽  
Flow Model ◽  
Fluid Model ◽  
Phase Flow ◽  
Complex Flow ◽  
Flow Models ◽  
Drift Flux Model ◽  
Three Phase ◽  
Three Phase Flow ◽  
Two Fluid

Summary Multiphase flow models have been widely used for downhole-gauging and production logging analysis in the wellbores. Coexistence of hydrocarbon fluids with water in production wells yields a complex flow system that requires a three-phase flow model for better characterizing the flow and analyzing measured downhole data. In the past few decades, many researchers and commercial developers in the petroleum industry have aggressively expanded development of robust multiphase flow models for the wellbore. However, many of the developed models apply homogeneous-flow models with limited assumptions for slippage between gas and liquid bulks or use purely two-fluid models. In this paper, we propose a new three-phase flow model that consists of a two-fluid model between liquid and gas and a drift-flux model between water and oil in the liquid phase. With our new method, we improve the simplifying assumptions for modeling oil, water, and gas multiphase flow in wells, which can be advantageous for better downhole flow characterization and phase separations in gravity-dominated systems. Furthermore, we developed semi-implicit and nearly implicit numerical algorithms to solve the system of equations. We discuss the stepwise-development procedures for these methods along with the assumptions in our flow model. We verify our model results against analytical solutions for the water faucet problem and phase redistribution, field data, and a commercial simulator. Our model results show very good agreement with benchmarks in the data.

Compositional simulation of three-phase flow in mixed-wet shale oil reservoir

Fuel ◽  
2020 ◽  
Vol 260 ◽  
pp. 116361 ◽  
Author(s):  
Jingwei Huang ◽  
Tianying Jin ◽  
Zhi Chai ◽  
Maria Barrufet ◽  
John Killough
Keyword(s):  
Oil Reservoir ◽  
Phase Flow ◽  
Shale Oil ◽  
Compositional Simulation ◽  
Three Phase ◽  
Three Phase Flow

scholarly journals Universality of Riemann solutions in porous media

2021 ◽  
Vol 28 (1) ◽  
Author(s):  
Pablo Castañeda ◽  
Dan Marchesin ◽  
Frederico Furtado
Keyword(s):  
Oil Recovery ◽  
Phase Flow ◽  
Two Phase ◽  
Permeability Model ◽  
Riemann Solutions ◽  
Flow Models ◽  
Three Phase ◽  
Desirable Feature ◽  
Three Phase Flow ◽  
Universal Structure

AbstractUniversality, a desirable feature in any system. For decades, elusive measurements of three-phase flows have yielded countless permeability models that describe them. However, the equations governing the solution of water and gas co-injection has a robust structure. This universal structure stands for Riemann problems in green oil reservoirs. In the past we established a large class of three phase flow models including convex Corey permeability, Stone I and Brooks–Corey models. These models share the property that characteristic speeds become equal at a state somewhere in the interior of the saturation triangle. Here we construct a three-phase flow model with unequal characteristic speeds in the interior of the saturation triangle, equality occurring only at a point of the boundary of the saturation triangle. Yet the solution for this model still displays the same universal structure, which favors the two possible embedded two-phase flows of water-oil or gas-oil. We focus on showing this structure under the minimum conditions that a permeability model must meet. This finding is a guide to seeking a purely three-phase flow solution maximizing oil recovery.

Simulation of Multiphase Flow With Vaporization in DGI Engine Injector

2001 ◽  
Author(s):  
Ales Alajbegovic ◽  
Gerhard Meister ◽  
David Greif ◽  
Christopher von Kuensberg Sarre ◽  
Reinhard Tatschl ◽  
...  
Keyword(s):  
Flow Simulation ◽  
Vapor Flow ◽  
Phase Flow ◽  
Flow Models ◽  
Air Core ◽  
Three Phase ◽  
Three Phase Flow ◽  
Swirl Injector ◽  
Simulation Results ◽  
Pressure Swirl

Abstract The purpose of the paper is to present a simulation concept, which is able to take into account the most important phenomena that occur in the high-pressure swirl injector fuel flows, typical for the direct gasoline injection (DGI) engines. Used are two- (air, gasoline liquid) and three-phase (air, gasoline liquid and vapor) flow models. The most important characteristics of the flow were predicted. Both two- and three-phase flow simulation results show the formation of a thin conical sheet with an air core. Vaporization in the air core due to pressure drop below the saturation conditions was predicted in the three-phase flow simulation.

scholarly journals A maximum principle for multiphase flow models

2017 ◽  
pp. 138-145
Author(s):  
К.А. Новиков
Keyword(s):  
Maximum Principle ◽  
Flow Model ◽  
Maximum Principles ◽  
Phase Flow ◽  
Two Phase ◽  
Flow Models ◽  
Three Phase ◽  
Three Phase Flow ◽  
Multi Phase Flow ◽  
Multi Phase

Сформулированы и доказаны принципы максимума для нескольких моделей многофазной фильтрации. Первый принцип справедлив для фазовых насыщенностей в несжимаемом случае модели двухфазной фильтрации с постоянными вязкостями, а второй - для глобального давления в моделях двух- и трехфазной фильтрации Two maximum principles for several multi-phase flow models are formulated and proved. The first one is valid for phase saturations in an incompressible two-phase flow model with constant viscosities. The second one is valid for the global pressure in two- and three-phase flow models with constant viscosities and is also valid for phase pressures in the case of zero capillary pressure.

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