Investigation of Enhanced Oil Recovery with the Upscaled Three Phase Flow Model in an Oil Reservoir

2019 ◽  
Author(s):  
Shahid Rabbani ◽  
Hamid Abderrahmane ◽  
Mohamed Sassi
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Flow Model ◽  
Oil Reservoir ◽  
Phase Flow ◽  
Three Phase ◽  
Three Phase Flow

An Improved Three-Phase Relative Permeability and Hysteresis Model for the Simulation of a Water-Alternating-Gas Injection

SPE Journal ◽  
2013 ◽  
Vol 18 (05) ◽  
pp. 841-850 ◽  
Author(s):  
H.. Shahverdi ◽  
M.. Sohrabi
Keyword(s):  
Relative Permeability ◽  
Oil Recovery ◽  
Gas Injection ◽  
Phase Flow ◽  
Relative Permeabilities ◽  
Water Alternating Gas ◽  
Three Phase ◽  
Three Phase Flow ◽  
Oil Water ◽  
Wag Injection

Summary Water-alternating-gas (WAG) injection in waterflooded reservoirs can increase oil recovery and extend the life of these reservoirs. Reliable reservoir simulations are needed to predict the performance of WAG injection before field implementation. This requires accurate sets of relative permeability (kr) and capillary pressure (Pc) functions for each fluid phase, in a three-phase-flow regime. The WAG process also involves another major complication, hysteresis, which is caused by flow reversal happening during WAG injection. Hysteresis is one of the most important phenomena manipulating the performance of WAG injection, and hence, it has to be carefully accounted for. In this study, we have benefited from the results of a series of coreflood experiments that we have been performing since 1997 as a part of the Characterization of Three-Phase Flow and WAG Injection JIP (joint industry project) at Heriot-Watt University. In particular, we focus on a WAG experiment carried out on a water-wet core to obtain three-phase relative permeability values for oil, water, and gas. The relative permeabilities exhibit significant and irreversible hysteresis for oil, water, and gas. The observed hysteresis, which is a result of the cyclic injection of water and gas during WAG injection, is not predicted by the existing hysteresis models. We present a new three-phase relative permeability model coupled with hysteresis effects for the modeling of the observed cycle-dependent relative permeabilities taking place during WAG injection. The approach has been successfully tested and verified with measured three-phase relative permeability values obtained from a WAG experiment. In line with our laboratory observations, the new model predicts the reduction of the gas relative permeability during consecutive water-and-gas-injection cycles as well as the increase in oil relative permeability happening in consecutive water-injection cycles.

scholarly journals A hyperbolic three-phase flow model

2006 ◽  
Vol 342 (10) ◽  
pp. 779-784 ◽  
Author(s):  
Jean-Marc Hérard
Keyword(s):  
Flow Model ◽  
Phase Flow ◽  
Three Phase ◽  
Three Phase Flow

Influence of Wettability on Residual Gas Trapping and Enhanced Oil Recovery in Three-Phase Flow: A Pore-Scale Analysis by Use of Microcomputed Tomography

SPE Journal ◽  
2016 ◽  
Vol 21 (06) ◽  
pp. 1916-1929 ◽  
Author(s):  
Stefan Iglauer ◽  
Taufiq Rahman ◽  
Mohammad Sarmadivaleh ◽  
Adnan Al-Hinai ◽  
Martin A. Fernø ◽  
...  
Keyword(s):  
Power Law ◽  
Oil Recovery ◽  
Oil And Gas ◽  
Microcomputed Tomography ◽  
Rock Surface ◽  
Phase Flow ◽  
Pore Scale ◽  
Three Phase ◽  
Three Phase Flow ◽  
Capillary Pressures

Summary We imaged an intermediate-wet sandstone in three dimensions at high resolution (1–3.4 µm3) with X-ray microcomputed tomography (micro-CT) at various saturation states. Initially the core was at connate-water saturation and contained a large amount of oil (94%), which was produced by a waterflood [recovery factor Rf = 52% of original oil in place (OOIP)] or a direct gas flood (Rf = 66% of OOIP). Subsequent waterflooding and/or gasflooding (water-alternating-gas process) resulted in significant incremental-oil recovery (Rf = 71% of OOIP), whereas a substantial amount of gas could be stored (approximately 50%)—significantly more than in an analog water-wet plug. The oil- and gas-cluster-size distributions were measured and followed a power-law correlation N ∝ V−τ , where N is the frequency with which clusters of volume V are counted, and with decays exponents τ between 0.7 and 1.7. Furthermore, the cluster volume V plotted against cluster surface area A also correlated with a power-law correlation A ∝ Vp, and p was always ≈ 0.75. The measured τ- and p-values are significantly smaller than predicted by percolation theory, which predicts p ≈ 1 and τ = 2.189; this raises increasing doubts regarding the applicability of simple percolation models. In addition, we measured curvatures and capillary pressures of the oil and gas bubbles in situ, and analyzed the detailed pore-scale fluid configurations. The complex variations in fluid curvatures, capillary pressures, and the fluid/fluid or fluid/fluid/fluid pore-scale configurations (exact spatial locations also in relation to each other and the rock surface) are the origin of the well-known complexity of three-phase flow through rock.

Experimental Study on Void Fractions and Pressure Drops in Three-Phase Flow for Deep Sea Mining

2021 ◽  
Author(s):  
Satoru Takano ◽  
Sotaro Masanobu ◽  
Shigeo Kanada ◽  
Masao Ono
Keyword(s):  
Flow Model ◽  
Homogeneous Model ◽  
Slip Flow ◽  
Phase Flow ◽  
Pressure Drops ◽  
Drift Flux Model ◽  
Void Fractions ◽  
Three Phase ◽  
Three Phase Flow ◽  
Air Lift

Abstract Subsea minerals exist in the deep water within Japan’s exclusive economic zone. There are many technical issues which should be addressed for subsea mining. The air-lift pumping systems are one of promising methods for subsea minerals transport. Flow assurance for three-phase flow is important to design the air-lift pumping system for subsea mining. It is important to establish methods for estimating void fractions and frictional pressure drops. To establish the methods for three-phase flow, we reviewed previous studies for two- or three-phase flow. There are some models to estimate the void fractions such as slip flow model and drift flux model. There are also some models to estimate the frictional pressure drops such as homogeneous model and separated flow model. We calculated void fractions and frictional pressure drops by existing correlation and compared calculated results with experimental data in two- or three-phase flow. In addition, we proposed the methods for estimating the void fractions and frictional pressure drops in three-phase flow. These had fewer number of experimental constants than existing correlations, these could calculate void fractions and frictional pressure drops in more various conditions than existing correlations.

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
Sign in / Sign up

Export Citation Format

Share Document