Experimental study on the performance of foamy oil flow under different solution gas–oil ratios

RSC Advances ◽  
2015 ◽  
Vol 5 (82) ◽  
pp. 66797-66806 ◽  
Author(s):  
Songyan Li ◽  
Zhaomin Li ◽  
Zhuangzhuang Wang
Keyword(s):  
Experimental Study ◽  
Interfacial Tension ◽  
Gas Oil ◽  
Oil Viscosity ◽  
Foamy Oil ◽  
Oil Flow ◽  
Dilational Viscoelasticity ◽  
Visualization Experiments ◽  
Solution Gas ◽  
Limit Of Solution

The lower limit of solution gas–oil ratio for foamy oil from Carabobo reservoir was determined by sandpack and visualization experiments, and explained by interfacial tension, interfacial dilational viscoelasticity, oil viscosity and elastic energy.

Characterization of Foamy Oil and Gas/Oil Two-Phase Flow in Porous Media for a Heavy Oil/Methane System

2018 ◽  
Vol 141 (3) ◽  
Author(s):  
Xinqian Lu ◽  
Xiang Zhou ◽  
Jianxin Luo ◽  
Fanhua Zeng ◽  
Xiaolong Peng
Keyword(s):  
Pressure Distribution ◽  
Heavy Oil ◽  
Simulation Models ◽  
Production Data ◽  
Gas Oil ◽  
Foamy Oil ◽  
Black Oil ◽  
Foamy Oil Flow ◽  
Oil Flow ◽  
Black Oil Model

In our previous study, a series of experiments had been conducted by applying different pressure depletion rates in a 1 m long sand-pack. In this study, numerical simulation models are built to simulate the lab tests, for both gas/oil production data and pressure distribution along the sand-pack in heavy oil/methane system. Two different simulation models are used: (1) equilibrium black oil model with two sets of gas/oil relative permeability curves; (2) a four-component nonequilibrium kinetic model. Good matching results on production data are obtained by applying black oil model. However, this black oil model cannot be used to match pressure distribution along the sand-pack. This result suggests the description of foamy oil behavior by applying equilibrium black oil model is incomplete. For better characterization, a four-component nonequilibrium kinetic model is developed aiming to match production data and pressure distribution simultaneously. Two reactions are applied in the simulation to capture gas bubbles status. Good matching results for production data and pressure distribution are simultaneously obtained by considering low gas relative permeability and kinetic reactions. Simulation studies indicate that higher pressure drop rate would cause stronger foamy oil flow, but the exceed pressure drop rate could shorten lifetime of foamy oil flow. This work is the first study to match production data and pressure distribution and provides a methodology to characterize foamy oil flow behavior in porous media for a heavy oil/methane system.

The Role of Emulsification and Interfacial Tension Ift For the Enhanced Oil Recovery Eor in Surfactant Flooding

2021 ◽  
Author(s):  
Xiaoxiao Li ◽  
Xiang'an Yue ◽  
Jirui Zou ◽  
Lijuan Zhang ◽  
Kang Tang
Keyword(s):  
Interfacial Tension ◽  
Crude Oil ◽  
Flow Rate ◽  
Oil Recovery ◽  
Surfactant Flooding ◽  
Displacement Efficiency ◽  
Oil Viscosity ◽  
Oil Film ◽  
Oil Flow ◽  
Emulsifying Capacity

Abstract In this study, a visualized physical model of artificial oil film was firstly designed to investigate the oil film displacement mechanisms. Numerous comparative experiments were conducted to explore the detachment mechanisms of oil film and oil recovery performances in different fluid mediums with flow rate. In addition, the of influencing factors of oil film were comprehensively evaluated, which mainly includes: flow rate, surfactant behaviors, and crude oil viscosity. The results show that, (1) regardless of the viscosity of crude oil, flow rate presents a limited contribution to the detachment of oil film and the maximum of ultimate oil film displacement efficiency is only approximately 10%; (2) surfactant flooding has a synergistic effect on the oil film displacement on two aspects of interfacial tension (ITF) reduction and emulsifying capacity. Giving the most outstanding performance for two oil samples in all runs, IFT reduction of ultra-low value is not the only decisive factor affecting oil film displacement efficiency, but the emulsifying capability plays the key role to the detachment of oil film due to effect of emulsifying and dispersing on oil film; (3) the increasing flow rate of surfactant flooding is able to enhance the detachment of oil film but has an objective effect on the final oil film displacement efficiency; (4) flow rate have the much influence on the detachment of oil film, but the most easily controlled factor is the surfactant property. The finding provides basis for oil film detachment and surfactant selection EOR application.

scholarly journals Experimental Study of Foamy Oil Solution Gas Drive Process in an Etched Glass Micromodel

2019 ◽  
Vol 223 ◽  
pp. 012035
Author(s):  
Yanyu Zhang ◽  
Hao Zhao ◽  
Xiaofei Sun ◽  
Shuo Zhang ◽  
Zhiyong Gai ◽  
...  
Keyword(s):  
Experimental Study ◽  
Foamy Oil ◽  
Glass Micromodel ◽  
Solution Gas Drive ◽  
Gas Drive ◽  
Solution Gas

Relative Permeability of Foamy Oil for Different Types of Dissolved Gases

2016 ◽  
Vol 19 (04) ◽  
pp. 604-619 ◽  
Author(s):  
Achinta Bera ◽  
Tayfun Babadagli
Keyword(s):  
Oil Recovery ◽  
Flow Through Porous Media ◽  
Foamy Oil ◽  
Different Types ◽  
Foamy Oil Flow ◽  
Oil Flow ◽  
Flow Through ◽  
Gas Drive ◽  
Different Gases ◽  
Solution Gas

Summary Foamy-oil flow is encountered not only during the primary stage of the cold-heavy-oil-production (CHOP) process through evolving methane originally in the oil but also in the post-CHOP enhanced-oil-recovery (EOR) applications in which different gases are injected and dissolved in heavy oil. Despite remarkable efforts on the physics of foamy oil flow, the mechanics of its flow through porous media is not properly understood yet. This is mainly because of lack of detailed experimental studies at the core scale to clarify the physics of the process and to support numerical-modeling studies. One also should test foamy-oil flow for different types of EOR gases dissolved and evolved at different conditions under pressure depletion. The objective of the present work is to perform detailed laboratory experiments on foamy-oil flow through porous media. Pressure/volume/temperature (PVT) studies were conducted to determine the actual pressure ranges in the coreflooding experiments in the beginning. After dissolving different gases in dead oil at 400 psi for methane (CH4) and carbon dioxide (CO2) and 112 psi for propane, the oil was injected into a sandpack to saturate it. The solution-gas-drive test was started by opening the outlet valve of the coreholder after reaching equilibrium. To mimic typical post-CHOP EOR conditions with methane, propane, or CO2 injection, the pressure was kept high (400 psi for CO2 and CH4 and 112 psi for propane). The produced oil by solution-gas drive and the gas evolved were monitored by collecting them in a graduated cylinder and a gas cylinder, respectively, while the pressure was recorded by an automatic data-acquisition system. The experimental data provided information about the effect of initial pressure of the depletion test in the amount of oil and gas measured as well as the visual observations of bubble characteristics of the foamy oil. Results showed that, among the three gases, CO2 is a good candidate for foamy oil. Maximum oil recovery [more than 50% of original oil in place (OIP) (OOIP)] was obtained in case of CO2.

Effect of Temperature on the Gas/Oil Relative Permeability of Orinoco Belt Foamy Oil

SPE Journal ◽  
2016 ◽  
Vol 21 (01) ◽  
pp. 170-179 ◽  
Author(s):  
Songyan Li ◽  
Zhaomin Li
Keyword(s):  
Relative Permeability ◽  
Oil Recovery ◽  
Heavy Oil ◽  
High Viscosity ◽  
Viscosity Reduction ◽  
Gas Oil ◽  
Foamy Oil ◽  
Solution Gas Drive ◽  
Gas Drive ◽  
Solution Gas

Summary Foamy-oil flow has been successfully demonstrated in laboratory experiments and site applications. On the basis of solution-gas-drive experiments with Orinoco belt heavy oil, the effects of temperature on foamy-oil recovery and gas/oil relative permeability were investigated. Oil-recovery efficiency increases and then decreases with temperature and attains a maximum value of 20.23% at 100°C. The Johnson-Bossler-Naumann (JBN) method has been proposed to interpret relative permeability characteristics from solution-gas-drive experiments with Orinoco belt heavy oil, neglecting the effect of capillary pressure. The gas relative permeability is lower than the oil relative permeability by two to four orders of magnitude. No intersection was identified on the oil and gas relative permeability curves. Because of an increase in temperature, the oil relative permeability changes slightly, and the gas relative permeability increases. Thermal recovery at an intermediate temperature is suitable for foamy oil, whereas a significantly higher temperature can reduce foamy behavior, which appears to counteract the positive effect of viscosity reduction. The main reason for the flow characteristics of foamy oil in porous media is the low gas mobility caused by the oil components and the high viscosity. High resin and asphaltene concentrations and the high viscosity of Orinoco belt heavy oil increase the stability of bubble films and prevent gas breakthrough in the oil phase, which forms a continuous gas, compared with the solution-gas drive of light oil. The increase in the gas relative permeability with temperature is caused by higher interfacial tensions and the bubble-coalescence rate at high temperatures. The experimental results can provide theoretical support for foamy-oil production.

Sign in / Sign up

Export Citation Format

Share Document